UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2013
2016
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Commission File Number | | Exact name of registrants as specified in their charters, address of principal executive offices and registrants' telephone number | | IRS Employer Identification Number |
| 1-8841 | | NEXTERA ENERGY, INC. | | 59-2449419 |
2-27612
| | FLORIDA POWER & LIGHT COMPANY 700 Universe Boulevard Juno Beach, Florida 33408 (561) 694-4000 | | 59-0247775
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State or other jurisdiction of incorporation or organization:Florida
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| | Name of exchange on which registered |
| Securities registered pursuant to Section 12(b) of the Act: | |
| NextEra Energy, Inc.: | Common Stock, $0.01 Par Value | New York Stock Exchange |
| | 5.889%6.371% Corporate Units | New York Stock Exchange |
| | 5.799%6.123% Corporate Units | New York Stock Exchange |
Florida Power & Light Company:None | |
Indicate by check mark if the registrants are well-known seasoned issuers, as defined in Rule 405 of the Securities Act of 1933. |
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NextEra Energy, Inc. Yes þ No o Florida Power & Light Company Yes þ No o |
Indicate by check mark if the registrants are not required to file reports pursuant to Section 13 or Section 15(d) of the Securities Exchange Act of 1934.
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NextEra Energy, Inc. Yes o No þ Florida Power & Light Company Yes o No þ |
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months, and (2) have been subject to such filing requirements for the past 90 days.
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NextEra Energy, Inc. Yes þ No o Florida Power & Light Company Yes þ No o |
Indicate by check mark whether the registrants have submitted electronically and posted on their corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months.
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NextEra Energy, Inc. Yes þ No o Florida Power & Light Company Yes þ No o |
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrants' knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ
Indicate by check mark whether the registrants are a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Securities Exchange Act of 1934.
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| NextEra Energy, Inc. | Large Accelerated Filer þ | Accelerated Filer o | Non-Accelerated Filer o | Smaller Reporting Company o |
| Florida Power & Light Company | Large Accelerated Filer o | Accelerated Filer o | Non-Accelerated Filer þ | Smaller Reporting Company o |
Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Securities Exchange Act of 1934). Yes ¨ No þ
Aggregate market value of the voting and non-voting common equity of NextEra Energy, Inc. held by non-affiliates as of June 28, 201330, 2016 (based on the closing market price on the Composite Tape on June 28, 201330, 2016) was $34,470,185,53960,089,366,330.
There was no voting or non-voting common equity of Florida Power & Light Company held by non-affiliates as of June 28, 201330, 2016.
The numberNumber of shares outstanding of NextEra Energy, Inc. common stock, as of the latest practicable date: Common Stock, $0.01 par value, outstanding as of January 31, 20142017: 435,382,649 shares.467,581,899
AsNumber ofJanuary 31, 2014, there were issued and outstanding 1,000 shares of Florida Power & Light Company common stock, without par value, outstanding as of January 31, 2017, all of which were held, beneficially and of record, by NextEra Energy, Inc.: 1,000
DOCUMENTS INCORPORATED BY REFERENCE
Portions of NextEra Energy, Inc.'s Proxy Statement for the 20142017 Annual Meeting of Shareholders are incorporated by reference in Part III hereof.
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This combined Form 10-K represents separate filings by NextEra Energy, Inc. and Florida Power & Light Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Florida Power & Light Company makes no representations as to the information relating to NextEra Energy, Inc.'s other operations.
Florida Power & Light Company meets the conditions set forth in General Instruction I.(1)(a) and (b) of Form 10-K and is therefore filing this Form with the reduced disclosure format.
DEFINITIONS
Acronyms and defined terms used in the text include the following:
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| Term | Meaning |
| AFUDC | allowance for funds used during construction |
AFUDC - debt | debt component of allowance for funds used during construction |
AFUDC - equity | equity component of allowance for funds used during constructionAFUDC |
| AOCI | accumulated other comprehensive income |
| Bcf | billion cubic feet |
| capacity clause | capacity cost recovery clause, as established by the FPSC |
CFTC | U.S. Commodity Futures Trading Commission |
CO2 | carbon dioxide |
| DOE | U.S. Department of Energy |
| Duane Arnold | Duane Arnold Energy Center |
| environmental clause | environmental cost recovery clause |
| EPA | U.S. Environmental Protection Agency |
| ERCOT | Electric Reliability Council of Texas |
FDEP | Florida Department of Environmental Protection |
| FERC | U.S. Federal Energy Regulatory Commission |
| Florida Southeast Connection | Florida Southeast Connection, LLC, a wholly-owned NEECHwholly owned NEER subsidiary |
| FPL | Florida Power & Light Company |
FPL FiberNet | fiber-optic telecommunications business |
| FPSC | Florida Public Service Commission |
| fuel clause | fuel and purchased power cost recovery clause, as established by the FPSC |
| GAAP | generally accepted accounting principles in the U.S. |
| GHG | greenhouse gas(es) |
| IPO | initial public offering |
| ISO | independent system operator |
| ITC | investment tax credit |
| kW | kilowatt |
| kWh | kilowatt-hour(s) |
Lone Star | Lone Star Transmission, LLC |
| Management's Discussion | Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations |
| MMBtu | One million British thermal units |
| mortgage | mortgage and deed of trust dated as of January 1, 1944, from FPL to Deutsche Bank Trust Company Americas, as supplemented and amended |
| MW | megawatt(s) |
| MWh | megawatt-hour(s) |
| NEE | NextEra Energy, Inc. |
| NEECH | NextEra Energy Capital Holdings, Inc. |
| NEER | NextEra Energy Resources, LLC |
| NEET | NextEra Energy Transmission, LLC |
| NEP | NextEra Energy Partners, LP |
| NEP OpCo | NextEra Energy Operating Partners, LP |
| NERC | North American Electric Reliability Corporation |
NHT | New Hampshire Transmission, LLC |
| Note __ | Note __ to consolidated financial statements |
| NOx | nitrogen oxide |
| NRC | U.S. Nuclear Regulatory Commission |
| NYISO | New York ISO |
| O&M expenses | other operations and maintenance expenses in the consolidated statements of income |
| OCI | other comprehensive income |
| OTC | over-the-counter |
| OTTI | other than temporary impairment |
| PJM | PJM Interconnection, L.L.C. |
| PMI | NextEra Energy Power Marketing, LLC |
| Point Beach | Point Beach Nuclear Power Plant |
| PTC | production tax credit |
| PUCT | Public Utility Commission of Texas |
| PURPA | Public Utility Regulatory Policies Act of 1978, as amended |
| PV | photovoltaic |
| Recovery Act | The American Recovery and Reinvestment Act of 2009, as amended |
| regulatory ROE | return on common equity as determined for regulatory purposes |
| RFP | request for proposal |
| ROE | return on common equity |
| RPS | renewable portfolio standards |
| RTO | regional transmission organization |
| Sabal Trail | Sabal Trail Transmission, LLC, an entity in which a NEECHNEER subsidiary has a 33%42.5% ownership interest |
| Seabrook | Seabrook Station |
| SEC | U.S. Securities and Exchange Commission |
SO2 | sulfur dioxide |
| U.S. | United States of America |
WCEC | FPL's West County Energy Center in western Palm Beach County, Florida |
NEE, FPL, NEECH and NEER each has subsidiaries and affiliates with names that may include NextEra Energy, FPL, NextEra Energy Resources, NextEra, FPL Group, FPL Group Capital, FPL Energy, FPLE, NEP 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.
TABLE OF CONTENTS
FORWARD-LOOKING STATEMENTS
This report includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, strategies, future events or performance (often, but not always, through the use of words or phrases such as may result, are expected to, will continue, is anticipated, aim, believe, will, could, should, would, estimated, may, plan, potential, future, projection, goals, target, outlook, predict and intend or words of similar meaning) are not statements of historical facts and may be forward looking. Forward-looking statements involve estimates, assumptions and uncertainties. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, important factors included in Part I, Item 1A. Risk Factors (in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements) that could have a significant impact on NEE's and/or FPL's operations and financial results, and could cause NEE's and/or FPL's actual results to differ materially from those contained or implied in forward-looking statements made by or on behalf of NEE and/or FPL in this combined Form 10-K, in presentations, on their respective websites, in response to questions or otherwise.
Any forward-looking statement speaks only as of the date on which such statement is made, and NEE and FPL undertake no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law. New factors emerge from time to time and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.
PART I
Item 1. Business
OVERVIEW
NextEra Energy, Inc. (hereafter, NEE)NEE is one of the largest electric power companies in North America with approximately 42,500 MWand, through its subsidiary NEER and its affiliated entities, is the largest generator of generating capacity in 26 statesrenewable energy from the wind and sun in the U.S. and 4 provinces in Canada, and employing approximately 13,900 people as of December 31, 2013.world based on 2016 MWh produced. NEE provides retail and wholesale electric services to nearly 5 million customers andalso owns and/or operates generation, transmission and distribution facilities to support its services. It also purchases electric power for resaleservices to itsretail and wholesale customers, and has investments in gas infrastructure assets. NEE also provides risk management services related to power and gas consumption related to its own generation assets and for a limited number of wholesale customers in selected markets. NEE is the largest generator in North America of renewable energy from the wind and sun. NEE owns and operates approximately 17% of the installed base of U.S. wind power production capacity and owns and/or operates approximately 14% of the installed base of U.S. utility-scale solar power production capacity as of December 31, 2013. NEE also owns and operates one of the largest fleets of nuclear power stations in the U.S., with eight reactors at five sites located in four states, representing approximately 6% of U.S. nuclear power electric generating capacity as of December 31, 2013. NEE's business strategy has emphasized the development, acquisition and operation of renewable, nuclear and natural gas-fired generation facilities in response to long-term federal policy trends supportive of zero and low air emissions sources of power. As of December 31, 2016, NEE's business included the following:
approximately 45,900 MW of generating capacity with electric generation fleet has significantly lower rates of emissions of CO2facilities located in 30 states in the U.S., SO24 provinces in Canada and NOx than the average ratesin Spain;
approximately 16% of the installed base of U.S. electricwind power industry with production capacity;
approximately 96% of its 2013 generation, measured by MWh produced, coming from renewable, nuclear and natural gas-fired facilities. Certain environmental attributes11% of the wholesale business'installed base of U.S. universal solar power production capacity;
one of the largest fleets of nuclear power stations in the U.S., with 8 reactors at 5 sites located in 4 states, representing approximately 6% of U.S. nuclear power electric generating facilities, such as renewable energy credits (RECs), emissions reductions, offsets, allowancescapacity;
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| • | a generation fleet with significantly lower rates of emissions of CO2, SO2 and NOx than the average rates of the U.S. electric power industry with approximately 98% of its 2016 generation, measured by MWh produced, coming from renewable, nuclear and natural gas-fired facilities; |
approximately 800 substations and 76,700 miles of transmission and distribution lines;
more than 5.4 million retail and wholesale electric customer accounts; and
approximately 14,700 people employed, primarily in the avoided emission of GHG pollutants, have been or likely will be sold or transferred to third parties, who are solely entitled to the reporting rights and ownership of the environmental attributes.U.S.
NEE was incorporated in 1984 under the laws of Florida and conducts its operations principally through two wholly-ownedwholly owned subsidiaries, Florida Power & Light Company (hereafter, FPL)FPL and NextEra Energy Resources, LLC (hereafter, NEER). NextEra Energy Capital Holdings, Inc. (hereafter, NEECH),NEER. NEECH, another wholly-ownedwholly owned subsidiary of NEE, owns and provides funding for NEER's and NEE's other operating subsidiaries, other than FPL and its subsidiaries. During 2014, NEE formed NEP to acquire, manage and own contracted clean energy projects with stable, long-term cash flows. See NEER section below for further discussion of NEP. When discussed in this combined Form 10-K, NEE's and NEER's generating capacity as of December 31, 2016 includes approximately 971 MW associated with noncontrolling interests related to NEP.
NEE's two principal businesses, FPL and NEER, also constitute NEE's reportable segments for financial reporting purposes.
FPL is a rate-regulated electric utility engaged primarily in the generation, transmission, distribution and sale of electric energy in Florida. FPL is the largest electric utility in the state of Florida and one of the largest electric utilities in the U.S. based on retail MWh sales. FPL is vertically integrated, with approximately 24,300 MW of generating capacity as of December 31, 2013. FPL's investments in its infrastructure since 2001, such as modernizing less-efficient fossil generating plants to produce more energy with less fuel and fewer air emissions, increasing generating capacity at its existing nuclear units and upgrading its transmission and distribution systems to deliver service reliability that is the best of the Florida investor-owned utilities, have provided significant benefits to FPL's customers, all while providing residential and commercial bills that were among the lowest in Florida and below the national average based on a rate per kWh as of July 2013 (the latest date See Note 14 for which this data is available). With approximately 94% of its power generation coming from natural gas, nuclear and solar, FPL is also one of the cleanest electric utilities in the nation. Based on 2013certain financial information FPL's emissions rates for CO2, SO2 and NOx were 35%, 97% and 71% lower, respectively, than the average rates of the U.S. electric power industry.
NEER, with approximately 18,300 MW of generating capacity at December 31, 2013, is one of the largest wholesale generators of electric power in the U.S., with nearly 17,800 MW of generating capacity across 24 states, and with approximately 400 MW in 4 Canadian provinces. NEER produces the majority of its electricity from clean and renewable sources, including wind and solar. NEER also provides full energy and capacity requirements services, engages in power and gas marketing and trading activities, participates in natural gas, natural gas liquids and oil production and pipeline infrastructure development and owns a retail electricity provider.
NEECH's other business activities are primarily conducted through NEET and FPL FiberNet. NEET conducts its operations principally through two wholly-owned subsidiaries, Lone Star, a rate-regulated transmission service provider in Texas, and NHT, a rate-regulated transmission owner in New Hampshire. FPL FiberNet delivers wholesale and enterprise telecommunications services in Florida, Texas and certain areas of the South Central U.S.
about these segments. NEE seeks to create value in its two principal businesses by meeting its customers' needs more economically and more reliably than its competitors, as described in more detail in the following sections. NEE's strategy has resulted in profitable growth over sustained periods at both FPL and NEER. Management seeks to grow each business in a manner consistent with the varying opportunities openavailable to it; however, management believes that the diversification and balance represented by FPL and NEER is a valuable characteristic of the enterprise and recognizes that each business contributes to NEE's credit profile in different ways. FPL and NEER, as well as other NEE subsidiaries, share common support functions with the objective of lowering costs and creating efficiencies for their businesses. During 2013, NEE and its subsidiaries commenced an enterprise-wide initiativecontinue to develop and implement enterprise wide initiatives focused mainly on improving productivity and reducing O&M expenses (cost savings initiative), and management expects to continue those efforts over the near term.
NEE'S OPERATING SUBSIDIARIESinitiatives).
I. In July 2016, NEE announced a proposed merger (EFH merger) under which a newly formed subsidiary of NEE will acquire 100% of the equity of reorganized Energy Future Holdings Corp. (reorganized EFH) and certain of its direct and indirect subsidiaries, including its indirect ownership of approximately 80% of the outstanding equity interests of Oncor Electric Delivery Company LLC
(Oncor), a regulated electric distribution and transmission business that operates the largest distribution and transmission system in Texas. The merger agreement (EFH merger agreement) provides that the consideration for the transaction funded by NEE will be $9.796 billion, which will be paid almost all in cash, with the balance in shares of NEE common stock. The amount of consideration will be subject to adjustment as provided in the EFH merger agreement. In late October 2016, additional agreements were entered into with other parties that, when combined with the EFH merger agreement, if completed, would result in NEE owning 100% of Oncor. The aggregate consideration to be paid by NEE under these additional agreements will be approximately $2.4 billion and will be subject to adjustment as provided in the additional agreements. On February 17, 2017, the U.S. Bankruptcy Court for the District of Delaware confirmed Energy Future Holdings Corp.'s Eighth Amended Joint Plan of Reorganization. Completion and actual closing dates of the EFH merger and the other Oncor-related transactions remain subject to, among other things, approval by the PUCT and receipt of a supplemental private letter ruling from the Internal Revenue Service (IRS). The PUCT hearings regarding the merger transactions were conducted the week of February 20, 2017. NEE, EFH and the other parties to the EFH merger agreement, and the parties to the other Oncor-related transaction agreements, have certain specified termination rights. NEE expects the EFH merger and the other Oncor-related transactions to be completed in the first half of 2017. See Note 7 - Pending Oncor-Related Transactions.
In January 2017, a subsidiary of NEE completed the sale of its fiber-optic telecommunications business (FPL FiberNet) for net cash proceeds of approximately $1.1 billion, after repayment of $370 million of related long-term debt. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale.
FPL
FPL was incorporated under the laws of Florida in 1925 and is a wholly-owned subsidiary of NEE. FPL is a rate-regulated electric utility engaged primarily in the generation, transmission, distribution and sale of electric energy in Florida. FPL is the largest electric utility in the state of Florida and one of the largest electric utilities in the U.S. based on retail MWh sales. At December 31, 2016, FPL with 24,273had approximately 26,000 MW of net generating capacity, at74,800 miles of transmission and distribution lines and 600 substations. FPL provides service to its customers through an integrated transmission and distribution system that links its generation facilities to its customers. At December 31, 2013, supplies electric2016, FPL served approximately 10 million people through approximately 4.9 million customer accounts. FPL's service throughoutterritory, which covers most of the east and lower west coasts of Florida, serving more than 9 million people through approximately 4.7 million customer accounts. At December 31, 2013, FPL's service territory and plant locations areas of December 31, 2016 were as follows (see Item 2 - Generating Facilities)Sources of Generation below):
FRANCHISE AGREEMENTS AND COMPETITION
FPL's service to its retail customers is provided primarily under franchise agreements negotiated with municipalities or counties. Alternatively, municipalities and counties may form their own utility companies to provide service to their residents. In a very few cases, an FPL franchise agreement provides the respective municipality the right to buy the electrical assets serving local residents at the end of the agreement. However, during the term of a franchise agreement, which is typically 30 years, the municipality or county agrees not to form its own utility, and FPL has the right to offer electric service to residents. FPL currently holds 177 franchise agreements with various municipalities and counties in Florida with varying expiration dates through 2043. Six of these franchise agreements expire in 2014, four expire in 2015 and 167 expire during the period 2016 through 2043. These franchise agreements cover approximately 85% of FPL's retail customer base in Florida. Negotiations are ongoing to renew the franchise agreements that expire in 2014 and 2015. FPL considers its franchises to be adequate for the conduct of its business. FPL also provides service to 12 other municipalities and to 22 unincorporated areas within its service area without franchise agreements pursuant to the general obligation to serve as a public utility. FPL relies upon Florida law for access to public rights of way.
Because any customer may elect to provide his/her own electric services, FPL effectively must compete for an individual customer's business. As a practical matter, few customers provide their own service at the present time since FPL's cost of service is substantially lower than the cost of self-generation for the vast majority of customers. Changing technology, economic conditions and other factors could alter the favorable relative cost position that FPL currently enjoys; however, FPL seeks as a matter of strategy to ensure that it delivers superior value, in the form of high reliability, low bills and excellent customer service.
In addition to self-generation by residential, commercial and industrial customers, FPL also faces competition from other suppliers of electrical energy to wholesale customers and from alternative energy sources. In each of 2013, 2012 and 2011, operating revenues from wholesale and industrial customers combined represented approximately 3% of FPL's total operating revenues. FPL expects revenues from wholesale sales to increase in 2014 primarily due to an increase in contracted load served under existing wholesale contracts.
The FPSC promotes cost competitiveness in the building of new steam and solar generating capacity by requiring investor-owned electric utilities, including FPL, to issue an RFP except when the FPSC determines that an exception from the RFP process is in the public interest. The RFP process allows independent power producers and others to bid to supply the new generating capacity. If a bidder has the most cost-effective alternative, meets other criteria such as financial viability and demonstrates adequate expertise and experience in building and/or operating generating capacity of the type proposed, the investor-owned electric utility would seek to negotiate a purchased power agreement with the selected bidder and request that the FPSC approve the terms of the purchased power agreement and, if appropriate, provide the required authorization for the construction of the bidder's generating capacity.
New nuclear power plants and combustion turbines are exempt from the RFP requirement. See FPL Sources of Generation - Fossil Operations and Nuclear Operations below.
CUSTOMERS AND REVENUE
FPL's primary source of operating revenues is from its retail customer base; it also serves a limited number of wholesale customers within Florida. Beginning in 2013, operating revenues include gains associated with an incentive mechanism allowed under the 2012 rate agreement (see FPL Regulation - FPL Rate Regulation - Base Rates - Rates Effective January 2013 - December 2016); such gains are included in other in the chart below. The percentage of FPL's operating revenues and customer accounts by customer class were as follows:
For both retail and wholesale customers, the prices (or rates) that FPL may charge are approved by regulatory bodies, by the FPSC in the case of retail customers, and by the FERC in the case of wholesale customers. In general, under U.S. and Florida law, regulated rates are intended to cover the cost of providing service, including an appropriatea reasonable rate of return on capital employed.invested capital. Since the regulatory bodies have authority to determine the relevant cost of providing service and the appropriate rate of return on capital employed, there can be no guarantee that FPL will be able to earn any particular rate of return or recover all of its costs through regulated rates. See FPL Regulation below.
FPL seeks to maintain attractive rates for its customers. Since rates are largely cost-based, maintaining low rates requires a strategy focused on developing and maintaining a low cost position. Thelow-cost position, including the implementation of ideas generated from the cost savings initiative are expected to keep FPL's O&M expenses recovered through base rates flat through 2016 as compared to 2012.initiatives discussed above. A common benchmark used in the electric power industry for comparing rates across companies is the price of 1,000 kWh of consumption per month for a residential customer. FPL's 20132016 average bill for 1,000 kWh of monthly residential usage was the lowest among reporting electric utilities within Florida and well below the July 2016 national average (the latest date for which this data is available) as indicated below:
POWER DELIVERY
FRANCHISE AGREEMENTS AND COMPETITION
FPL's service to its retail customers is provided primarily under franchise agreements negotiated with municipalities or counties. During the term of a franchise agreement, which is typically 30 years, the municipality or county agrees not to form its own utility, and FPL has the right to offer electric service to residents. FPL currently holds180franchise agreements with various municipalities and counties in Florida with varying expiration dates through2046. These franchise agreements cover approximately 88% of FPL's retail customer base in Florida. FPL also provides service to 13other municipalities and to 21 unincorporated areas within its service area without franchise agreements pursuant to the general obligation to serve as a public utility. FPL relies upon Florida law for access to public rights of way.
Because any customer may elect to provide his/her own electric services, FPL effectively must compete for an individual customer's business. As a practical matter, few customers provide their own service at the present time since FPL's cost of service is lower than the cost of self-generation for the vast majority of customers. Changing technology, economic conditions and other factors could alter the favorable relative cost position that FPL currently enjoys; however, FPL seeks as a matter of strategy to ensure that it delivers superior value, in the form of high reliability, low bills and excellent customer service.
In addition to self-generation by residential, commercial and industrial customers, FPL also faces competition from other suppliers of electrical energy to wholesale customers and from alternative energy sources. In each of 2016, 2015 and 2014, operating revenues from wholesale and industrial customers combined represented approximately five percent of FPL's total operating revenues.
For the building of new steam and solar generating capacity of 75 MW or greater, the FPSC requires investor-owned electric utilities, including FPL, to issue an RFP except when the FPSC determines that an exception from the RFP process is in the public interest. The RFP process allows independent power producers and others to bid to supply the new generating capacity. If a bidder has the most cost-effective alternative, meets other criteria such as financial viability and demonstrates adequate expertise and experience in building and/or operating generating capacity of the type proposed, the investor-owned electric utility would seek to negotiate a purchased power agreement with the selected bidder and request that the FPSC approve the terms of the purchased power agreement and, if appropriate, provide the required authorization for the construction of the bidder's generating capacity.
FPL provides service to its customers through an integrated transmission and distribution system that links its generation facilities to its customers. FPL also maintains interconnection facilities with neighboring utilities and non-utility generators inside its territory, enabling it to buy and sell wholesale electricity and to enhance the reliability of its own network and support the reliability of neighboring networks. FPL's transmission system carries high voltage electricity from its generating facilities to substations where the electricity is stepped down to lower voltage levels and is sent through the distribution system to its customers.SOURCES OF GENERATION
A key element of FPL's strategy is to provide highly reliable service to its customers. The transmission and distribution system is susceptible to interruptions or outages from a wide variety of sources including weather, animal and vegetation interference, traffic accidents, equipment failure and many others, and FPL seeks to reduce or eliminate outages where economically practical and to restore service rapidly when outages occur. A common industry benchmark for transmission and distribution system reliability is the system average interruption duration index (SAIDI), which represents the number of minutes the average customer is without power during a time period. For the five years 2008 - 2012, FPL's average annual SAIDI was the best of the investor-owned utilities in Florida. FPL is accelerating its existing storm hardening and reliability program through 2016, to continue strengthening its infrastructure against tropical storms and hurricanes. Also, during 2013, FPL completed the final installation of approximately 4.5 million smart meters and other equipment, as part of its commitment to building a smarter, more reliable and efficient electric infrastructure.
FPL SYSTEM CAPABILITY AND LOAD
At December 31, 2013,2016, FPL's resources for serving load consisted of 26,23626,836 MW, of which 24,27326,017 MW were from FPL-owned facilities (see Item 2 - Generating Facilities) and 1,963 approximately 819MW were available through purchased power agreements, including 330 MW associated with a coal-fired generation facility located in Indiantown, Florida that FPL purchased in January 2017 (Indiantown generation facility) (see Note 13 - Contracts). FPL Sourcesowned and operated 33 units that used fossil fuels, primarily natural gas, and had joint ownership interests in 3 coal units with an aggregate generating capacity of Generation - Purchased Power22,305 MW. In addition, FPL owned, or had undivided interests in, and operated 4 nuclear units with generating capacity totaling 3,453 MW (see Nuclear Operations below) and5 solar generation facilities with generating capacity totaling 259MW (excluding 75 MW of non-incremental solar capability which is provided through a natural gas generation facility). FPL customer usage and operating revenues are typically higher during the summer months, largely due to the prevalent use of air conditioning in FPL's service territory. Occasionally, unusually cold temperatures during the winter months result in significant increases in electricity usage for short periods of time. The highest peak load FPL has served to date was 24,346 MW, which occurred on January 11, 2010. FPL had adequate resources available at the time of this peak to meet customer demand.
FPL's projected reserve margin for the summer of 2014 is approximately 28%. This reserve margin is expected to be achieved through the combination of available output from FPL's active generating units, purchased power agreements and the capability to reduce peak demand through the implementation of demand side management programs, including load management which was estimated at December 31, 2013 to be capable of reducing demand by 1,870 MW, and energy efficiency and conservation programs. See FPLFuel Sources of Generation - Fossil Operations and Nuclear Operations below regarding generation projects currently under construction.
FPL SOURCES OF GENERATION
FPL relies upon a mix of fuel sources for its generatinggeneration facilities, along withthe ability of some of its generation facilities to operate on both natural gas and oil, and on purchased power in order to maintain the flexibility to achieve a more economical fuel mix by respondingin order to respond to market and industry developments. See descriptions of fossil, nuclear and solar operations below and a listing of FPL's generating facilities in Item 2 - Generating Facilities.
FPL's 2013 fuel mix based on MWh produced, including purchased power, was as follows:
Fossil Operations (Natural Gas, Coal and Oil)
At December 31, 2013, FPL owned and operated 71 units that used fossil fuels, primarily natural gas, and had a joint ownership interest in 3 coal units. Combined, the fossil fleet provided 20,785 MW of generating capacity for FPL. These fossil units are out of service from time to time for routine maintenance or on standby during periods of reduced electricity demand. A common industry benchmark for fossil unit reliability is the equivalent forced outage rate (EFOR), which represents a generating unit's inability to provide electricity when required to operate. For the five years 2008 - 2012, FPL's average annual EFOR was in the top decile among its electric utility fossil fleet peers in the U.S. |
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| *Oil is less than 1% | *Oil and Solar are collectively less than 1% |
FPL's natural gas plants require natural gas transportation, supply and storage. Significant Fuel Contracts.As of December 31, 2016, FPL had the following significant fuel contracts in place:
FPL has firm transportation contracts in place for existing natural gas pipeline capacity with fivedifferent transportation suppliers. These agreementssuppliers, which provide for an aggregate maximum delivery quantity of 1,969,000 MMBtu/day with expiration dates ranging from 20152017 to 2036 that together2036. Together, these contracts are expected to satisfy substantially all of the currently anticipated needs for natural gas transportation through 2016.mid-2017. To the extent desirable, FPL also purchases interruptible natural gas transportation service from thesethe five transportation suppliers.
FPL has 25-year natural gas transportation suppliers based onagreements with each of Sabal Trail and Florida Southeast Connection for a quantity of 400,000 MMBtu/day beginning in mid-2017 and increasing to 600,000 MMBtu/day in mid-2020. These new agreements, when combined with FPL's existing agreements, are expected to satisfy substantially all of FPL's natural gas transportation needs through at least 2020. FPL's firm commitments under the new agreements are contingent upon the occurrence of certain events, including the completion of construction of the pipeline availability. system to be built by Sabal Trail and Florida Southeast Connection. See NEER - Generation and Other Operations - Other Operations below and Note 13 - Contracts.
FPL has several short- and medium-term natural gas supply contracts to provide a portion of FPL's anticipated needs for natural gas. The remainder of FPL's natural gas requirements is purchased in the spot market. FPL has an agreement for the storage of natural gas that expires in 2017. See Note 13 - Contracts.2018.
FPL has several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel with expiration dates ranging from late February 2017 through 2031.
In October 2013, the FPSC approved FPL's 25-year natural gas transportation agreements with each of Sabal Trail and Florida Southeast Connection for a quantity of 400,000 MMBtu/day beginning on May 1, 2017 and increasing to 600,000 MMBtu/day on May 1, 2020. FPL's firm commitments under the agreements 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. A FERC decision is expected in 2015. See Other NEE Operating Subsidiaries - Natural Gas Pipeline System below and Note 13 - Contracts. These new agreements are expected to enable FPL to satisfy substantially all of its natural gas transportation needs through at least 2020.
St. Johns River Power Park (SJRPP) Units Nos.1 and 2, coal-fired units in which FPL has a joint ownership interest, have firm coal supply contracts and a firm transportation contract for a portion of their fuel and transportation needs through 2016. Scherer Unit No.4, the other coal-fired unit in which FPL has a joint ownership interest, has firm coal supply and transportation contracts for a portion of its fuel needs and all of its transportation needs through 2015. Any of the remaining fuel and transportation requirements for these coal-fired units will be obtained in the spot market.See Note13- Contracts. With respect to its oil plants, FPL obtains its fuel requirements in the spot market.
Modernization Projects. In April 2013, FPL placed in service, ahead of schedule and below budgeted construction cost, an approximately 1,210 MW natural gas-fired combined-cycle modernized unit at its Cape Canaveral power plant. FPL is in the process
of modernizing its Riviera Beach and Port Everglades power plants to high-efficiency natural gas-fired units that are expected to provide approximately 1,200 MW and 1,240 MW of capacity, respectively, and be placed in service in the second quarter of 2014 and by mid-2016, respectively.
Potential Gas Turbine Replacement Project. By the second quarter of 2014, FPL expects to begin monitoring emissions from the peaking gas turbines at its Lauderdale power plant for the purpose of confirming air-quality modeling that indicates exceedances of air quality standards for nitrogen dioxide (NO2) at its Lauderdale and Port Everglades power plants. If the monitoring confirms the modeled exceedances, FPL will be required to reduce NO2 emissions from these two power plants. Currently, FPL expects that the most cost-effective alternative to achieve the required emission reductions will be to retire these gas turbines, totaling 1,260 MW of capacity, and replace them with modern, low-emission combustion turbines, totaling approximately 1,005 MW of capacity. FPL plans to evaluate the results of the monitoring at the Lauderdale power plant, among other factors, to determine what action, if any, is indicated for the peaking gas turbines at its Fort Myers power plant.
Nuclear Operations
At December 31, 2013,2016, FPL owned, or had undivided interests in, and operated the following four nuclear units in Florida with a total net generating capacity of 3,453 MW. This includes approximately 520 MWFPL's nuclear units are periodically removed from service to accommodate planned refueling and maintenance outages, including inspections, repairs and certain other modifications. Scheduled nuclear refueling outages typically require the unit to be removed from service for variable lengths of generating capacity added from the generation power uprate project completed in 2013.
time.
| | | Facility | | MW | | Operating License Expiration Dates | | FPL's Ownership (MW) | | Beginning of Current or Next Scheduled Refueling Outage | | Operating License Expiration Dates |
| St. Lucie Unit No. 1 | | 981 | | 2036 | | 981 | | March 2018 | | 2036 |
| St. Lucie Unit No. 2 | | 840 | | 2043 | | 840 | | February 2017 | | 2043 |
| Turkey Point Unit No. 3 | | 811 | | 2032 | | 811 | | March 2017 | | 2032 |
| Turkey Point Unit No. 4 | | 821 | | 2033 | | 821 | | October 2017 | | 2033 |
FPL has several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel with expiration dates ranging from March 2014 through 2023. See Note 13 - Commitments. NRC regulations require FPL to submit a plan for decontamination and decommissioning five years before the projected end of plant operation. FPL's current plans, under the applicable operating licenses, provide for prompt dismantlement of Turkey Point Units Nos. 3 and 4 with decommissioning activities commencing in 2032 and 2033, respectively. Current plans provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the prompt dismantlement of St. Lucie Unit No. 2 commencing in 2043.
Projects to Add Additional Capacity. FPL's need petition for two additional nuclear units at its Turkey Point site was approved by the FPSC in 2008 and FPL is moving forward with activities necessary to obtain all permits, licenses and approvals necessary for construction and operation of the units. The two units are expected to add a total of approximately 2,200 MW of capacity and are projected to be placed in-service in 2022 and 2023. Such in-service dates could be impacted by various regulatory approvals from the FPSC and other regulatory agencies which will be required throughout the licensing and development processes, as well as other regulatory actions.
Nuclear Unit Scheduled Refueling Outages. FPL's nuclear units are periodically removed from service to accommodate normal refueling and maintenance outages, including inspections, repairs and certain other modifications. Scheduled nuclear refueling outages typically require the unit to be removed from service for variable lengths of time. The following table summarizes each unit's next scheduled refueling outage:
|
| | |
Facility | | Next Scheduled
Refueling Outage
|
St. Lucie Unit No. 1 | | March 2015 |
St. Lucie Unit No. 2 | | March 2014 |
Turkey Point Unit No. 3 | | March 2014 |
Turkey Point Unit No. 4 | | September 2014 |
Spent Nuclear Fuel.FPL's nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which are expected to provide sufficient storage of spent nuclear fuel at these facilities through license expiration.
In 2010,Projects to Add Additional Capacity
FPL is in the NRC amended its Waste Confidence Rule to supportprocess of adding the determination that licensees can safely store spent nuclear fuel at nuclear power plants for up to 60 years beyondfollowing additional capacity during the original and renewed licensed operating lifeterm of the plants. Several parties petitioned the U.S. Court of Appeals for the District of Columbia (D.C. Circuit) to challenge the revised rule and in 2012, the D.C.
Circuit vacated the rule and remanded it back to the NRC. The NRC determined that no final licenses would be issued until the required revisions to the Waste Confidence Rule are made, which revisions are not expected to be finalized before late 2014.
Nuclear Waste Policy Act of 1982, as amended (Nuclear Waste Policy Act) - Under the Nuclear Waste Policy Act, the DOE is responsible for the development of a repository for the disposal of spent nuclear fuel and high-level radioactive waste. As required by the Nuclear Waste Policy Act, FPL is a party to contracts with the DOE to provide for disposal of spent nuclear fuel from its nuclear units.
The DOE was required to construct permanent disposal facilities and take title to and provide transportation and disposal for spent nuclear fuel by January 31, 1998 for a specified fee based on current generation from nuclear power plants. The DOE did not meet its statutory obligation for disposal of spent nuclear fuel under the Nuclear Waste Policy Act. In 2009, FPL and certain of FPL's nuclear plant joint owners entered into a settlement2016 rate agreement (spent fuel settlement agreement) with the U.S. government agreeing to dismiss with prejudice lawsuits filed against the U.S. government seeking damages caused by the DOE's failure to dispose of spent nuclear fuel from FPL's nuclear plants. The spent fuel settlement agreement permits FPL to make annual filings to recover certain spent fuel storage costs incurred by FPL which are reimbursable by the U.S. government on an annual basis.
In a separate lawsuit filed in 2011, FPL joined the Nuclear Energy Institute and several other nuclear plant owners and operators (Petitioners) in petitioning the D.C. Circuit to challenge the DOE's decision to continue to collect the nuclear waste fee. In June 2012, the D.C. Circuit ruled, which ruling was confirmed in November 2013, that the DOE's fee adequacy determination was legally defective. In November 2013, the D.C. Circuit directed the DOE to submit a proposal to the U.S. Congress to change the fee to zero until the DOE complies with the Nuclear Waste Policy Act or until Congress enacts an alternative waste management plan. In January 2014, the DOE sent the court-mandated proposal to adjust the fee, subject to any further judicial decision in the proceeding, to the heads of both the U.S. Senate and the U.S. House of Representatives and, at the same time, filed a petition with the D.C. Circuit to rehear the matter. If a rehearing is granted, the D.C. Circuit’s earlier directive that the DOE submit a proposal to Congress for changing the fee to zero would be stayed, which decision on rehearing is expected in the first quarter of 2014. FPL will continue to pay fees to the U.S. government's nuclear waste fund pending Congressional approval of and implementation of a zero-fee proposal.
Yucca Mountain - In March 2010, the DOE filed a motion with the NRC to withdraw its license application for a nuclear waste repository at Yucca Mountain, which request was denied. In September 2011, the NRC issued an order suspending the Yucca Mountain licensing proceeding, which order was challenged, and in August 2013, the 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, the NRC is taking steps toward completing the technical review of the application and has requested the DOE to complete its supplemental environmental impact statement.
In light of its March 2010 motion not to proceed with the Yucca Mountain repository project, the DOE established a Blue Ribbon Commission on America's Nuclear Future (BRC) to conduct a comprehensive review of policies for managing the back end of the nuclear fuel cycle and to provide recommendations for developing a safe, long-term solution to managing spent nuclear fuel and high-level radioactive waste. In 2012, the BRC issued its report and recommendations which includes a consent-based approach to site future nuclear waste management facilities; creation of a new organization, independent of the DOE, dedicated solely to assuring the safe storage and ultimate disposal of spent nuclear fuel and high-level radioactive waste; providing access to the U.S. government's nuclear waste fund for the purpose of nuclear waste storage and disposal; and initiating prompt efforts to develop geologic disposal facilities, consolidated interim storage facilities and transportation to those facilities. In January 2013, the DOE issued a strategy document for implementing the BRC recommendations. The strategy document outlines, among other things, long-term plans for a new management organization to handle spent fuel storage and disposal activities, development of new interim storage facilities and several possible funding reforms, including accessing the nuclear waste fund for funding these activities. Each of these steps will require new federal legislation.
Nuclear Regulatory Developments.Based on the NRC's comprehensive review of processes and regulations relating to nuclear facilities in the U.S. following the 2011 earthquake and tsunami in Japan, the NRC established, among other things, actions to be completed at each nuclear site and issued various orders and requests for information with a prescribed timeline for implementation and completion by the end of 2016. The NRC continues to revise orders for, among other things, enhanced venting capabilities for boiling water reactors for which implementation is expected to go beyond 2016 (FPL's nuclear units do not use boiling water reactors; see NEER - Generation and Other Operations - Nuclear Facilities - Nuclear Regulatory Developments). FPL is currently working with the NRC on the approval and implementation of actions required to meet new NRC requirements. A portion of the costs for these actions is being recovered through base rates based on estimated costs for 2013, with any incremental costs being recovered through the capacity clause, all of which are included in estimated capital expenditures. In January 2014, the State of Florida Office of Public Counsel (OPC) filed a notice of appeal to the Florida Supreme Court of the FPSC’s final order regarding the recovery of the incremental costs through the capacity clause. In February 2014, the Florida Supreme Court granted the OPC's request to stay that appeal until it has ruled on the OPC's appeal of the FPSC's final order regarding the 2012 rate agreement. See FPL Regulation -(see FPL Rate Regulation - Cost Recovery Clauses belowBase Rates - Rates Effective January 2017 through December 2020 below):
an approximately 1,750 MW natural gas-fired combined-cycle unit in Okeechobee County, Florida (Okeechobee Clean Energy Center), with a planned in-service date of mid-2019; and Note 13 - Commitments.
up to 300 MW annually of new solar generation in each of 2017 through 2020.
The lessons learned from the events in Japan and the results of the NRC's actions have and will continue to, among other things, result in new licensing and safety-related requirements for U.S. nuclear facilities. Any new requirements could, among other things, impact future licensing and operations of U.S. nuclear facilities, including FPL's existing nuclear facilities and NRC approval of two
additional nuclear units at FPL's Turkey Point site, and could, among other things, result in increased cost and capital expenditures associated with the operation and maintenance of FPL's nuclear units.
Solar Operations
Solar generation can be provided primarily through two conventions: utility-owned and customer-owned or leased. In utility-owned solar generation, the energy generated goes directly to the transmission grid, whereas customer-owned or leased solar generation generally goes directly to the location it is serving with any excess over local need being fed back to the transmission grid. There are two principal solar technologies used for utility-scale projects: PV and thermal. At December 31, 2013, FPL owned and operated two PV solar generating facilities, which provided a total of 35 MW of generation capacity, and a 75 MW solar thermal hybrid facility. FPL supports the advancement of solar generation primarily for its fuel diversity and emissions reduction benefits, and plans to continue to support, study and pursue solar generation that is beneficial for FPL's customers.
Purchased Power
In addition to owning generation facilities, FPL also purchases electricity from non-utility generators and other utilities to meet customer demand through long- and short-term purchased power agreements. As of December 31, 2013, FPL's long-term purchased power agreements provided for the purchase of approximately 1,963 MW of power with expiration dates ranging from 2015 through 2032. See Note 13 - Contracts. FPL also procures short-term capacity for both economic and reliability purposes.
FPL ENERGY MARKETING AND TRADING
FPL's Energy Marketing & Trading division (EMT) buys and sells wholesale energy commodities, such as natural gas, oil and electricity. EMT procures natural gas and oil for FPL's use in power generation and sells excess natural gas, oil and electricity. Prior to January 2017, EMT also useshad utilized derivative instruments (primarily swaps, options and forwards) to manage the commodity price risk inherent in the purchase and sale of fuel and electricity. Under the 2016 rate agreement that is effective beginning January 2017 and discussed below, EMT will not enter into any new derivative instruments to manage its commodity price risk for the term of the 2016 rate agreement. Substantially all of the results of EMT's activities are passed through to customers in the fuel or capacity clauses. See FPL Regulation - FPL Rate Regulation below, Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity and Note 3.
FPL REGULATION
FPL's operations are subject to regulation by a number of federal, state and other organizations, including, but not limited to, the following:
the FPSC, which has jurisdiction over retail rates, service territory, issuances of securities, planning, siting and construction of facilities, among other things;
the FERC, which oversees the acquisition and disposition of generation, transmission and other facilities, transmission of electricity and natural gas in interstate commerce, proposals to build and operate interstate natural gas pipelines and storage facilities, and wholesale purchases and sales of electric energy, among other things;
the NERC, which, through its regional entities, establishes and enforces mandatory reliability standards, subject to approval by the FERC, to ensure the reliability of the U.S. electric transmission and generation system and to prevent major system blackouts;
the NRC, which has jurisdiction over the operation of nuclear power plants through the issuance of operating licenses, rules, regulations and orders; and
the EPA, which has the responsibility to maintain and enforce national standards under a variety of environmental laws. The EPA also works with industries and all levels of government, including federal and state governments, in a wide variety of voluntary pollution prevention programs and energy conservation efforts.
FPL Rate Regulation
The FPSC sets rates at a level that is intended to allow FPL the opportunity to collect from retail customers total revenues (revenue requirements) equal to FPL's cost of providing service, including a reasonable rate of return on invested capital. To accomplish this, the FPSC uses various ratemaking mechanisms, including, among other things, base rates and cost recovery clauses.
Base Rates. In general, the basic costs of providing electric service, other than fuel and certain other costs, are recovered through base rates, which are designed to recover the costs of constructing, operating and maintaining the utility system. These basic costs include O&M expenses, depreciation and taxes, as well as a return on FPL's investment in assets used and useful in providing electric service (rate base). At the time base rates are determined,established, the allowed rate of return on rate base approximates the FPSC's determination of FPL's estimated weighted-average cost of capital, which includes its costs for outstanding debt and an allowed ROE. The FPSC monitors FPL's actual regulatory ROE through a surveillance report that is filed monthly by FPL with the FPSC. The FPSC does not provide assurance that any regulatory ROE will be achieved. Base rates are determined in rate proceedings or through negotiated settlements of those proceedings. Proceedings can occur at the initiative of FPL or upon action by the FPSC. Base rates remain in effect until new base rates are approved by the FPSC.
Rates Effective January 2013 -2017 through December 20162020 - In January 2013,December 2016, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012(2016 rate agreement). Key elements of the 20122016 rate agreement, which is effective from January 20132017 through at least December 2016,2020, include, among other things, the following:
New retail base rates and charges were established in January 2013 resulting in an increasethe following increases in annualized retail base revenuesrevenues:
| |
| ◦ | $400 million beginning January 1, 2017; |
| |
| ◦ | $211 million beginning January 1, 2018; and |
| |
| ◦ | $200 million when the Okeechobee Clean Energy Center achieves commercial operation, which is expected to occur in mid-2019. |
In addition, FPL is eligible to receive, subject to conditions specified in the 2016 rate agreement, base rate increases associated with the addition of $350 million onup to 300 MW annually of new solar generation in each of 2017 through 2020 and may carry forward any unused MW to subsequent years during the term of the 2016 rate agreement. FPL will be required to demonstrate that any proposed solar facilities are cost effective and scheduled to be in service before December 31, 2021. FPL has agreed to an annualized basis.installed cost cap of $1,750 per kW.
FPL's allowed regulatory ROE is 10.50%10.55%, with a range of plus or minus 100 basis points.9.60% to 11.60%. If FPL's earned regulatory ROE falls below 9.50%9.60%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.50%11.60%, any party to the 2012 rate agreement other than FPL may seek a review of FPL's retail base rates.
Retail base rates will be increased by the annualized base revenue requirements for FPL's three modernization projects (Cape Canaveral, Riviera Beach and Port Everglades) as each of the modernized power plants becomes operational. (Cape Canaveral became operational in April 2013 and Riviera Beach and Port Everglades are expected to be operational in the second quarter of 2014 and by mid-2016, respectively.)
Cost recovery of WCEC Unit No. 3, which was placed in service in May 2011, will continue to occur through the capacity clause; however, such recovery will not be limited to the projected annual fuel cost savings as was the case in the previous rate agreement discussed below.
Subject to certain conditions, FPL may amortize, over the term of the 20122016 rate agreement, aup to $1.0 billion of depreciation reserve surplus plus the reserve amount remaining at the end ofunder FPL's 2012 under the 2010 rate agreement discussed below (approximately $224$250 million) and may amortize a portion of FPL's fossil dismantlement reserve up to a maximum of $176 million (collectively, the reserve), provided that in any year of the 20122016 rate agreement, FPL must amortize at least enough reserve to maintain a 9.50%9.60% earned regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 11.50%11.60%.
Future storm restoration costs would be recoverable on an interim basis beginning 60 days from the filing of a cost recovery petition, but capped at an amount that could produce a surcharge of no more than $4 for every 1,000 kWh of usage on residential bills during the first 12 months of cost recovery. Any additional costs would be eligible for recovery in subsequent years. If storm restoration costs exceed $800 million in any given calendar year, FPL may request an increase to the $4 surcharge to recover the amountamounts above $800$400 million.
An
In January 2017, the Sierra Club filed a notice of appeal challenging the FPSC’s final order approving the 2016 rate agreement, which notice of appeal is pending before the Florida Supreme Court.
Rates Effective January 2013 through December 2016 - Effective January 2013, pursuant to an FPSC final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement), new retail base rates and charges for FPL were established resulting in an increase in retail base revenues of $350 million on an annualized basis. The 2012 rate agreement, provided for, among other things, the following:
•a regulatory ROE of 10.50% with a range of plus or minus 100 basis points;
an increase in annualized base revenue requirements as each of three FPL modernized power plants became operational in April 2013, April 2014 and April 2016;
the continuation of cost recovery through the capacity clause (reported as retail base revenues) for a generating unit which was placed in service in May 2011 (beginning January 2017, under the 2016 rate agreement, cost recovery will be through base rates);
subject to certain conditions, the right to reduce depreciation expense up to $400 million (reserve), provided that in any year of the 2012 rate agreement, FPL was required to amortize enough reserve to maintain an earned regulatory ROE within the range of 9.50% to 11.50% (see below regarding a subsequent reduction in the reserve amount);
an interim cost recovery mechanism for storm restoration costs (see Note 1 - Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve); and
an incentive mechanism whereby customers will receive 100% of certain gains, including but not limited to gains from the purchase and sale of electricity and natural gas (including transportation and storage), up to a specified threshold; gains exceeding that specified threshold will bewere shared by FPL and its customers.
In September 2013, the Florida Supreme Court heard oral argument on the OPC's appeal of the FPSC's final order regarding the 2012 rate agreement. A ruling by the Florida Supreme Court is pending.
Rates Effective March 2010 - December 2012 - Effective March 1, 2010, pursuant to an FPSC final order (2010 FPSC rate order), new retail base rates for FPL were established, resulting in an increase in retail base revenues of approximately $75 million on an annualized basis. The 2010 FPSC rate order, among other things, also established a regulatory ROE of 10.0% with a range of plus or minus 100 basis points. In February 2011,August 2015, the FPSC issued a final order approvingapproved a stipulation and settlement agreement between the Office of Public Counsel and FPL and principal partiesregarding issues relating to the ratemaking treatment for FPL’s purchase of a 250 MW coal-fired generation facility located in FPL's 2009 rate case (2010 rate agreement). The 2010 rate agreement,Jacksonville, Florida (Cedar Bay generation facility), which was effective throughFPL retired in December 31, 2012, provided for, among other things, a reduction in depreciation expense (surplus depreciation credit) in any calendar year up to a cap in 20102016. As part of $267 million, a cap in subsequent years of $267 million plus the amount of any unused portion from prior years, and a total cap of $776 million over the course of the 2010 rate agreement, provided that in any year of the 2010 rate agreement FPL was required to use enough surplus depreciation credit to maintain an earned regulatory ROE within the range of 9.0% - 11.0%. The 2010 rate agreement also permitted incremental cost recovery through FPL's capacity clause for WCEC Unit No. 3 up tothis settlement, the amount of the projected annual fuel savings for customers. See Cost Recovery Clauses below for additional information regarding the capacity clause.reserve was reduced by $30 million to $370 million.
Cost Recovery Clauses. Cost recovery clauses which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through the various clauses, include substantially all fuel, purchased power and interchange costs, certain construction-related costs and conservation and certain environmental-related costs.clauses. Cost recovery clause costs are recovered through levelized monthly charges per kWh or kW, depending on the customer's rate class. These cost recovery clause charges are calculated at least annually based on estimated costs and estimated customer usage for the following year, plus or minus true-up adjustments to reflect the estimated over or under recovery of costs for the current and prior periods. An adjustment to the levelized charges may be approved during the course of a year to reflect revised estimates. FPL recovers costs from customers through the following clauses:
Fuel - fuel costs are recovered from customers through the fuel clause,and energy charges relating to purchased power agreements, the most significant of the cost recovery clauses in terms of operating revenues. FPL uses a risk management fuel procurement program which has been approved by the FPSC. The FPSC reviews the program activities and results for prudence annually as part of its review of fuel costs. The program is intended to manage fuel price volatility by locking in fuel prices for a portion of FPL's fuel requirements. See FPL Energy Marketing and Trading above,revenues (see Note 1 - Regulation and Note 3.
Rate Regulation);
Capacity - primarily capacity payments to non-utility generators and other utilities and non-utility generators for purchased power are recovered from customers through the capacity clause. In accordancecertain costs associated with the FPSC's nuclear cost recovery rule, FPL also recovers pre-construction costs and carrying charges (equal to a pretax AFUDC rate) on construction costs for new nuclear capacity through the capacity clause. As property related to the new nuclear capacity goes into service, construction costs and a return on investment are recovered through base
rate increases effective beginning the following January. See FPL Sources of Generation - Nuclear Operations above. In January 2014, FPL began recovering, through the capacity clause, the incremental costs incurred to comply with new NRC requirements established following the 2011 earthquake and tsunami in Japan. See FPL Sources of Generation - Nuclear Operations - Nuclear Regulatory Developments above. In accordance with the 2012 and 2010 rate agreements, cost recovery for WCEC Unit No. 3 is permitted during the termacquisition of the agreements through FPL's capacity clause and is reported as retail base revenues.Cedar Bay generation facility (see Note 1 - Rate Regulation);
CostsEnergy Conservation - costs associated with implementing energy conservation programs are recovered from customers through the energy conservation cost recovery clause. Certainprograms; and
Environmental - certain costs of complying with federal, state and local environmental regulations enacted after April 1993 and costs associated with three of FPL's three solar facilities are recovered through the environmental cost recovery clause (environmental clause).facilities.
The FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. These costs may include, among others, fuel and O&M expenses, the cost of replacing power lost when fossil and nuclear units are unavailable, storm restoration costs and costs associated with the construction or acquisition of new facilities.
FERC
The Federal Power Act givesgrants the FERC exclusive ratemaking jurisdiction over wholesale sales of electricity and the transmission of electricity and natural gas in interstate commerce. Pursuant to the Federal Power Act, electric utilities must maintain tariffs and rate schedules on file with the FERC which govern the rates, terms and conditions for the provision of FERC-jurisdictional wholesale power and transmission services. The Federal Power Act also gives the FERC authority to certify and oversee a national electric reliability organization with authority to developestablish and independently enforce mandatory reliability standards applicable to all users, owners and operators of the bulk-power system. The FERC also approves and enforces reliability standards. See NERC below. Electric utilities are subject to accounting, record-keeping and reporting requirements administered by the FERC. The FERC also places certain limitations on transactions between electric utilities and their affiliates.
NERC
The NERC has been certified by the FERC as the national electric reliability organization. The NERC's mandate is to ensure the reliability and security of the North American bulk-power system through the establishment and enforcement of reliability standards.standards approved by FERC. The NERC's regional entities establish requirements,also enforce reliability standards approved by the FERC, for reliable operation and maintenance of power generation facilities and transmission systems.FERC. FPL is subject to these reliability requirementsstandards and incurs costs to ensure compliance with continually heightened requirements, and can incur significant penalties for failing to comply with them.
FPL Environmental Regulation
FPL is subject to environmental laws and regulations and is affected by some of the emerging issuesas described in the NEE Environmental Matters section below. FPL expects to seek recovery through the environmental clause for compliance costs associated with any new environmental laws and regulations.
As part of the conditions of certification by the FDEP for the generation uprate project at the Turkey Point nuclear units, which was completed in 2013, FPL was required to implement a monitoring plan in and around the Turkey Point cooling canals due to concerns over potential saltwater intrusion beyond FPL's property. Monitoring under the plan includes collection of data prior to and after the additional capacity is placed in service. Data for the first three years has been collected and provided to the FDEP and other agencies. The ultimate outcome of the monitoring plan is uncertain, and the financial and operational impacts on FPL, if any, cannot be determined at this time.
FPL EMPLOYEES
FPL had approximately 8,900 employees at December 31, 2013.2016. Approximately 33%34% of the employees are represented by the International Brotherhood of Electrical Workers (IBEW) under a collective bargaining agreement with FPL that expires October 31, 2014.2017.
II. NEER
NEER, a limited liability company organized under the laws of Delaware, was formed in 1998 to aggregate NEE's competitive energy businesses. ItNEER is a limited liabilitydiversified clean energy company organized underwith a business strategy that emphasizes the lawsdevelopment, acquisition and operation of Delaware and islong-term contracted assets with a wholly-owned subsidiary of NEECH.focus on renewable projects. Through its subsidiaries, NEER currently owns, develops, constructs, manages and operates electric generatinggeneration facilities in wholesale energy markets primarily in the U.S., as well
as in Canada and Spain. See Note 14.14 for information on revenues from foreign sources and long–lived assets located in foreign countries. NEER, with approximately 19,882 MW of generating capacity at December 31, 2016, is one of the largest wholesale generators of electric power in the U.S., with approximately 18,30318,862 MW of generating capacity across 2429 states, and has 920 MW of generating capacity in 4 Canadian provinces and 1 Spanish province as99.8 MW of December 31, 2013.generating capacity in Spain. NEER produces the majority of its electricity from clean and renewable sources as described more fully below. NEER is the largest ownergenerator in the world of electric power from wind and utility-scaleuniversal solar energy projects in North America. Since 2002,based on 2016 MWh produced. NEER has more than doubled its generating capacity, primarily through the developmentalso owned and operated approximately 200 substations and 1,240 circuit miles of new wind projects and the acquisition of nuclear projects.
NEER also engages in power and gasenergy-related commodity marketing and trading activities, including entering into financial and physical contracts, to hedge the production from its generatinggeneration assets that is not sold under long-term power supply agreements. These activitiescontracts primarily include providingpower and gas commodities and their related products, as well as provide full energy and capacity requirements services primarily to distribution utilities in certain markets and offeringoffer customized power and gas and related risk management services to wholesale customers. In addition, NEER also participates in natural gas, natural gas liquids and oil production primarily through non-operating ownership interests, and in pipeline infrastructure development, construction, management and operations, through either wholly owned subsidiaries or noncontrolling or joint venture interests, hereafter referred to as the gas infrastructure business, and owns a retail electricity provider.business. NEER also hedges the expected output from its gas infrastructure production assets to protect against price movements.
MARKETS AND COMPETITION
Electricity marketsAs discussed in the U.S. are regionalOverview above, during 2014, NEP was formed to acquire, manage and diverse in character. All are extensively regulated, and competition in these markets is shaped and constrained by regulation. The nature of the products offered varies based on the specifics of regulation in each region. Generally, in addition to the natural constraints on pricing freedom presented by competition, NEER may also face specific constraints in the form of price caps, or maximum allowed prices, for certain products. NEER's ability to sell the output of its generation facilities is also constrained by available transmission capacity, which can vary from time to time and can have a significant impact on pricing.
The degree and nature of competition that NEER faces is different in wholesale markets and in retail markets. Approximately 90% of NEER's revenue is derived from wholesale markets.
Wholesale power generation is a capital-intensive, commodity-driven businessown contracted clean energy projects with numerous industry participants. NEER primarily competes on the basis of price, but believes the green attributes of NEER's generating assets, its creditworthiness and its ability to offer and manage customized risk solutions to wholesale customers are competitive advantages. Wholesale power generation is a regional business that is highly fragmented relative to many other commodity industries and diverse in terms of industry structure. As such, there is a wide variation in terms of the capabilities, resources, nature and identity of the companies NEER competes with depending on the market. In wholesale markets, customers' needs are metstable, long-term cash flows through a varietylimited partner interest in NEP OpCo. Through an indirect wholly owned subsidiary, NEE owns 101,440,000 common units of means, including long-term bilateral contracts, standardized bilateral products such as full requirements service and customized supply and risk management services.
In general, U.S. electricity markets encompass three classesNEP OpCo representing a noncontrolling interest in NEP's operating projects of product: energy, capacity and ancillary services. Energy services relate to the physical delivery of power; capacity services relate to the availability of MW capacity of a power generation asset; and ancillary services are other services related to power generation assets, such as load regulation and spinning and non-spinning reserves. The exact nature of these classes of product is defined in part by regional tariffs. Not all regions have a capacity product class, and the specific definitions of ancillary services vary from region to region.
RTOs and ISOs exist in a number of regions within which NEER operates to coordinate generation and transmission across wide geographic areas and to run markets. NEER also has operations that fall within the Western Electricity Coordinating Council reliability region that are not under the jurisdiction of an established RTO or ISO. Although each RTO and ISO may have differing objectives and structures, some benefits of these entities include regional planning, managing transmission congestion, developing larger wholesale markets for energy and capacity, maintaining reliability and facilitating competition among wholesale electricity providers. NEER has operations that fall within the following RTOs and ISOs:
Alberta Electric System Operator
California Independent System Operator
ERCOT
Independent Electricity System Operator (in Ontario)
ISO New England (ISO-NE)
Midcontinent Independent System Operator, Inc. (MISO)
New York Independent System Operator (NYISO)
PJM
Southwest Power Pool
NEER competes in different regions to different degrees, but in general it seeks to enter into long-term bilateral contracts for the full output of its generating facilities, and,approximately 65.2% as of December 31, 2013, approximately 62%2016.NEE owns a controlling general partner interest in NEP and consolidates NEP for financial reporting purposes. See Note 1 - NextEra Energy Partners, LP. As of December 31, 2016, NEP, through the combination of NEER's generating capacity is fully committed under long-term contracts. Where long-term contracts are notcontribution of energy projects to NEP OpCo in effect,connection with NEP’s IPO in July 2014 and the acquisition of additional energy projects from NEER sells the outputin 2015 and 2016, owns, or has an interest in, a portfolio of its facilities into daily spot markets. In such cases, NEER will frequently enter into shorter term bilateral contracts, typically but not always of one to three years duration, to hedge the price risk associated with selling into a daily spot market. Such bilateral contracts, which may be hedges either for physical delivery or for financial (pricing) offset, may only protect a portion of the revenue that NEER expects to derive from the associated generation facility and may not qualify for hedge accounting under GAAP. Contracts that serve the economic purpose of hedging some portion of the expected revenue of a generation facility but are not recorded as hedges under GAAP are referred to as “non-qualifying hedges” for adjusted earnings purposes. See Management's Discussion - Overview - Adjusted Earnings.
Certain facilities within the NEER22 wind and solar generation portfolio produce RECsprojects with generating capacity totaling approximately 2,787 MW and other environmental attributes which are typically sold alonglong-term contracted natural gas pipeline assets as discussed below. In addition in 2015, NEP OpCo issued 2 million NEP OpCo Class B Units to NEER in exchange for an approximately 50% ownership interest in three solar projects with a total generating capacity of 277 MW. NEER, as holder of the energy fromClass B Units, will retain 100% of the plants under long-term contracts. Foreconomic interests if, and until, NEER offers to sell the economic interests to NEP and NEP accepts such offer. NEP OpCo has a right of first offer for certain of NEER's assets (ROFO assets) if NEER should seek to sell the assets. The ROFO assets remaining as of December 31, 2016, include contracted wind and solar generation not sold underprojects with a combined capacity of approximately 1,076 MW. In 2015, NEP completed the acquisition of the membership interests in NET Holdings Management, LLC (Texas pipeline business), a developer, owner and operator of a portfolio of seven intrastate long-term contracted natural gas pipeline assets located in Texas (Texas pipelines). See Generation and Other Operations - Contracted, Merchant and Other Operations - Other Operations below.
long-term contracts, the RECs and other environmental attributes may be sold separately.
While the majority of NEER's revenue is derived from the output of its generating facilities, NEER is also an active competitor in several regions in the wholesale full requirements business and in providing structured and customized power and fuel products and services to a variety of customers. In the full requirements service, typically, the supplier agrees to meet the customer's needs for a full range of products for every hour of the day, at a fixed price, for a predetermined period of time, thereby assuming the risk of fluctuations in the customer's volume requirements.
The deregulated retail energy business is typically a highly competitive business. In general, competition in the retail energy business is on the basis of price, service, brand image, product offerings and market perceptions of creditworthiness. Electricity is sold pursuant to a variety of product types, including fixed, indexed and renewable products, and customers elect terms of service typically ranging from one month to five years. Retail energy rates are market-based, and not subject to traditional cost-of-service regulation by public service commissions. Transmission and distribution service companies provide, on a non-discriminatory basis, the wires and metering services necessary to deliver service to customers. Subsidiaries of NEER compete in certain states for retail customers, which can be divided into two principal segments: residential and commercial and industrial (C&I). Residential customers largely require only energy services, which may be purchased on a month-to-month basis or under a multi-year contract. Large C&I customers share many of the same characteristics as wholesale utility customers and may require similarly customized and structured products.
In general, competitive retail electric providers are exposed to both volume and price risk: customers' volumes will vary, and competitive retail providers are committed to supplying the customer's full needs at all times and are therefore responsible for purchases in wholesale markets to meet those needs; and wholesale prices will fluctuate in ways that do not necessarily match the retail prices committed to the customer.
Expanded competition in a frequently changing regulatory environment presents both opportunities and risks for NEER. Opportunities exist for the selective acquisition of generation assets and for the construction and operation of efficient facilities that can sell power in competitive markets. NEER seeks to reduce its market risk by having a diversified portfolio by fuel type and location, as well as by contracting for the future sale of a significant amount of the electricity output of its facilities.
GENERATION AND OTHER OPERATIONS
The vast majority of NEER's revenue is derived from selling theNEER sells products associated with its own generation facilities (energy, capacity, RECsrenewable energy credits (RECs) and ancillary services) produced by its own generating facilities. However,in competitive markets in regions where those facilities are located. Customer transactions may be supplied from NEER may combinegeneration facilities or from purchases of relevant products in the wholesale markets, with products produced by its own generating facilities in order to meet particular customers' needs.or from a combination thereof. See Markets and Competition below.
At December 31, 2013, the locations of NEER's generation facilities in North America are as follows:
At December 31, 2013,2016, NEER managed or participated in the management of essentially all of its generation projects and all of its natural gas pipeline assets in which it has an ownership interest. At December 31, 2016, the locations of NEER's generation facilities and natural gas pipeline assets in North America were as follows:
NEER categorizes its portfolio in a number
Contracted, Merchant and Other Operations
NEER's portfolio of generation operations based on the presence/absence of long-term contractspower sales agreements and other operations is described below.was as follows:
Contracted Generation Assets. Contracted generation assets are projectsgeneration facilities with long-term power sales agreements for substantially all of their output and certain windcapacity and/or energy output. Information related to contracted generation assets where long-term power contracts are expected to be executed. Atas of December 31, 2013, NEER had 11,5622016 was as follows:
represented approximately 15,994 MW of contracted assets, substantially all of which have long-term power contracts. Essentially all of the output of these contracted assets were under power sales agreements, with a weighted-averagegenerating capacity;
weighted average remaining contract lifeterm of approximately 1517 years, based on forecasted contributions to earnings; and
contracts for the supply of uranium and somethe conversion, enrichment and fabrication of nuclear fuel have firm fuel and transportation agreements with expiration dates ranging from March 2014late February 2017 through 2022. See2032 (see Note 13 - Contracts. Approximately 8,366 MWContracts).
Merchant Generation Assets. Merchant generation assets are projectsgeneration facilities that do not have long-term power sales agreements to sell their output, capacity and/or in the case of certain wind assets, are not expected to have long-term power contracts,energy output and therefore require active marketing and hedging. AtInformation related to merchant generation assets as of December 31, 2013, NEER's portfolio of merchant assets consists of 6,7412016 was as follows:
represented approximately 3,888 MW of owned wind, nuclear, natural gas, oil and solar generating facilities,capacity, including 846781 MW of oil-fired peak generating facilities. Approximately 60% (based on net MW capacity)generation facilities;
primarily located in Texas and the Northeast regions of the natural gas-fueled merchant assetsU.S.;
contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel have natural gas transportation agreements to provide for fluctuating natural gas requirements. Seeexpiration dates ranging from August 2017 through 2029 (see Note 13 - Contracts. Derivative instruments (primarilyContracts); and
utilize swaps, options, futures and forwards) are generally usedforwards to lock in pricing and manage the commodity price risk inherent in power sales and fuel purchases. Managing market risk through these instruments introduces other types of risk, primarily counterparty, credit and operational risks.
Other Operations.
Other Operations.Gas Infrastructure Business NEER's operations also include the gas infrastructure business and the customer supply and proprietary power and gas trading businesses.- At December 31, 2013,2016, NEER had approximately $3.5 billion invested in the natural gas infrastructure business had non-operatingpipelines discussed below and ownership interests in investments located in oil and gas shale formations primarily in Texas, Oklahoma, Wyoming, North Dakotathe Midwest and Louisiana. Also, see NEER South regions of the U.S.
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| | | | | | | | | |
| | Miles of Pipeline | | Pipeline Location/Route | | NEER's Ownership | | Total Capacity (per day) | | Actual/Expected In-Service Dates |
| Operational: | | | | | | | | | |
Texas Pipelines(a) | 542 | | South Texas | | 61.6% | | 4.05 Bcf | | 1950 - 2014 |
| Under Construction or In Development: | | | | | | | | | |
Sabal Trail(b) | 515 | | Southwestern Alabama to Central Florida | | 42.5% | | 0.83 Bcf - 1.075 Bcf | | Mid-2017 - Mid-2021 |
Florida Southeast Connection(b) | 126 | | Central Florida to Martin County, Florida | | 100% | | 0.64 Bcf | | Mid-2017 |
Mountain Valley Pipeline(c) | 301 | | Marcellus and Utica shale regions to markets in the Mid-Atlantic and Southeast regions of the U.S. | | 31% | | 2.00 Bcf | | End of 2018 |
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| |
| (a) | A portfolio of seven natural gas pipelines, of which a third party owns a 10% interest in a 120 mile pipeline with a daily capacity of approximately 2.3 Bcf. The pipelines have a total existing capacity of approximately 4 Bcf per day, of which 3 Bcf per day is contracted with firm ship-or-pay contracts that have a weighted-average remaining contract life of approximately 14 years. |
| |
| (b) | See FPL - FPL Sources of Generation - Fuel Sources - Significant Fuel Contracts and Note 13 - Commitments and - Contracts. |
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| (c) | Construction of the natural gas pipeline is subject to certain conditions, including FERC approval. See Note 13 - Commitments. |
Customer Supply and Proprietary Power and Gas Trading below.- NEER provides commodities-related products to customers, engages in energy-related commodity marketing and trading activities and includes the operations of a retail electricity provider. Through its subsidiary PMI, NEER:
manages risk associated with fluctuating commodity prices and optimizes the value of NEER's power generation and gas infrastructure production assets through the use of swaps, options, futures and forwards;
sells output from NEER's plants that is not sold under long-term contracts and procures fossil fuel for use by NEER's generation fleet;
provides full energy and capacity requirements to customers; and
markets and trades energy-related commodity products and provides a wide range of electricity and fuel commodity products as well as marketing and trading services to customers.
NEER Fuel/Technology Mix
NEER's generating output is produced using a varietyNEER owns and operates the majority of its generation facilities, which utilize the following mix of fuel sources as further described below.sources:
NEER's power generation in terms of MWh produced for the year ended December 31, 2013 by fuel type is as follows:
Wind Facilities
At December 31, 2013, NEER had ownership interests in wind generating facilities withand operated a total net generating capacity of 10,210 MW. NEER operates all of these wind facilities, which are 13,852 MW at December 31, 2016;
located in 1920 states in the U.S. and 4 provinces in Canada. During 2013, NEER Canada;
approximately 12,008 MW is from contracted wind assets located primarily throughout the West and Midwest regions of the U.S. and Canada;
approximately 1,844 MW is from merchant wind assets located in Texas;
added approximately 250 MW of new U.S. wind generation and 124 MW of new Canadian wind generation and sold wind facilities with generation capacity totaling 223 MW located in Wyoming and California. NEER is currently committed to add new wind generation in 2014 and 2015 totaling approximately 465 MW in Canada and 1,1751,465 MW in the U.S. Seein 2016; and
expects to add new contracted wind generation of approximately 2,400 to 4,100 MW and approximately 1,600 MW of additional repowering generation within the existing U.S. wind portfolio in 2017 to 2018 (see Policy Incentives for Renewable Energy Projects below for additional discussion of NEER's expectations regarding wind development, construction and construction.retrofitting).
Natural Gas Facilities
At December 31, 2013, NEER had ownership interests in natural gas facilities with net generating capacity (NEER's net ownership interest in facility capacity) of 3,991 MW. NEER operates all of these facilities and approximately 1,003 MW of net generating capacity is from contracted natural gas assets located throughout the Northeastern U.S.
Nuclear Facilities
At December 31, 2013, NEER owned, or had undivided interests in, and operated the following four nuclear units with a total net generating capacity of 2,721 MW.
|
| | | | | | | | | | |
| Facility | | Location | | MW | | Portfolio Category | | Operating License Expiration Dates |
| Seabrook | | New Hampshire | | 1,100 |
| | Merchant | | 2030 | (a) |
| Duane Arnold | | Iowa | | 431 |
| | Contracted(b) | | 2034 | |
| Point Beach Unit No. 1 | | Wisconsin | | 595 |
| | Contracted(c) | | 2030 | |
| Point Beach Unit No. 2 | | Wisconsin | | 595 |
| | Contracted(c) | | 2033 | |
______________________
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(a) | In 2010, NEER filed an application with the NRC to renew Seabrook's operating license for an additional 20 years, which license renewal is dependent on various NRC regulatory approvals and actions. |
| |
(b) | NEER sells all of its share of the output of Duane Arnold under a long-term contract expiring in February 2025. |
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(c) | NEER sells all of the output of Point Beach Units Nos. 1 and 2 under long-term contracts through their current operating license expiration dates. |
NEER's nuclear facilities have several contracts for the supply of uranium and conversion, enrichment and fabrication of nuclear fuel with expiration dates ranging from March 2014 through 2022. See Note 13 - Contracts. NEER is responsible for all nuclear unit operations and the ultimate decommissioning of the nuclear units, the cost of which is shared on a pro-rata basis by the joint owners for the jointly-owned units. NRC regulations require plant owners to submit a plan for decontamination and decommissioning five years before the projected end of plant operation.
Nuclear Unit Scheduled Refueling Outages. NEER's nuclear units are periodically removed from service to accommodate normal refueling and maintenance outages, including inspections, repairs and certain other modifications. Scheduled nuclear refueling outages typically require the unit to be removed from service for variable lengths of time. The following table summarizes each unit's next scheduled refueling outage:
|
| | |
Facility | | Next Scheduled
Refueling Outage
|
Seabrook | | April 2014 |
Duane Arnold | | October 2014 |
Point Beach Unit No. 1 | | October 2014 |
Point Beach Unit No. 2 | | March 2014 |
Spent Nuclear Fuel. NEER's nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which are expected to provide sufficient storage of spent nuclear fuel at these facilities through license expiration.
As owners and operators of nuclear facilities, certain subsidiaries of NEER are subject to the Nuclear Waste Policy Act and are parties to the spent fuel settlement agreement and legal actions described in FPL - FPL Sources of Generation - Nuclear Operations. Similar to FPL, these subsidiaries will continue to pay fees to the U.S. government's nuclear waste fund pending Congressional approval of and implementation of a zero-fee proposal.
Nuclear Regulatory Developments. For discussion of developments regarding the impact of the 2011 earthquake and tsunami in Japan as it relates to U.S. nuclear facilities, see FPL - FPL Sources of Generation - Nuclear Operations. NEER's nuclear facilities are subject to the same NRC actions as described for FPL. Duane Arnold is NEER's only boiling water reactor unit. NEER is currently working with the NRC on the approval and implementation of actions required to meet new NRC requirements, the costs of which are included in estimated capital expenditures. See Note 13 - Commitments.
Solar Facilities
At December 31, 2013, NEER had ownership interests in and operated the majority of PV and solar thermal facilities with a total net generating capacity of 4772,108 MW at December 31, 2016;
located in 11 states in the U.S., 1 province in Canada and 1 province in Spain;
essentially all MW is from contracted solar facilities located primarily throughout the West region of the U.S.;
added approximately 980 MW in the U.S. in 2016; and
expects to add new contracted solar generation of approximately 400 to 1,300 MW in 2017 to 2018.
Fossil Facilities
ownership interests in and Canada. During 2013, NEER added 125 MW of capacity from a 250 MW solar thermal project in California (Genesis solar project) and 155 MW of net capacity from a 550 MW solar PV project in California (Desert Sunlight solar project), in which NEER has a 50% equity investment. The remaining capacity for the Genesis solar project (125 MW) and the Desert Sunlight solar project (120 MW) are expected to be added during 2014. In addition, NEER and its affiliates completed construction of solar thermaloperated natural gas generation facilities with a total net generating capacity of 99.8420 MW at December 31, 2016; approximately 262 MW is contracted and 158 MW is merchant; located in Spain (Spain solar projects) during 20133 states in the Northeast region of the U.S.;
completed the sales of its ownership interests in merchant natural gas generation facilities located in Texas with a total generating capacity of 2,884 MW and in natural gas generation facilities located primarily in Pennsylvania with a total generating capacity of 840 MW (see Note 131 - Spain Solar ProjectsAssets and Liabilities Associated with Assets Held for additional developments that impact the Spain solar projects).Sale); and
owned, or had undivided interests in, and operated oil-fired peak generation facilities with a total generating capacity of 781 MW at December 31, 2016 primarily located in Maine.
Nuclear Facilities
At December 31, 2016, NEER owned, or had undivided interests in, and operated the following four nuclear units with a total net generating capacity of 2,721 MW. NEER's nuclear units are periodically removed from service to accommodate planned refueling and maintenance outages, including inspections, repairs and certain other modifications. Scheduled nuclear refueling outages
Other Assetstypically require the unit to be removed from service for variable lengths of time.
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| | | | | | | | | | |
| Facility | | Location | | NEER's Ownership (MW) | | Portfolio Category | | Next Scheduled Refueling Outage | | Operating License Expiration Dates |
| Seabrook | | New Hampshire | | 1,100 | | Merchant | | April 2017 | | 2030(a) |
| Duane Arnold | | Iowa | | 431 | | Contracted(b) | | September 2018 | | 2034 |
| Point Beach Unit No. 1 | | Wisconsin | | 595 | | Contracted(c) | | October 2017 | | 2030 |
| Point Beach Unit No. 2 | | Wisconsin | | 595 | | Contracted(c) | | March 2017 | | 2033 |
______________________
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| (a) | In 2010, NEER filed an application with the NRC to renew Seabrook's operating license for an additional 20 years, which license renewal is dependent on NRC regulatory approvals. |
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| (b) | NEER sells all of its share of the output of Duane Arnold under a long-term contract expiring in December 2025. |
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| (c) | NEER sells all of the output of Point Beach Units Nos. 1 and 2 under long-term contracts through their current operating license expiration dates. |
NEER is responsible for all nuclear unit operations and the ultimate decommissioning of the nuclear units, the cost of which is shared on a pro-rata basis by the joint owners for the jointly-owned units. NRC regulations require plant owners to submit a plan for decontamination and decommissioning five years before the projected end of plant operation.
At December 31, 2013, NEER had 804 MWNEER's nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which are expected to provide sufficient storage of other generation assets, primarily oilspent nuclear fuel at these facilities located in Maine. During 2013, NEER initiated a plan and received internal approval to pursue the sale of its ownership interests in the oil-fired generating plants located in Maine with a total capacity of 796 MW. In the first quarter of 2013, a subsidiary of NEER completed the sale of its ownership interest in a portfolio of hydropower generation plants and related assets with a total generating capacity of 351 MW located in Maine and New Hampshire.through license expiration.
Policy Incentives for Renewable Energy Projects
In itsU.S. federal, state and local governments have established various incentives to support the development of renewable energy projects. These incentives include accelerated tax depreciation, PTCs, ITCs, cash grants, tax abatements and operationRPS programs. Wind and solar projects qualify as five-year property that is eligible to be depreciated under the U.S. federal Modified Accelerated Cost Recovery System (MACRS). Pursuant to MACRS, wind and solar projects are fully depreciated for tax purposes over a five-year period even though the useful life of U.S.such projects is generally much longer than five years.
Owners of utility-scale wind generation facilities NEER depends heavily on the federal PTC, which currently providesare eligible to claim an income tax credit for(the PTC, or an ITC in lieu of the productionPTC) upon initially achieving commercial operation. The PTC is determined based on the amount of electricity from utility-scaleproduced by the wind turbines forfacility during the first ten years of commercial operation. This incentive was created under the Energy Policy Act of 1992 and underhas been extended several times. Alternatively, an ITC equal to 30% of the American Taxpayer Relief Actcost of 2012 (Taxpayer Relief Act),a wind facility may be claimed in lieu of the PTC. In December 2015, the PTC (and ITC in lieu of PTC) for wind facilities was extended for wind projects whose construction began before January 1, 2014. The Internal Revenue Service (IRS) has issued guidance relatedfive years, subject to which projects willthe phase-down schedule in the table below. In order to qualify for the PTC including, among other things, criteria for the beginning(or ITC in lieu of PTC), construction of a projectwind facility must begin before a specified date. The IRS previously issued guidance setting forth two alternatives pursuant to which a taxpayer may begin construction on a wind facility and providing that the taxpayer must maintain a continuous program of construction or the continuous efforts to advance the project to completion. PursuantIn May 2016, the IRS issued additional guidance relating to the IRS guidance, NEER expects its projects currently in development or under construction in the U.S. will qualify for the PTC. Alternatively, wind project developers can choose to receive a 30% ITC, in lieuDecember 2015 extension and phase-down of the PTC withand ITC for wind facilities. In general, this guidance modifies and extends the same requirement thatsafe harbor for the continuous efforts and continuous construction requirements to four years compared to two years under the previous guidance. The safe harbor will generally be satisfied if the facility is placed in service no more than four calendar years after the calendar year in which construction of the facility began. The IRS also confirmed that retrofitted wind project began before January 1, 2014. NEER's expectationsfacilities may re-qualify for wind development andPTCs or ITCs pursuant to the 5% safe harbor for the begin construction will depend, in part, on whether legislationrequirement, as long as the cost basis of the new investment is passed to further extendat least 80% of the PTC.facility’s total fair value.
Solar project developersOwners of solar projects are also eligible to receiveclaim a 30% ITC for new solar projects, that achieve commercial operation before 2017. Solar project developersor can elect to receive an equivalent cash payment from the U.S. Department of Treasury for the value of the 30% ITC (convertible ITC) for qualifying solar projects where construction began before the end of 2011 and the projects are placed in service before 2017. In December 2015, the 30% ITC for new solar projects was extended, subject to the following phase-down schedule.
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| | | | | | | | | | | | | | | | | | | | | | | |
| | Year construction of project begins |
| | 2015 | | 2016 | | 2017 | | 2018 | | 2019 | | 2020 | | 2021 | | 2022 |
PTC(a) | 100 | % | | 100 | % | | 80 | % | | 60 | % | | 40 | % | | - |
| | - |
| | - |
|
| Wind ITC | 30 | % | | 30 | % | | 24 | % | | 18 | % | | 12 | % | | - |
| | - |
| | - |
|
Solar ITC(b) | 30 | % | | 30 | % | | 30 | % | | 30 | % | | 30 | % | | 26 | % | | 22 | % | | 10 | % |
_________________________
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| (a) | Percentage of the full PTC available for wind projects that begin construction during the applicable year. |
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| (b) | ITC is limited to 10% for projects not placed in service before January 1, 2024. |
Other countries, including Canada and Spain, provide for incentives like feed-in-tariffs for renewable energy projects. The feed-in-tariffs promote renewable energy investments by offering long-term contracts to renewable energy producers, typically based on the cost of generation of each technology. See Note 13 - Spain Solar Projects for developments in Spain.
NEER Generation by Geographic Region in North America
NEER's generating capacity spans various geographic regions in North America, thereby reducing overall volatility related to varying market conditions and seasonality on a portfolio basis. NEER's generating facilities at December 31, 2013 are categorized by geographic region (see Item 2 - Generating Facilities) in terms of MW of capacity as follows:
NEER CUSTOMER SUPPLYMARKETS AND PROPRIETARY POWER AND GAS TRADINGCOMPETITION
PMI,Electricity markets in the U.S. and Canada are regional and diverse in character. All are extensively regulated, and competition in these markets is shaped and constrained by regulation. The nature of the products offered varies based on the specifics of regulation in each region. Generally, in addition to the natural constraints on pricing freedom presented by competition, NEER may also face specific constraints in the form of price caps, or maximum allowed prices, for certain products. NEER's ability to sell the output of its generation facilities may also be constrained by available transmission capacity, which can vary from time to time and can have a subsidiarysignificant impact on pricing.
The degree and nature of competition that NEER buysfaces is different in wholesale markets and sellsin retail markets. During 2016, approximately 86% of NEER's revenue was derived from wholesale energy commodities,electricity markets.
Wholesale power generation is a capital-intensive, commodity-driven business with numerous industry participants. NEER primarily competes on the basis of price, but believes the green attributes of NEER's generation assets, its creditworthiness and its ability to offer and manage reliable customized risk solutions to wholesale customers are competitive advantages. Wholesale power generation is a regional business that is highly fragmented relative to many other commodity industries and diverse in terms of industry structure. As such, there is a wide variation in terms of the capabilities, resources, nature and identity of the companies NEER competes with depending on the market. In wholesale markets, customers' needs are met through a variety of means, including long-term bilateral contracts, standardized bilateral products such as full requirements service and customized supply and risk management services.
In general, U.S. electricity natural gasmarkets encompass three classes of services: energy, capacity and oil. PMIancillary services. Energy services relate to the physical delivery of power; capacity services relate to the availability of MW capacity of a power generation asset; and ancillary services are other services that relate to power generation assets, such as load regulation and spinning and non-spinning reserves. The exact nature of these classes of services is defined in part by regional tariffs. Not all regions have a capacity services class, and the specific definitions of ancillary services vary from region to region.
RTOs and ISOs exist throughout much of North America to coordinate generation and transmission across wide geographic areas and to run markets. NEER operates in all RTO and ISO jurisdictions. As of December 31, 2016, NEER also had operations of approximately 3,114 MWs that fall within reliability regions that are not under the jurisdiction of an established RTO or ISO, including 2,519 MWs within the Western Electricity Coordinating Council. Although each RTO and ISO may have differing objectives and structures, some benefits of these entities include regional planning, managing transmission congestion, developing larger wholesale markets for energy and capacity, maintaining reliability and facilitating competition among wholesale electricity providers. NEER has operations that fall within the following RTOs and ISOs:
NEER competes in different regions to different degrees, but in general it seeks to enter into long-term bilateral contracts for the full output of its generation facilities, and, as of December 31, 2016, approximately 80% of NEER's generating capacity was committed under long-term contracts. Where long-term contracts are not in effect, NEER sells the output of its facilities into daily spot markets. In such cases, NEER will frequently enter into shorter term bilateral contracts, typically of less than three years duration, to hedge the price risk associated with selling into a daily spot market. Such bilateral contracts, which may be hedges either for physical delivery or for financial (pricing) offset, may only protect a portion of the revenue that NEER expects to derive from NEER'sthe associated generation facility and may not qualify for hedge accounting under GAAP. Contracts that serve the economic purpose of hedging some portion of the expected revenue of a generation facility but are not recorded as hedges under GAAP are referred to as “non-qualifying hedges” for adjusted earnings purposes. See Management's Discussion - Overview - Adjusted Earnings.
Certain facilities within the NEER wind and solar generation portfolio produce RECs and other environmental attributes which are typically sold along with the energy from the plants that isunder long-term contracts, or may be sold separately for the wind and solar generation not sold under long-term contractscontracts. The purchasing party is solely entitled to the reporting rights and procuresownership of the fossilenvironmental attributes.
While the majority of NEER's revenue is derived from the output of its generation facilities, NEER is also an active competitor in several regions in the wholesale full requirements business and in providing structured and customized power and fuel products and services to a variety of customers. In the full requirements service, typically, the supplier agrees to meet the customer's needs for use by NEER's generation fleet. Its primary role is to managea full range of products for every hour of the commodityday, at a fixed price, for a predetermined period of time, thereby assuming the risk of NEER's portfolio. PMI uses derivative instruments such as swaps, options, futures and forwards to managefluctuations in the risk associated with fluctuating commodity prices and to optimize the value of NEER's power generation and gas infrastructure assets.customer's volume requirements.
PMI also providesExpanded competition in a wide rangefrequently changing regulatory environment presents both opportunities and risks for NEER. Opportunities exist for the selective acquisition of electricitygeneration assets and gas commodity productsfor the construction and operation of efficient facilities that can sell power in competitive markets. NEER seeks to customersreduce its market risk by having a diversified portfolio by fuel type and markets and trades energy commodity products. PMI's customer supply business includes providing full energy and capacity requirements and mid-market services that include sales and purchases of wholesale commodities-related products andlocation, as well as by contracting for the operationsfuture sale of a retailsignificant amount of the electricity provider.
The resultsoutput of PMI's activities are included in NEER's operating results. See Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity, Note 1 - Energy Trading and Note 3.its facilities.
NEER REGULATION
The energy markets in which NEER operates are subject to domestic and foreign regulation, as the case may be, including local, state and federal regulation, and other specific rules.
At December 31, 2013,2016, NEER had ownership interests in operating independent power projects located in the U.S. that have received exempt wholesale generator status as defined under the Public Utility Holding Company Act of 2005, which represent approximately 98%99% of NEER's net generating capacity.capacity in the U.S. Exempt wholesale generators own or operate a facility exclusively to sell electricity to wholesale customers. They are barred from selling electricity directly to retail customers. NEER's exempt wholesale generators produce electricity from wind, fossil fuels, solar and nuclear facilities. Essentially all of the remaining 2%1% of NEER's net generating capacity has qualifying facility status under the PURPA. NEER's qualifying facilities generate electricity primarily from wind, solar and fossil fuels. Qualifying facility status exempts the projects from, among other things, many of the provisions of the Federal Power Act, as well as state laws and regulations relating to rates and financial or organizational regulation of electric utilities. While projects with qualifying facility and/or exempt wholesale generator status are exempt from various restrictions, each project must still comply with other federal, state and local laws, including, but not limited to, those regarding siting, construction, operation, licensing, pollution abatement and other environmental laws.
Additionally, most of the NEER facilities located in the U.S. are subject to FERC regulations and market rules and the NERC's mandatory reliability standards, all of its facilities are subject to environmental laws and the EPA's environmental laws,regulations, and its nuclear facilities are also subject to the jurisdiction of the NRC. See FPL - FPL Regulation for additional discussion of FERC, NERC, NRC and EPA regulations. With the exception of facilities located in ERCOT, the FERC has jurisdiction over various aspects of NEER's business in the U.S., including the oversight and investigation of competitive wholesale energy markets, regulation of the transmission and sale of natural gas, and oversight of environmental matters related to natural gas projects and major electricity policy initiatives. The PUCT has jurisdiction, including the regulation of rates and services, oversight of competitive markets, and enforcement of statutes and rules, over NEER facilities located in ERCOT.
NEER and its affiliates are also subject to nationalfederal and provincial or regional regulations in Canada and Spain related to energy operations, energy markets and environmental standards. In Canada, activities related to owning and operating wind and solar projects and participating in wholesale and retail energy markets are regulated at the provincial level. In Ontario, for example, electricity generation facilities must be licensed by the Ontario Energy Board and may also be required to complete registrations and maintain market participant status with the Independent Electricity System Operator, in which case they must agree to be bound by and comply with the provisions of the market rules for the Ontario electricity market as well as the mandatory reliability standards of the NERC.
In addition, NEER is subject to environmental laws and regulations and is affected by some of the emerging issues related to renewable energy resources as described in the NEE Environmental Matters section below. In order to better anticipate potential regulatory changes, NEER continues to actively evaluate and participate in regional market redesigns of existing operating rules for the integration of renewable energy resources and for the purchase and sale of energy commodities.
NEER EMPLOYEES
NEER and its subsidiaries had approximately 4,5005,300 employees at December 31, 2013.2016. Certain subsidiaries of NEER have collective bargaining agreements with the IBEW, the Utility Workers Union of America, the Security Police and Fire Professionals of America and the International Union of Operating Engineers, which collectively represent approximately 22%17% of NEER's employees. The collective bargaining agreements have one-three- to five-year terms and expire between February 20152018 and 2016.2021.
III. OTHER NEE OPERATING SUBSIDIARIES
Corporate and Other represents other business activities, primarily NEET and FPL FiberNet, that are not separately reportable. See Note 14. In addition, certain subsidiaries of NEECH are pursuing approvals to build, own and operate an approximately 600-mile natural gas pipeline system to provide new natural gas transportation infrastructure in Florida.
NEET
NEET, a wholly-owned subsidiary of NEECH, is a limited liability company organized under the laws of Delaware. NEET conducts its business primarily through two subsidiaries, Lone Star and NHT, and is pursuing opportunities to develop, build and operate new transmission facilities throughout North America. In August 2013, an entity in which an affiliate of NEET has a joint venture investment was selected to complete development work for a 250-mile transmission line in Northwestern Ontario, Canada. Once development is complete, subject to Ontario Energy Board approval, the NEET affiliate, through its joint venture, is expected to construct, own and operate the new transmission line that is projected to begin service in 2018.
Lone Star
Lone Star, a rate-regulated transmission service provider in Texas, is a limited liability company organized under the laws of Delaware. Lone Star owns and operates approximately 330 miles of 345 kilovolt (kV) transmission lines and other associated facilities that were placed in service in 2012 and 2013. Lone Star is subject to regulation by a number of federal, state and other agencies, including, but not limited to, the PUCT, the ERCOT, the NERC and the EPA, as well as certain limited regulations of the FERC. See FPL - FPL Regulation for further discussion of FERC, NERC and EPA regulations and NEE Environmental Matters. The PUCT has jurisdiction over a wide range of Lone Star's business activities, including, among others, rates charged to customers and certain aspects of the operation of transmission systems. The PUCT sets rates at a level that allows Lone Star the opportunity to collect from customers total revenues (revenue requirements) equal to Lone Star's cost of providing service, including a reasonable rate of return on invested capital.
During late 2012 through mid-2013, the PUCT approved Lone Star's initial rate case proceeding as well as its interim rate adjustment filings for wholesale transmission service which ultimately provides for an annual revenue requirement of approximately $103 million for, among other things, $723 million of rate base, a regulatory equity ratio of 45%, an allowed regulatory ROE of 9.6% and other operating expenses. Lone Star's subsequent capital investment will be recovered through either interim rate adjustment filings or a base rate filing. Capital investment included in rates through the interim rate adjustment mechanism is subject to prudence review in Lone Star's next general rate case which is expected to be filed in mid-2014.
NHT
NHT, a rate-regulated transmission owner in ISO-NE, is a limited liability company organized under the laws of Delaware. NHT owns transmission facilities which connect NEER's Seabrook nuclear facility to the New England transmission grid and interconnect three 345 kV transmission lines in New England. NHT is subject to regulation by a number of federal, state and other agencies, including, but not limited to, the New Hampshire Public Utility Commission, ISO-NE, the FERC, the NERC and the EPA. See FPL - FPL Regulation and NEE Environmental Matters for further discussion of FERC, NERC and EPA regulations. NHT wholesale transmission revenues are provided through an ISO-NE tariff.
FPL FIBERNET
FPL FiberNet conducts its business through two separate wholly-owned subsidiaries of NEECH. One subsidiary was formed in 2000 to enhance the value of NEE's fiber-optic network assets that were originally built to support FPL operations and the other was formed in 2011 to hold fiber-optic network assets which were acquired. Both subsidiaries are limited liability companies organized under the laws of Delaware. FPL FiberNet leases fiber-optic network capacity and dark fiber to FPL and other customers, primarily telephone, wireless, internet and other telecommunications companies. FPL FiberNet's networks cover most of the metropolitan areas in Florida and several in Texas. FPL FiberNet also has a long-haul network providing bandwidth at wholesale rates. The long-haul network connects major cities in Florida and Texas with additional connectivity to Atlanta, Georgia and the South Central U.S., including Arkansas, Louisiana and Oklahoma. At December 31, 2013, FPL FiberNet's network consisted of approximately 8,760 route miles. FPL FiberNet is subject to regulation by the Federal Communications Commission which has jurisdiction over wire and wireless communication networks and by the public utility commissions in the states in which it provides intrastate telecommunication services.
NATURAL GAS PIPELINE SYSTEM
In July 2013, FPL announced the winning proposals from its 2012 RFP for an approximately 600-mile natural gas pipeline system for new natural gas transportation infrastructure in Florida. The proposed pipeline system will be composed of two pipelines, each of which is expected to be operational beginning in mid-2017. Sabal Trail, which is 33% owned by a NEECH subsidiary and will be a FERC-regulated entity, was selected to build, own and operate the northern pipeline that would originate in southwestern Alabama and end at a new hub to be built in Central Florida (Central Florida Hub). Florida Southeast Connection, which is a wholly-owned NEECH subsidiary and will be a FERC-regulated entity, was selected to build, own and operate the southern pipeline that
would originate at the Central Florida Hub and end in Martin County, Florida at FPL's Martin power plant.
Total estimated capital expenditures for the 33% portion of the northern pipeline plus the entire southern pipeline are estimated to be approximately $1.5 billion. At December 31, 2013, NEE's investment in the proposed pipeline system totaled approximately $33 million. The obligations of Sabal Trail and Florida Southeast Connection to build and operate the northern pipeline and southern pipeline, respectively, are subject to certain conditions, including FERC approval. A FERC decision is expected in 2015.
See FPL - FPL Sources of Generation - Fossil Operations and Note 13 - Commitments and Contracts.
NEE ENVIRONMENTAL MATTERS
NEE and FPL are subject to domestic and foreign environmental laws and regulations, including extensive federal, state and local environmental statutes, rules and regulations.regulations, for the siting, construction and ongoing operations of their facilities. The U.S. Congress and certain states and regions, continue to consider several legislative and regulatory proposals with respect to GHG emissions. Theas well as the Government of Canada and its provinces, are also takinghave taken and continue to take certain actions, such as proposing and finalizing regulation or setting targets or goals, regarding the reduction of GHG emissions. The economic and operational impact of climate change legislation on NEE and FPL depends on a variety of factors, including, but not limited to, the allowed emissions whether emission allowances will be allocated or auctioned, the cost to reduce emissions or buy allowances in the marketplace and the availabilityincrease of offsets and mitigating factors to moderate the costs of compliance. Based on the most recent reference data available from government sources, NEE is among the lowest emitters, among electric generators, of GHG in the U.S. measured by its rate of emissions expressed as pounds of CO2 per MWh ofrenewable energy generation. However, the legislative and regulatory proposals have differing methods of implementation and the impact on FPL's and NEER's generating units and/or the financial impact (either positive or negative) to NEE and FPL could be material, depending on the eventual structure of any specific implementation rules adopted.
I. Environmental Regulations
The following is a discussion of certain existing and emerging federal and state initiatives and rules, some of which could potentially have a material effect (either positive or negative) on NEE and its subsidiaries. FPL expects to seek recovery through theNumerous environmental clause for compliance costs associated with any new environmental laws and regulations.
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• | Clean Air Interstate Rule (CAIR)/Cross-State Air Pollution Rule (CSAPR). The EPA's CAIR requires SO2 and NOx emissions reductions from electric generating units in specified Eastern states and the District of Columbia, where the emissions from electric generating units are deemed to be transported to downwind states. NEER and FPL began complying with the CAIR on January 1, 2009. In 2011, the EPA issued the CSAPR, a final rule which was to replace the CAIR beginning in January 2012. The CSAPR would limit emissions of SO2 and NOx from power plants in 28 eastern states and provides an allocation methodology for emission allowances and reduction limits for SO2, NOx and seasonal ozone requirements. In August 2012, the D.C. Circuit vacated the CSAPR and remanded it back to the EPA for further rulemaking, which decision was appealed to the U.S. Supreme Court by several parties, including the EPA. The D.C. Circuit ordered that the CAIR remain in place until such time that the EPA promulgates a valid replacement, which the EPA is expected to propose in late 2014. In June 2013, the U.S. Supreme Court issued an order granting the petitions for review of the D.C. Circuit's decision to vacate the CSAPR andoral arguments were heard in December 2013.
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Clean Water Act Section 316(b). In March 2011, the EPA issued a proposed rule under Section 316(b) of the Clean Water Act to address the location, design, construction and capacity of intake structures at existing power plants with once-through cooling water systems. The proposed rule is intended to require the Best Technology Available to reduce the impact on aquatic organisms from once-through cooling water intake systems. Under the proposed rule, potentially thirteen of FPL's facilities and five of NEER's facilities may be required to add additional controls and/or make operational changes to comply, the economic and operational impact of which cannot be determined at this time, but could be material. The issuance of a final rule is expected in April 2014.
Regulation of GHG Emissions. In September 2013, the EPA re-proposed standards for new fossil fuel-fired power units pursuant to a Presidential Memorandum related to the regulation of GHG emissions. The Presidential Memorandumregulations also directed the EPA to issue a final rule for new fossil fuel-fired power units after considering all public comments and to propose a rule for existing fossil fuel-fired power units by June 2014 with a final rule by June 2015 and to prepare guidelines requiring each state to revise their state implementation plans, which will set forth the program requirements within that state, by the end of June 2016. In October 2013, the U.S. Supreme Court granted a request by several petitioners for review of the D.C. Circuit's June 2012 decision which upheld the EPA's 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 scheduled to hear oral arguments on February 24, 2014.
Avian/Bat Regulations and Wind Turbine Siting Guidelines.affecting FPL, NEER and NEET are subject to numerous environmental regulations and guidelines relatedcertain other subsidiaries relate to threatened and endangered species and their habitats, as well as other avian and bat species, for the siting, construction andongoing operations of their facilities. The facilities most significantly affected are wind and solar facilities and transmission and distribution lines. The environmental laws in the U.S., including, among others, the Endangered
Species Act, the Migratory Bird Treaty Act, and the Bald and Golden Eagle Protection Act and similar environmental laws in Canada provide for the protection of migratory birds, eagles and endangered species of birds and bats and their habitats. Regulations have been adopted under some of these laws that contain provisions that allow the owner/operator of a facility to apply for a permit to undertake specific activities including those associated with certain siting decisions, construction activities and operations. In addition to regulations, voluntary wind turbine siting guidelines established by the U.S. Fish and Wildlife Service set forth siting, monitoring and coordination protocols that are designed to support wind development in the U.S. while also protecting both birds and bats and their habitats. These guidelines include provisions for specific monitoring and study conditions which need to be met in order for projects to be in adherence with these voluntary guidelines.species. Complying with these environmental laws and regulations and adhering to the provisions set forthresults in, among other things, changes in the voluntary wind turbine siting guidelines could result in additional costs or reduced revenues atdesign and operation of existing and new wind and solar facilities and transmission and distribution facilities at FPL, NEER and NEET.
II. Other GHG Emissions Reduction Initiatives
NEER's plants operate in certain states and regions that continue to consider and implement regulatory proposals to reduce GHG emissions. RPS, currently in place in approximately 30 states and the District of Columbia, require electricity providerschanges or delays in the state or districtlocation, design, construction and operation of new facilities. The impact of complying with current environmental laws and regulations has not had, and, along with compliance with proposed regulations as currently written, is not expected to meet a certain percentage of their retail sales with energy from renewable sources. These standards vary, but the majority include requirements to meet 10% to 25% of the electricity providers' retail sales with energy from renewable sources by 2025. Approximately 7 other states have set renewable energy goals as well. NEER's plants operate in 20 statesthat have, a RPS or renewable energy goalsmaterial adverse effect on the financial statements of NEE and NEER believes that these standards and goals will create incremental demand for renewable energy inFPL. As permitted by the future.
Other GHG reduction initiatives including, among others, the Regional Greenhouse Gas Initiative and the California Greenhouse Gas Regulation aim to reduce emissions through a variety of programs and under varying timelines. Based on its clean generating portfolio, NEERenvironmental clause, FPL expects to continue experiencing a positive impact on earnings as a result of these GHG reduction initiatives. Additionally, these initiatives provide NEER opportunitiesseek recovery for compliance costs associated with regards to windany new environmental laws and solar development as well as favorable energy pricing.regulations.
WEBSITE ACCESS TO SEC FILINGS
NEE and FPL make their SEC filings, including the annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports, available free of charge on NEE's internet website, www.nexteraenergy.com, as soon as reasonably practicable after those documents are electronically filed with or furnished to the SEC. The information and materials available on NEE's website (or any of its subsidiaries' websites) are not incorporated by reference into this combined Form 10-K. The SEC maintains an internet website that contains reports, proxy and information statements, and other information regarding registrants that file electronically with the SEC at www.sec.gov.
EXECUTIVE OFFICERS OF NEE(a)
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| Name | | Age | | Position | | Effective Date |
| Miguel Arechabala | | 5356 | | Executive Vice President, Power Generation Division of NEE
Executive Vice President, Power Generation Division of FPL
| | January 1, 2014 |
| Deborah H. Caplan | | 5154 | | Executive Vice President, Human Resources and Corporate Services of NEE
Executive Vice President, Human Resources and Corporate Services of FPL
| | April 15, 2013 |
| Terrell Kirk Crews, II | | 38 | | Vice President, Controller and Chief Accounting Officer of NEE | | September 19, 2016 |
| Paul I. Cutler | | 5457 | | Treasurer of NEE Treasurer of FPL Assistant Secretary of NEE
| | February 19, 2003 February 18, 2003 December 10, 1997 |
Moray P. DewhurstJoseph T. Kelliher | | 5856 | | Executive Vice President, Federal Regulatory Affairs of NEE | | May 18, 2009 |
| John W. Ketchum | | 46 | | Executive Vice ChairmanPresident, Finance and Chief Financial Officer and Executive Vice President - Finance of NEE Executive Vice President, Finance and Chief Financial Officer of FPL
| | October 5, 2011 |
Chris N. Froggatt | | 56 | | Vice President of NEE
Controller and Chief Accounting Officer of NEE
| | October 19, 2009
February 27, 2010
|
Joseph T. Kelliher | | 53 | | Executive Vice President, Federal Regulatory Affairs of NEE
| | May 18, 2009March 4, 2016 |
| Manoochehr K. Nazar | | 5962 | | Executive Vice President Nuclear Division and Chief Nuclear Officer of NEE
Executive Vice President Nuclear Division and Chief Nuclear Officer of FPL
| | January 1, 2010May 23, 2014
January 15, 2010May 30, 2014
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| Armando Pimentel, Jr. | | 5154 | | President and Chief Executive Officer of NEER
| | October 5, 2011 |
| James L. Robo | | 5154 | | Chairman, of NEE President and Chief Executive Officer of NEE Chairman and Chief Executive Officer of FPL
| | December 13, 2013 July 1, 2012
May 2, 2012 |
| Charles E. Sieving | | 4144 | | Executive Vice President & General Counsel of NEE Executive Vice President of FPL
| | December 1, 2008 January 1, 2009 |
| Eric E. Silagy | | 4851 | | President and Chief Executive Officer of FPL
| | December 16, 2011May 30, 2014 |
| William L. Yeager | | 5558 | | Executive Vice President, Engineering, Construction &and Integrated Supply Chain of NEE Executive Vice President, Engineering, Construction &and Integrated Supply Chain of FPL
| | January 1, 2013 |
______________________
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| (a) | Information is as of February 21, 201423, 2017. Executive officers are elected annually by, and serve at the pleasure of, their respective boards of directors. Except as noted below, each officer has held his/her present position for five years or more and his/her employment history is continuous. Mr. Arechabala was president of NextEra Energy España, S.L., an indirect wholly owned subsidiary of NEE, from February 2010 to December 2013. From March 2007 to February 2010, Mr. Arechabala was vice president, thermal hydro plant operations & management of NEER. Ms. Caplan was vice president and chief operating officer of FPL from May 2011 to April 2013. Mr. Crews served as NEE’s Vice President, Finance from April 2016 to September 2016. From July 20052015 to May 2011, Ms. CaplanApril 2016, he was vice president, integrated supply chaina Partner in the national office of NEEDeloitte & Touche LLP (Deloitte); from June 2013 to June 2015, he served as a professional accounting fellow in the Office of the Chief Accountant of the SEC; and FPL.from June 2010 to June 2013, he was an audit service senior manager at Deloitte. Mr. Dewhurst has been vice chairmanKetchum served as NEE’s Senior Vice President, Finance from February 2015 to March 2016, and Senior Vice President, Business Management and Finance from December 2013 to February 2015. From December 2012 to December 2013, he was Senior Vice President, Business Management of NEE since August 2009NEER and was chiefVice President, General Counsel & Secretary of staff of NEENEER from AugustJune 2009 to October 2011. Mr. Froggatt was the vice president and treasurer of Pinnacle West Capital Corporation, a public utility holding company, and its major subsidiary, Arizona Public Service Company, a regulated electric utility, from December 2008 to October 2009.2012. Mr. Nazar was thehas been chief nuclear officer of NEE from January 2009 to December 2009. From January 2009 toand FPL since January 2010 Mr. Nazarand was the seniorexecutive vice president, and chief nuclear officer of FPL. Mr. Pimentel was chief financial officerdivision of NEE and FPL from January 2010 to May 2008 to October 20112014. Mr. Robo has been president and chief executive vice president, financeofficer of NEE andsince July 2012. Mr. Robo was the chief executive officer of FPL from February 2008May 2012 to October 2011. Mr. Robo wasMay 2014 and president and chief operating officer of NEE from December 2006 to June 2012. Mr. Sieving was also assistant secretary of NEE from May 2010 to May 2011 and general counselSilagy has been president of FPL from January 2009 to May 2010. Mr. Silagy was senior vice president, regulatory and state governmental affairs of FPL from May 2010 tosince December 2011. Mr. Silagy was vice president and chief development officer of FPL from July 2008 to May 2010. Mr. Yeager was vice president, engineering, construction and integrated supply chain services of NEE and FPL from October 2012 to December 2012. Mr. Yeager was2012 and vice president, integrated supply chain of NEE and FPL from May 2011 to October 2012. From January 2005 to May 2011, Mr. Yeager was vice president, engineering and construction of FPL. |
Item 1A. Risk Factors
Risks Relating to NEE's and FPL's Business
The business, financial condition, results of operations and prospects of NEE and FPL are subject to a variety of risks, many of which are beyond the control of NEE and FPL. The following is a description of importantThese risks, as well as additional risks and uncertainties either not presently known or that are currently believed to not be material to the business, may materially adversely affect the business, financial condition, results of operations and prospects of NEE and FPL and may cause actual results of NEE and FPL to differ substantially from those that NEE or FPL currently expects or seeks. In that event, the market price for the securities of NEE or FPL could decline. Accordingly, the risks described below should be carefully considered together with the other information set forth in this report and in future reports that NEE and FPL file with the SEC. The risks described below are not the only risks facing NEE and FPL. Additional risks and uncertainties may also materially adversely affect NEE's or FPL's business, financial condition, results of operations and prospects. Each of NEE and FPL has disclosed the material risks known to it to affect its business at this time. However, there may be further risks and uncertainties that are not presently known or that are not currently believed to be material that may in the future materially adversely affect the performance or financial condition of NEE and FPL.
Regulatory, Legislative and Legal Risks
NEE's and FPL's business, financial condition, results of operations and prospects may be materially adversely affected by the extensive regulation of their business.
The operations of NEE and FPL are subject to complex and comprehensive federal, state and other regulation. This extensive regulatory framework, portions of which are more specifically identified in the following risk factors, regulates, among other things and to varying degrees, NEE's and FPL's industries, businesses, rates and cost structures, operation and licensing of nuclear power facilities, construction and operation of electricity generation, transmission and distribution facilities and natural gas and oil production, transmissionnatural gas, oil and other fuel transportation, processing and storage facilities, acquisition, disposal, depreciation and amortization of facilities and other assets, decommissioning costs and funding, service reliability, wholesale and retail competition, and commodities trading and derivatives transactions. In their business planning and in the management of their operations, NEE and FPL must address the effects of regulation on their business and any inability or failure to do so adequately could have a material adverse effect on their business, financial condition, results of operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected if they are unable to recover in a timely manner any significant amount of costs, a return on certain assets or an appropriatea reasonable return on invested capital through base rates, cost recovery clauses, other regulatory mechanisms or otherwise.
FPL is a regulated entityan electric utility subject to the jurisdiction of the FPSC over a wide range of business activities, including, among other items, the retail rates charged to its customers through base rates and cost recovery clauses, the terms and conditions of its services, procurement of electricity for its customers issuanceand fuel for its plant operations, issuances of securities, and aspects of the siting, construction and operation of its generatinggeneration plants and transmission and distribution systems for the sale of electric energy. The FPSC has the authority to disallow recovery by FPL of costs that it considers excessive or imprudently incurred and to determine the level of return that FPL is permitted to earn on invested capital. The regulatory process, which may be adversely affected by the political, regulatory and economic environment in Florida and elsewhere, limits or could otherwise adversely impact FPL's ability to increase earnings andearnings. The regulatory process also does not provide any assurance as to achievement of authorized or other earnings levels.levels, or that FPL will be permitted to earn an acceptable return on capital investments it wishes to make. NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected if any material amount of costs, a return on certain assets or an appropriatea reasonable return on invested capital cannot be recovered through base rates, cost recovery clauses, other regulatory mechanisms or otherwise. Certain subsidiaries of NEET, which are indirect wholly-ownedother subsidiaries of NEE are regulated electric transmission utilities subject to the jurisdiction of their regulators and are subject to similar risks.
Regulatory decisions that are important to NEE and FPL may be materially adversely affected by political, regulatory and economic factors.
The local and national political, regulatory and economic environment has had, and may in the future have, an adverse effect on FPSC decisions with negative consequences for FPL. These decisions may require, for example, FPL to cancel or delay planned development activities, to reduce or delay other planned capital expenditures or to pay for investments or otherwise incur costs that it may not be able to recover through rates, each of which could have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL. Certain other subsidiaries of NEETNEE are subject to similar risks.
FPL's use of derivative instruments could be subject to prudence challenges and, if found imprudent, could result in disallowances of cost recovery for such use by the FPSC.
The FPSC engages in an annual prudence review of FPL's use of derivative instruments in its risk management fuel procurement program and should it find any such use to be imprudent, the FPSC could deny cost recovery for such use by FPL. Such an outcome could have a material adverse effect on FPL's business, financial condition, results of operations and prospects.
Any reductions or modifications to, or the elimination of, governmental incentives or policies that support utility scale renewable energy, including, but not limited to, tax laws, policies and incentives, RPS, or feed-in tariffs or the Clean Power Plan, 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 and/or financing of new renewable energy projects, NEER abandoning
the development of renewable energy projects, a loss of NEER's investments in renewable energy projects and reduced project returns, any of which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
NEER depends heavily on government policies that support utility scale renewable energy and enhance the economic feasibility of developing and operating wind and solar energy projects in regions in which NEER operates or plans to develop and operate renewable energy facilities. The federal government, a majority of the 50 U.S. states and portions of Canada and Spain provide incentives, such as tax incentives, RPS, or feed-in tariffs or the Clean Power Plan, that support or are designed to support the sale of energy from utility scale renewable energy facilities, such as wind and solar energy facilities. As a result of budgetary constraints, political factors or otherwise, governments from time to time may review their laws and policies that support renewable energy and consider actions tothat would make the laws and policies less conducive to the development and operation of renewable energy facilities. Any reductions or modifications to, or the elimination of, governmental incentives or policies that support renewable energy such as those reductions that have been enacted in Spain and are applicable to NEER's solar projects in that country, or the imposition of additional taxes or other assessments on renewable energy, could result in, among other items, the lack of a satisfactory market for the development and/or financing of new renewable energy projects, NEER abandoning the development of renewable energy projects, a loss of NEER's investments in the projects and reduced project returns, any of which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected as a result of new or revised laws, regulations, or interpretations or other regulatory initiatives.
NEE's and FPL's business is influenced by various legislative and regulatory initiatives, including, but not limited to, new or revised laws, including international trade laws, regulations, or interpretations orand other regulatory initiatives regarding deregulation or restructuring of the energy industry, regulation of the commodities trading and derivatives markets, and regulation of environmental regulation,matters, such as regulation of air emissions, regulation of water consumption and water discharges, and regulation of gas and oil infrastructure operations, as well as associated environmental permitting. Changes in the nature of the regulation of NEE's and FPL's business could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations.operations and prospects. NEE and FPL are unable to predict future legislative or regulatory changes, initiatives or interpretations, although any such changes, initiatives or interpretations may increase costs and competitive pressures on NEE and FPL, which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
FPL has limited competition in the Florida market for retail electricity customers. Any changes in Florida law or regulation which introduce competition in the Florida retail electricity market, such as government incentives that facilitate the installation of solar generation facilities on residential or other rooftops at below cost or that are otherwise subsidized by non-participants, or would permit third-party sales of electricity, could have a material adverse effect on FPL's business, financial condition, results of operations and prospects. There can be no assurance that FPL will be able to respond adequately to such regulatory changes, which could have a material adverse effect on FPL's business, financial condition, results of operations and prospects.
NEER is subject to FERC rules related to transmission that are designed to facilitate competition in the wholesale market on practically a nationwide basis by providing greater certainty, flexibility and more choices to wholesale power customers. NEE cannot predict the impact of changing FERC rules or the effect of changes in levels of wholesale supply and demand, which are typically driven by factors beyond NEE's control. There can be no assurance that NEER will be able to respond adequately or sufficiently quickly to such rules and developments, or to any other changes that reverse or restrict the competitive restructuring of the energy industry in those jurisdictions in which such restructuring has occurred. Any of these events could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
NEE'sNEE’s and FPL's business,FPL’s OTC financial condition, results of operations and prospects could be materially adversely affected if thederivatives are subject to rules implementing the Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank Act) broaden the scope of its provisions regarding the regulation of OTC financial derivatives and make certain provisions applicablesimilar international regulations that are designed to NEEpromote transparency, mitigate systemic risk and FPL.
The Dodd-Frank Act, enacted into law in July 2010, among other things, provides for substantially increased regulation of the OTC derivatives market. While the legislation is broad and detailed, there are still portions of the legislation that either require implementing rules to be adopted by federal governmental agencies or otherwise require further interpretive guidance.
NEE and FPL continue to monitor the development of rules related to the Dodd-Frank Act and are taking steps to comply with those rules that affect their businesses. While a number of rules have been finalized and are effective, the rules related to collateral requirements have yet to be finalized. If those rules, when finalized, require NEE and FPL to post significant amounts of cash collateral with respect to swap transactions, NEE's and FPL's liquidity could be materially adversely affected.
protect against market abuse. NEE and FPL cannot predict the impact these newany proposed or not fully implemented final rules will have on their ability to hedge their commodity and interest rate risks or on OTC derivatives markets as a whole, but theysuch rules and regulations could potentially have a material adverse effect on NEE's and FPL's risk exposure, as well as reduce market liquidity and further increase the cost of hedging activities.
NEE and FPL are subject to numerous environmental laws, regulations and other standards that may result in capital expenditures, increased operating costs and various liabilities, and may require NEE and FPL to limit or eliminate certain operations.
NEE and FPL are subject to domestic and foreign environmental laws, regulations and regulations,other standards, including, but not limited to, extensive federal, state and local environmental statutes, rules and regulations relating to air quality, water quality and usage, climate change, emissions of greenhouse gases, including, but not limited to, CO2, waste management, hazardous wastes, marine, avian and other wildlife mortality and habitat protection, historical artifact preservation, natural resources, health (including, but not limited to, electric and magnetic fields from power lines and substations), safety and RPS, that could, among other things, prevent or delay the development of power generation, power or natural gas transmission, or other infrastructure projects, restrict the output of some existing facilities, limit the availability and use of some fuels required for the production of electricity, require additional pollution control equipment, and otherwise increase costs, increase capital expenditures and limit or eliminate certain operations.
There are significant capital, operating and other costs associated with compliance with these environmental statutes, rules and regulations, and those costs could be even more significant in the future as a result of new legislation, the current trend toward more stringent standards,requirements and stricter andor more expansive application of existing environmental regulations. For example, among other new, potential or pending changes are federal regulation of CO2 emissions under the Clean Power Plan and state and federal regulation of the use of hydraulic fracturing or similar technologies to drill for natural gas and related compounds used by NEE's gas infrastructure business is currently being discussed for regulation at state and federal levels.business.
Violations of current or future laws, rules, regulations or other standards could expose NEE and FPL to regulatory and legal proceedings, disputes with, and legal challenges by, third parties, and potentially significant civil fines, criminal penalties and other sanctions. Proceedings could include, for example, litigation regarding property damage, personal injury, common law nuisance and enforcement by citizens or governmental authorities of environmental requirements such as air, water and soil quality standards.
NEE's and FPL's business could be negatively affected by federal or state laws or regulations mandating new or additional limits on the production of greenhouse gas emissions.
Federal or state laws or regulations may be adopted that would impose new or additional limits on the emissions of greenhouse gases, including, but not limited to, CO2CO2 and methane, from electric generatinggeneration units using fossil fuels like coal and natural gas. Although it is currently subject to a stay issued by the U.S. Supreme Court, the Clean Power Plan is an example of such a new regulation at the federal level. The potential effects of such greenhouse gas emission limits on NEE's and FPL's electric generatinggeneration units are subject to significant uncertainties based on, among other things, the timing of the implementation of any new requirements, the required levels of emission reductions, the nature of any market-based or tax-based mechanisms adopted to facilitate reductions, the relative availability of greenhouse gas emission reduction offsets, the development of cost-effective, commercial-scale carbon capture and storage technology and supporting regulations and liability mitigation measures, and the range of available compliance alternatives.
While NEE's and FPL's electric generatinggeneration units emit greenhouse gases at a lower rate of emissions than most of the U.S. electric generation sector, the results of operations of NEE and FPL could be materially adversely affected to the extent that new federal or state legislationlaws or regulatorsregulations impose any new greenhouse gas emission limits. Any future limits on greenhouse gas emissions could:
create substantial additional costs in the form of taxes or emission allowances;
make some of NEE's and FPL's electric generatinggeneration units uneconomical to operate in the long term;
require significant capital investment in carbon capture and storage technology, fuel switching, or the replacement of high-emitting generation facilities with lower-emitting generation facilities; or
affect the availability or cost of fossil fuels.
There can be no assurance that NEE or FPL would be able to completely recover any such costs or investments, which could have a material adverse effect on their business, financial condition, results of operations and prospects.
Extensive federal regulation of the operations and businesses 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.
NEENEE's and FPLFPL's operations and businesses are subject to extensive federal regulation, which generally imposes significant and increasing compliance costs on NEE'stheir operations and FPL's operations.businesses. Additionally, any actual or alleged compliance failures could result in significant costs and other potentially adverse effects of regulatory investigations, proceedings, settlements, decisions and claims, including, among other items, potentially significant monetary penalties. As an example, under the Energy Policy Act of 2005, NEE and FPL, as owners and operators of bulk-power transmission systems and/or electric generation facilities, are subject to mandatory reliability standards. Compliance with these mandatory reliability standards may subject NEE and FPL to higher operating costs and may result in increased capital expenditures. If FPL or NEE is found not to be in compliance with these standards, it may incur substantial monetary penalties and other sanctions. Both the costs of regulatory compliance and the costs that may be imposed as a result of any actual or alleged compliance failures could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
Changes in tax laws, guidance or policies, including but not limited to changes in corporate income tax rates, as well as judgments and estimates used in the determination of tax-related asset and liability amounts, could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's and FPL's provision for income taxes and reporting of tax-related assets and liabilities require significant judgments and the use of estimates. Amounts of tax-related assets and liabilities involve judgments and estimates of the timing and probability of recognition of income, deductions and tax credits, including, but not limited to, estimates for potential adverse outcomes regarding tax positions that have been taken and the ability to utilize tax benefit carryforwards, such as net operating loss and tax credit carryforwards. Actual income taxes could vary significantly from estimated amounts due to the future impacts of, among other things, changes in tax laws, regulations and interpretations,guidance or policies, including changes in corporate income tax rates, the financial condition and results of operations of NEE and FPL, and the resolution of audit issues raised by taxing authorities. UltimateThese factors, including the ultimate resolution of income tax matters, may result in material adjustments to tax-related assets and liabilities, which could negativelymaterially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects may be materially adversely affected due to adverse results of litigation.
NEE's and FPL's business, financial condition, results of operations and prospects may be materially affected by adverse results of litigation. Unfavorable resolution of legal proceedings in which NEE is involved or other future legal proceedings, including, but not limited to, class action lawsuits, may have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.
Operational Risks
NEE's and FPL's business, financial condition, results of operations and prospects could suffer if NEE and FPL do not proceed with projects under development or are unable to complete the construction of, or capital improvements to, electric generation, transmission and distribution facilities, gas infrastructure facilities or other facilities on schedule or within budget.
NEE's and FPL's ability to proceed with projects under development and to complete construction of, and capital improvement projects for, their electric generation, transmission and distribution facilities, gas infrastructure facilities and other facilities on schedule and within budget may be adversely affected by escalating costs for materials and labor and regulatory compliance, inability to obtain or renew necessary licenses, rights-of-way, permits or other approvals on acceptable terms or on schedule, disputes involving contractors, labor organizations, land owners, governmental entities, environmental groups, Native American and aboriginal groups, lessors, joint venture partners and other third parties, negative publicity, transmission interconnection issues and other factors. If any development project or construction or capital improvement project is not completed, is delayed or is subject to cost overruns, certain associated costs may not be approved for recovery or otherwise be recoverable through regulatory mechanisms that may otherwise be available, and NEE and FPL could become obligated to make delay or termination payments or become obligated for other damages under contracts, could experience the loss of tax credits or tax incentives, or delayed or diminished returns, and could be required to write-offwrite off all or a portion of their investment in the project. Any of these events could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE and FPL may face risks related to project siting, financing, construction, permitting, governmental approvals and the negotiation of project development agreements that may impede their development and operating activities.
NEE and FPL own, develop, construct, manage and operate electric-generatingelectric-generation and transmission facilities and natural gas transmission facilities. A key component of NEE's and FPL's growth is their ability to construct and operate generation and transmission facilities to meet customer needs. As part of these operations, NEE and FPL must periodically apply for licenses and permits from various local, state, federal and other regulatory authorities and abide by their respective conditions. Should NEE or FPL be unsuccessful in obtaining necessary licenses or permits on acceptable terms, should there be a delay in obtaining or renewing necessary licenses or permits or should regulatory authorities initiate any associated investigations or enforcement actions or impose related penalties or disallowances on NEE or FPL, NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected. Any failure to negotiate successful project development agreements for new facilities with third parties could have similar results.
The operation and maintenance of NEE's and FPL's electric generation, transmission and distribution facilities, gas infrastructure facilities and other facilities are subject to many operational risks, the consequences of which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's and FPL's electric generation, transmission and distribution facilities, gas infrastructure facilities and other facilities are subject to many operational risks. Operational risks could result in, among other things, lost revenues due to prolonged outages, increased expenses due to monetary penalties or fines for compliance failures, liability to third parties for property and personal injury damage, a failure to perform under applicable power sales agreements or other agreements and associated loss of revenues from terminated agreements or liability for liquidated damages under continuing agreements, and replacement equipment costs or an obligation to purchase or generate replacement power at higher prices.
Uncertainties and risks inherent in operating and maintaining NEE's and FPL's facilities include, but are not limited to:
risks associated with facility start-up operations, such as whether the facility will achieve projected operating performance on schedule and otherwise as planned;
failures in the availability, acquisition or transportation of fuel or other necessary supplies;
the impact of unusual or adverse weather conditions and natural disasters, including, but not limited to, hurricanes, tornadoes, icing events, floods, earthquakes and droughts;
performance below expected or contracted levels of output or efficiency;
breakdown or failure, including, but not limited to, explosions, fires, leaks or other major events, of equipment, transmission and distribution lines or pipelines;
availability of replacement equipment;
risks of property damage or human injury from energized equipment, hazardous substances or explosions, fires, leaks or other events;
availability of adequate water resources and ability to satisfy water intake and discharge requirements;
inability to identify, manage properly or mitigate known equipment defects in NEE's and FPL's facilities;
use of new or unproven technology;
risks associated with dependence on a specific type of fuel or fuel source, such as commodity price risk, availability of adequate fuel supply and transportation, and lack of available alternative fuel sources;
increased competition due to, among other factors, new facilities, excess supply, shifting demand and shifting demand;regulatory changes; and
insufficient insurance, warranties or performance guarantees to cover any or all lost revenues or increased expenses from the foregoing.
NEE's and FPL's business, financial condition, results of operations and prospects may be negatively affected by a lack of growth or slower growth in the number of customers or in customer usage.
Growth in customer accounts and growth of customer usage each directly influence the demand for electricity and the need for additional power generation and power delivery facilities.facilities, as well as the need for energy-related commodities such as natural gas. Customer growth and customer usage are affected by a number of factors outside the control of NEE and FPL, such as mandated energy efficiency measures, demand side management requirements, and economic and demographic conditions, such as population changes, job and income growth, housing starts, new business formation and the overall level of economic activity. A lack of growth, or a decline, in the number of customers or in customer demand for electricity or natural gas and other fuels may cause NEE and FPL to fail to fully realize the anticipated benefits from significant investments and expenditures and could have a material adverse effect on NEE's and FPL's growth, business, financial condition, results of operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects can be materially adversely affected by weather conditions, including, but not limited to, the impact of severe weather.
Weather conditions directly influence the demand for electricity and natural gas and other fuels and affect the price of energy and energy-related commodities. In addition, severe weather and natural disasters, such as hurricanes, floods, tornadoes, icing events and earthquakes, can be destructive and cause power outages and property damage, reduce revenue, affect the availability of fuel and water, and require NEE and FPL to incur additional costs, for example, to restore service and repair damaged facilities, to obtain replacement power and to access available financing sources. Furthermore, NEE's and FPL's physical plantplants could be placed at greater risk of damage should changes in the global climate produce unusual variations in temperature and weather patterns, resulting in more intense, frequent and extreme weather events, abnormal levels of precipitation and, particularly relevant to FPL, a change in sea level. FPL operates in the east and lower west coasts of Florida, an area that historically has been prone to severe weather events, such as hurricanes. A disruption or failure of electric generation, transmission or distribution systems or natural gas production, transmission, storage or distribution systems in the event of a hurricane, tornado or other severe weather event, or otherwise, could prevent NEE and FPL from operating their business in the normal course and could result in any of the adverse consequences described above. Any of the foregoing could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
At FPL and other businesses of NEE where cost recovery is available, recovery of costs to restore service and repair damaged facilities is or may be subject to regulatory approval, and any determination by the regulator not to permit timely and full recovery of the costs incurred could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
Changes in weather can also affect the production of electricity at power generatinggeneration facilities, including, but not limited to, NEER's wind and solar facilities. For example, the level of wind resource affects the revenue produced by wind generatinggeneration facilities. Because the levels of wind and solar resources are variable and difficult to predict, NEER's results of operations for individual wind and solar facilities specifically, and NEE's results of operations generally, may vary significantly from period to period, depending on the level of available resources. To the extent that resources are not available at planned levels, the financial results from these facilities may be less than expected.
Threats of terrorism and catastrophic events that could result from terrorism, cyber attacks, or individuals and/or groups attempting to disrupt NEE's and FPL's business, or the businesses of third parties, may materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
NEE and FPL are subject to the potentially adverse operating and financial effects of terrorist acts and threats, as well as cyber attacks and other disruptive activities of individuals or groups. There have been cyber attacks on energy infrastructure such as substations, gas pipelines and related assets in the past and there may be such attacks in the future. NEE's and FPL's generation, transmission and distribution facilities, fuel storage facilities, information technology systems and other infrastructure facilities and systems could be direct targets of, or otherwise be indirectlymaterially adversely affected by, such activities.
Terrorist acts, cyber attacks or other similar events affecting NEE's and FPL's systems and facilities, or those of third parties on which NEE and FPL rely, could harm NEE's and FPL's business, for example, by limiting their ability to generate, purchase or transmit power, natural gas or other energy-related commodities by limiting their ability to bill customers and collect and process
payments, and by delaying their development and construction of new generatinggeneration, distribution or transmission facilities or capital improvements to existing facilities. These events, and governmental actions in response, could result in a material decrease in revenues, significant additional costs (for example, to repair assets, implement additional security requirements or maintain or acquire insurance), significant fines and penalties, and reputational damage, could materially adversely affect NEE's and FPL's operations (for example, by contributing to disruption of supplies and markets for natural gas, oil and other fuels), and could impair NEE's and FPL's ability to raise capital (for example, by contributing to financial instability and lower economic activity). In addition, the implementation of security guidelines and measures has resulted in and is expected to continue to result in increased costs. Such events or actions may materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
The ability of NEE and FPL to obtain insurance and the terms of any available insurance coverage could be materially adversely affected by international, national, state or local events and company-specific events, as well as the financial condition of insurers. NEE's and FPL's insurance coverage does not provide protection against all significant losses.
Insurance coverage may not continue to be available or may not be available at rates or on terms similar to those presently available to NEE and FPL. The ability of NEE and FPL to obtain insurance and the terms of any available insurance coverage could be materially adversely affected by international, national, state or local events and company-specific events, as well as the financial condition of insurers. If insurance coverage is not available or obtainable on acceptable terms, NEE or FPL may be required to pay costs associated with adverse future events. NEE and FPL generally are not fully insured against all significant losses. For example, FPL is not fully insured against hurricane-related losses, but would instead seek recovery of such uninsured losses from customers subject to approval by the FPSC, to the extent losses exceed restricted funds set aside to cover the cost of storm damage. A loss for which NEE or FPL is not fully insured could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE invests in gas and oil producing and transmission assets through NEER’s gas infrastructure business. The gas infrastructure business is exposed to fluctuating market prices of natural gas, natural gas liquids, oil and other energy commodities. A prolonged period of low gas and oil prices could impact NEER’s gas infrastructure business and cause NEER to delay or cancel certain gas infrastructure projects and for certain existing projects to be impaired, which could materially adversely affect NEE's results of operations.
Natural gas and oil prices are affected by supply and demand, both globally and regionally. Factors that influence supply and demand include operational issues, natural disasters, weather, political instability, conflicts, new discoveries, technological advances, economic conditions and actions by major oil-producing countries. There can be significant volatility in market prices for gas and oil, and price fluctuations could have a material effect on the financial performance of gas and oil producing and transmission assets. For example, in a low gas and oil price environment, NEER would generate less revenue from its gas infrastructure investments in gas and oil producing properties, and as a result certain investments might become less profitable or incur losses. Prolonged periods of low oil and gas prices could also result in oil and gas production and transmission projects to be delayed or cancelled or to experience lower returns, and for certain projects to become impaired, which could materially adversely affect NEE's results of operations.
If supply costs necessary to provide NEER's full energy and capacity requirement services are not favorable, operating costs could increase and materially adversely affect NEE's business, financial condition, results of operations and prospects.
NEER provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, to satisfy all or a portion of such utilities' power supply obligations to their customers. The supply costs for these transactions may be affected by a number of factors, including, but not limited to, events that may occur after such utilities have committed to supply power, such as weather conditions, fluctuating prices for energy and ancillary services, and the ability of the distribution utilities' customers to elect to receive service from competing suppliers. NEER may not be able to recover all of its increased supply costs, which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
Due to the potential for significant volatility in market prices for fuel, electricity and renewable and other energy commodities, NEER's inability or failure to manage properly or hedge effectively the commodity risks within its portfolios could materially adversely affect NEE's business, financial condition, results of operations and prospects.
There can be significant volatility in market prices for fuel, electricity and renewable and other energy commodities. NEE's inability or failure to manage properly or hedge effectively its assets or positions against changes in commodity prices, volumes, interest rates, counterparty credit risk or other risk measures, based on factors both from within, or wholly or partially outside of, NEE's control, may materially adversely affect NEE's business, financial condition, results of operations and prospects.
Sales
A portion of NEER's power generation facilities operate wholly or partially without long-term power purchase agreements. Power from these facilities is sold on the spot market or on a short-term contractual basis. Spot market sales are subject to market volatility, and the revenue generated from these sales is subject to fluctuation that may cause NEE's results of operations to be volatile. NEER and NEE may not be able to manage volatility adequately, which could then have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
Reductions in the liquidity of energy markets may restrict the ability of NEE to manage its operational risks, which, in turn, could negatively affect NEE's results of operations.
NEE is an active participant in energy markets. The liquidity of regional energy markets is an important factor in NEE's ability to manage risks in these operations. OverMarket liquidity is driven in part by the past several years, othernumber of active market participants, which has declined in recent years as some banks and other financial institutions have ceased or significantly reduced their activities in energy markets as a result of several factors, including, but not limited to, government investigations, changes in market design and deteriorating credit quality.withdrawn from power marketing. Liquidity in the energy markets can be adversely affected by price volatility, restrictions on the availability of credit and other factors, and any reduction in the liquidity of energy markets could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
NEE's and FPL's hedging and trading procedures and associated risk management tools may not protect against significant losses.
NEE and FPL have hedging and trading procedures and associated risk management tools, such as separate but complementary financial, credit, operational, compliance and legal reporting systems, internal controls, management review processes and other mechanisms. NEE and FPL are unable to assure that such procedures and tools will be effective against all potential risks, including, without limitation, employee misconduct. If such procedures and tools are not effective, this could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
If price movements significantly or persistently deviate from historical behavior, NEE's and FPL's risk management tools associated with their hedging and trading procedures may not protect against significant losses.
NEE's and FPL's risk management tools and metrics associated with their hedging and trading procedures, such as daily value at risk, earnings at risk, stop loss limits and liquidity guidelines, are based on historical price movements. Due to the inherent uncertainty involved in price movements and potential deviation from historical pricing behavior, NEE and FPL are unable to assure that their risk management tools and metrics will be effective to protect against material adverse effects on their business, financial condition, results of operations and prospects. Such adverse effects could be material.
If power transmission or natural gas, nuclear fuel or other commodity transportation facilities are unavailable or disrupted, FPL's and NEER's ability to sell and deliver power or natural gas may be limited.
FPL and NEER depend upon power transmission and natural gas, nuclear fuel and other commodity transportation facilities, many of which they do not own. Occurrences affecting the operation of these facilities that may or may not be beyond FPL's and NEER's control (such as severe weather or a generatorgeneration or transmission facility outage, pipeline rupture, or sudden and significant increase or decrease in wind generation) may limit or halt the ability of FPL and NEER to sell and deliver power and natural gas, or to purchase necessary fuels and other commodities, which could materially adversely impact NEE's and FPL's business, financial condition, results of operations and prospects.
NEE and FPL are subject to credit and performance risk from customers, hedging counterparties and vendors.
NEE and FPL are exposed to risks associated with the creditworthiness and performance of their customers, hedging counterparties and vendors under contracts for the supply of equipment, materials, fuel and other goods and services required for their business operations and for the construction and operation of, and for capital improvements to, their facilities. Adverse conditions in the energy industry or the general economy, as well as circumstances of individual customers, hedging counterparties and vendors, may adversely affect the ability of some customers, hedging counterparties and vendors to perform as required under their contracts with NEE and FPL. For example, the prolonged downturn in oil and natural gas prices has adversely affected the financial stability of a number of enterprises in the energy industry, including some with which NEE does business.
If any hedging, vending or other counterparty fails to fulfill its contractual obligations, NEE and FPL may need to make arrangements with other counterparties or vendors, which could result in material financial losses, higher costs, untimely completion of power generation facilities and other projects, and/or a disruption of their operations. If a defaulting counterparty is in poor financial condition, NEE and FPL may not be able to recover damages for any contract breach.
NEE and FPL could recognize financial losses or a reduction in operating cash flows if a counterparty fails to perform or make payments in accordance with the terms of derivative contracts or if NEE or FPL is required to post margin cash collateral under derivative contracts.
NEE and FPL use derivative instruments, such as swaps, options, futures and forwards, some of which are traded in the OTC markets or on exchanges, to manage their commodity and financial market risks, and for NEE to engage in trading and marketing activities. Any failures by their counterparties to perform or make payments in accordance with the terms of those transactions could have a material adverse effect on NEE's or FPL's business, financial condition, results of operations and prospects. Similarly, any requirement for FPL or NEE to post margin cash collateral under its derivative contracts could have a material adverse effect on its business, financial condition, results of operations and prospects. These risks may be increased during periods of adverse market or economic conditions affecting the industries in which NEE participates.
NEE and FPL are highly dependent on sensitive and complex information technology systems, and any failure or breach of those systems could have a material adverse effect on their business, financial condition, results of operations and prospects.
NEE and FPL operate in a highly regulated industry that requires the continuous functioning of sophisticated information technology systems and network infrastructure. Despite NEE's and FPL's implementation of security measures, all of their technology systems are vulnerable to disability, failures or unauthorized access due to such activities. If NEE's or FPL's information technology systems were to fail or be breached, sensitive confidential and other data could be compromised and NEE and FPL could be unable to fulfill critical business functions.
NEE's and FPL's business is highly dependent on their ability to process and monitor, on a daily basis, a very large number of transactions, many of which are highly complex and cross numerous and diverse markets. Due to the size, scope, complexity and geographical
reach of NEE's and FPL's business, and due to the complexity of the process of power generation, transmission and distribution, the development and maintenance of information technology systems to keep track of and process information is critical and challenging. NEE's and FPL's operating systems and facilities may fail to operate properly or become disabled as a result of events that are either within, or wholly or partially outside of, their control, such as operator error, severe weather or terrorist activities. Any such failure or disabling event could materially adversely affect NEE's and FPL's ability to process transactions and provide services, and their business, financial condition, results of operations and prospects.
NEE and FPL add, modify and replace information systems on a regular basis. Modifying existing information systems or implementing new or replacement information systems is costly and involves risks, including, but not limited to, integrating the modified, new or replacement system with existing systems and processes, implementing associated changes in accounting procedures and controls, and ensuring that data conversion is accurate and consistent. Any disruptions or deficiencies in existing information systems, or disruptions, delays or deficiencies in the modification or implementation of new information systems, could result in increased costs, the inability to track or collect revenues and the diversion of management's and employees' attention and resources, and could negatively impact the effectiveness of the companies' control environment, and/or the companies' ability to timely file required regulatory reports.
NEE and FPL also face the risks of operational failure or capacity constraints of third parties, including, but not limited to, those who provide power transmission and natural gas transportation services.
NEE's and FPL's retail businesses are subject to the risk that sensitive customer data may be compromised, which could result in a material adverse impact to their reputation and/or have a material adverse effect on the business, financial condition, results of operations and prospects of the retail business.NEE and FPL.
NEE's and FPL's retail businesses require access to sensitive customer data in the ordinary course of business. NEE's and FPL's retail businesses may also need to provide sensitive customer data to vendors and service providers who require access to this information in order to provide services, such as call center services, to the retail businesses. If a significant breach occurred, the reputation of NEE and FPL could be materially adversely affected, customer confidence could be diminished, or customer information could be subject to identity theft. NEE and FPL would be subject to costs associated with the breach and/or NEE and FPL could be subject to fines and legal claims, any of which may have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.
NEE and FPL could recognize financial losses as a result of volatility in the market values of derivative instruments and limited liquidity in OTC markets.
NEE and FPL execute transactions in derivative instruments on either recognized exchanges or via the OTC markets, depending on management's assessment of the most favorable credit and market execution factors. Transactions executed in OTC markets have the potential for greater volatility and less liquidity than transactions on recognized exchanges. As a result, NEE and FPL may not be able to execute desired OTC transactions due to such heightened volatility and limited liquidity.
In the absence of actively quoted market prices and pricing information from external sources, the valuation of derivative instruments involves management's judgment orand use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these derivative instruments and have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE and FPL may be materially adversely affected by negative publicity.
From time to time, political and public sentiment may result in a significant amount of adverse press coverage and other adverse public statements affecting NEE and FPL. Adverse press coverage and other adverse statements, whether or not driven by political or public sentiment, may also result in investigations by regulators, legislators and law enforcement officials or in legal claims. Responding to these investigations and lawsuits, regardless of the ultimate outcome of the proceeding, can divert the time and effort of senior management from NEE's and FPL's business.
Addressing any adverse publicity, governmental scrutiny or enforcement or other legal proceedings is time consuming and expensive and, regardless of the factual basis for the assertions being made, can have a negative impact on the reputation of NEE and FPL,
on the morale and performance of their employees and on their relationships with their respective regulators. It may also have a negative impact on their ability to take timely advantage of various business and market opportunities. The direct and indirect effects of negative publicity, and the demands of responding to and addressing it, may have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects may be materially adversely affected if FPL is unable to maintain, negotiate or renegotiate franchise agreements on acceptable terms with municipalities and counties in Florida.
FPL must negotiate franchise agreements with municipalities and counties in Florida to provide electric services within such municipalities and counties, and electricity sales generated pursuant to these agreements represent a very substantial portion of FPL's revenues. If FPL is unable to maintain, negotiate or renegotiate such franchise agreements on acceptable terms, it could
contribute to lower earnings and FPL may not fully realize the anticipated benefits from significant investments and expenditures, which could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
Increasing costs associated with health care plans may materially adversely affect NEE's and FPL's results of operations.
The costs of providing health care benefits to employees and retirees have increased substantially in recent years. NEE and FPL anticipate that their employee benefit costs, including, but not limited to, costs related to health care plans for employees and former employees, will continue to rise. The increasing costs and funding requirements associated with NEE's and FPL's health care plans may materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects could be negatively affected by the lack of a qualified workforce or the loss or retirement of key employees.
NEE and FPL may not be able to service customers, grow their business or generally meet their other business plan goals effectively and profitably if they do not attract and retain a qualified workforce. Additionally, the loss or retirement of key executives and other employees may materially adversely affect service and productivity and contribute to higher training and safety costs.
Over the next several years, a significant portion of NEE's and FPL's workforce, including, but not limited to, many workers with specialized skills maintaining and servicing the nuclear generation facilities and electrical infrastructure, will be eligible to retire. Such highly skilled individuals may not be able to be replaced quickly due to the technically complex work they perform. If a significant amount of such workers retire and are not replaced, the subsequent loss in productivity and increased recruiting and training costs could result in a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected by work strikes or stoppages and increasing personnel costs.
Employee strikes or work stoppages could disrupt operations and lead to a loss of revenue and customers. Personnel costs may also increase due to inflationary or competitive pressures on payroll and benefits costs and revised terms of collective bargaining agreements with union employees. These consequences could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's ability to successfully identify, complete and integrate acquisitions is subject to significant risks, including, but not limited to, the effect of increased competition for acquisitions resulting from the consolidation of the power industry.
NEE is likely to encounter significant competition for acquisition opportunities that may become available as a result of the consolidation of the power industry in general. In addition, NEE may be unable to identify attractive acquisition opportunities at favorable prices and to complete and integrate them successfully and in a timely manner.
NEP’s acquisitions may not be completed and, even if completed, NEE may not realize the anticipated benefits of any acquisitions, which could materially adversely affect NEE’s business, financial condition, results of operations and prospects.
NEE may not realize the anticipated benefits from the Texas pipeline business. Although NEP has made a number of acquisitions of wind and solar generation projects, the Texas pipeline business is the first third party acquisition by NEP and is NEP’s first acquisition of natural gas pipeline assets.
In the future NEP may make additional acquisitions of assets which are inherently risky and NEE may not realize the anticipated benefits of any acquisitions, which could materially adversely affect NEE’s business, financial condition, results of operations and prospects.
Nuclear Generation Risks
The construction, operation and maintenance of NEE's and FPL's nuclear generation facilities involve environmental, health and financial risks that could result in fines or the closure of the facilities and in increased costs and capital expenditures.
NEE's and FPL's nuclear generation facilities are subject to environmental, health and financial risks, including, but not limited to, those relating to site storage of spent nuclear fuel, the disposition of spent nuclear fuel, leakage and emissions of tritium and other radioactive elements in the event of a nuclear accident or otherwise, the threat of a terrorist attack and other potential liabilities arising out of the ownership or operation of the facilities. NEE and FPL maintain decommissioning funds and external insurance coverage which are intended to reduce the financial exposure to some of these risks; however, the cost of decommissioning nuclear generation facilities could exceed the amount available in NEE's and FPL's decommissioning funds, and the exposure to liability and property damages could exceed the amount of insurance coverage. If NEE or FPL is unable to recover the additional costs incurred through insurance or, in the case of FPL, through regulatory mechanisms, their business, financial condition, results of operations and prospects could be materially adversely affected.
In the event of an incident at any nuclear generation facility in the U.S. or at certain nuclear generation facilities in Europe, NEE and FPL could be assessed significant retrospective assessments and/or retrospective insurance premiums as a result of their participation in a secondary financial protection system and nuclear insurance mutual companies.
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 millionthe maximum amount 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 perfor an incident at any nuclear reactor in the U.S. Under the secondary
financial protection system, NEE is subject to retrospective assessments and/or retrospective insurance premiums, of up to $1 billion ($509 million for FPL), plus any applicable taxes, perfor an incident at any nuclear reactor in the U.S. or at certain nuclear generation facilities in Europe, regardless of fault or proximity to the incident, payable at a
rate not to exceed $152 million ($76 million for FPL) per incident per year.incident. Such assessments, if levied, could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
NRC orders or new regulations related to increased security measures and any future safety requirements promulgated by the NRC could require NEE and FPL to incur substantial operating and capital expenditures at their nuclear generation facilities.facilities and/or result in reduced revenues.
The NRC has broad authority to impose licensing and safety-related requirements for the operation and maintenance of nuclear generation facilities, the addition of capacity at existing nuclear generation facilities and the construction of new nuclear generation facilities, and these requirements are subject to change. In the event of non-compliance, the NRC has the authority to impose fines and/or shut down a nuclear generation facility, or to take both of these actions, depending upon itsthe NRC's assessment of the severity of the situation, until compliance is achieved. Any of the foregoing events could require NEE and FPL to incur increased costs and capital expenditures, and could reduce revenues.
Any serious nuclear incident occurring at a NEE or FPL plant could result in substantial remediation costs and other expenses. A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation or licensing of any domestic nuclear generation facility. An incident at a nuclear facility anywhere in the world also could cause the NRC to impose additional conditions or other requirements on the industry, or on certain types of nuclear generation units, which could increase costs, reduce revenues and result in additional capital expenditures.
The inability to operate any of NEER'sNEE's or FPL's nuclear generation units through the end of their respective operating licenses could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
The operating licenses for NEE's and FPL's nuclear generation facilities extend through at least 2030. If the facilities cannot be operated for any reason through the life of those operating licenses, NEE or FPL may be required to increase depreciation rates, incur impairment charges and accelerate future decommissioning expenditures, any of which could materially adversely affect their business, financial condition, results of operations and prospects.
Various hazards posed to nuclear generation facilities, along with increased public attention to and awareness of such hazards, could result in increased nuclear licensing or compliance costs which are difficult or impossible to predict and could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
The threat of terrorist activity, as well as recent international events implicating the safety of nuclear facilities, could result in more stringent or complex measures to keep facilities safe from a variety of hazards, including, but not limited to, natural disasters such as earthquakes and tsunamis, as well as terrorist or other criminal threats. This increased focus on safety could result in higher compliance costs which, at present, cannot be assessed with any measure of certainty and which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE's and FPL's nuclear units are periodically removed from service to accommodate normalplanned refueling and maintenance outages, and for other purposes. If planned outages last longer than anticipated or if there are unplanned outages, NEE's and FPL's results of operations and financial condition could be materially adversely affected.
NEE's and FPL's nuclear units are periodically removed from service to accommodate normalplanned refueling and maintenance outages, including, but not limited to, inspections, repairs and certain other modifications. In addition, outages may be scheduled, often in connection with a refueling outage,modifications as well as to replace equipment, to increase the generation capacity at a particular nuclear unit, or for other purposes, and those planned activities increase the time the unit is not in operation.equipment. In the event that a scheduled outage lasts longer than anticipated or in the event of an unplanned outage due to, for example, equipment failure, such outages could materially adversely affect NEE's or FPL's business, financial condition, results of operations and prospects.
Liquidity, Capital Requirements and Common Stock Risks
Disruptions, uncertainty or volatility in the credit and capital markets may negatively affect NEE's and FPL's ability to fund their liquidity and capital needs and to meet their growth objectives, and can also materially adversely affect the results of operations and financial condition of NEE and FPL.
NEE and FPL rely on access to capital and credit markets as significant sources of liquidity for capital requirements and other operations requirements that are not satisfied by operating cash flows. Disruptions, uncertainty or volatility in those capital and credit markets including, but not limited to, the conditions of the most recent financial crises in the U.S. and abroad, could increase NEE's and FPL's cost of capital.capital and affect their ability to fund their liquidity and capital needs and to meet their growth objectives. If NEE or FPL is unable to access regularly the capital and credit markets on terms that are reasonable, it may have to delay raising capital, issue shorter-term securities and incur an unfavorable cost of capital, which, in turn, could adversely affect its ability to grow its business, could contribute to lower earnings and reduced financial flexibility, and could have a material adverse effect on its business, financial condition, results of operations and prospects.
Although NEE's competitive energy and certain other subsidiaries have used non-recourse or limited-recourse, project-specific or other financing in the past, market conditions and other factors could adversely affect the future availability of such financing. The inability of NEE's subsidiaries,
including, without limitation, NEECH and NEP and their respective subsidiaries, to access the capital and credit markets to provide project-specific or other financing for electric-generating andelectric generation or other energy facilities or acquisitions on favorable terms, whether because of disruptions or volatility in those markets or otherwise, could necessitate additional capital raising or borrowings by NEE and/or NEECH in the future.
The inability of subsidiaries that have existing project-specific or other financing arrangements to meet the requirements of various agreements relating to those financings could give rise to a project-specific financing default which, if not cured or waived, might result in the specific project, and potentially in some limited instances its parent companies, being required to repay the associated debt or other borrowings earlier than otherwise anticipated, and if such repayment were not made, the lenders or security holders
would generally have rights to foreclose against the project assets and related collateral. Such an occurrence also could result in NEE expending additional funds or incurring additional obligations over the shorter term to ensure continuing compliance with project-specific financing arrangements based upon the expectation of improvement in the project's performance or financial returns over the longer term. Any of these actions could materially adversely affect NEE's business, financial condition, results of operations and prospects, as well as the availability or terms of future financings for NEE or its subsidiaries.
NEE's, NEECH's and FPL's inability to maintain their current credit ratings may materially adversely affect NEE's and FPL's liquidity and results of operations, limit the ability of NEE and FPL to grow their business, and increase interest costs.
The inability of NEE, NEECH and FPL to maintain their current credit ratings could materially adversely affect their ability to raise capital or obtain credit on favorable terms, which, in turn, could impact NEE's and FPL's ability to grow their business and service indebtedness and repay borrowings, and would likely increase their interest costs. In addition, certain agreements and guarantee arrangements would require posting of additional collateral in the event of a ratings downgrade. Some of the factors that can affect credit ratings are cash flows, liquidity, the amount of debt as a component of total capitalization, NEE's overall business mix and political, legislative and regulatory actions. There can be no assurance that one or more of the ratings of NEE, NEECH and FPL will not be lowered or withdrawn entirely by a rating agency.
NEE's and FPL's liquidity may be impaired if their creditorscredit providers are unable to fund their credit commitments to the companies or to maintain their current credit ratings.
The inability of NEE's, NEECH's and FPL's credit providers to fund their credit commitments or to maintain their current credit ratings could require NEE, NEECH or FPL, among other things, to renegotiate requirements in agreements, find an alternative credit provider with acceptable credit ratings to meet funding requirements, or post cash collateral and could have a material adverse effect on NEE's and FPL's liquidity.
Poor market performance and other economic factors could affect NEE's defined benefit pension plan's funded status, which may materially adversely affect NEE's and FPL's business, financial condition, liquidity and results of operations and prospects.
NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. A decline in the market value of the assets held in the defined benefit pension plan due to poor investment performance or other factors may increase the funding requirements for this obligation.
NEE's defined benefit pension plan is sensitive to changes in interest rates, since, as interest rates decrease the funding liabilities increase, potentially increasing benefits costs and funding requirements. Any increase in benefits costs or funding requirements may have a material adverse effect on NEE's and FPL's business, financial condition, liquidity, results of operations and prospects.
Poor market performance and other economic factors could adversely affect the asset values of NEE's and FPL's nuclear decommissioning funds, which may materially adversely affect NEE's and FPL's liquidity, financial condition and results of operations.
NEE and FPL are required to maintain decommissioning funds to satisfy their future obligations to decommission their nuclear power plants. A decline in the market value of the assets held in the decommissioning funds due to poor investment performance or other factors may increase the funding requirements for these obligations. Any increase in funding requirements may have a material adverse effect on NEE's and FPL's business,liquidity, financial condition and results of operations and prospects.operations.
Certain of NEE's investments are subject to changes in market value and other risks, which may materially adversely affect NEE's liquidity, financial resultscondition and results of operations.
NEE holds othercertain investments where changes in the fair value affect NEE's financial results. In some cases there may be no observable market values for these investments, requiring fair value estimates to be based on other valuation techniques. This type of analysis requires significant judgment and the actual values realized in a sale of these investments could differ materially from those estimated. A sale of an investment below previously estimated value, or other decline in the fair value of an investment, could result in losses or the write-off of such investment, and may have a material adverse effect on NEE's liquidity, financial condition and results of operations.
NEE may be unable to meet its ongoing and future financial obligations and to pay dividends on its common stock if its subsidiaries are unable to pay upstream dividends or repay funds to NEE.
NEE is a holding company and, as such, has no material operations of its own. Substantially all of NEE's consolidated assets are held by its subsidiaries. NEE's ability to meet its financial obligations, including, but not limited to, its guarantees, and to pay dividends on its common stock is primarily dependent on its subsidiaries' net income and cash flows, which are subject to the risks of their respective businesses, and their ability to pay upstream dividends or to repay funds to NEE.
NEE's subsidiaries are separate legal entities and have no independent obligation to provide NEE with funds for its payment obligations. The subsidiaries have financial obligations, including, but not limited to, payment of debt service, which they must satisfy
before they can provide NEE with funds. In addition, in the event of a subsidiary's liquidation or reorganization, NEE's right to participate in a distribution of assets is subject to the prior claims of the subsidiary's creditors.
The dividend-paying ability of some of the subsidiaries is limited by contractual restrictions which are contained in outstanding financing agreements and which may be included in future financing agreements. The future enactment of laws or regulations also may prohibit or restrict the ability of NEE's subsidiaries to pay upstream dividends or to repay funds.
NEE may be unable to meet its ongoing and future financial obligations and to pay dividends on its common stock if NEE is required to perform under guarantees of obligations of its subsidiaries.
NEE guarantees many of the obligations of its consolidated subsidiaries, other than FPL, through guarantee agreements with NEECH. These guarantees may require NEE to provide substantial funds to its subsidiaries or their creditors or counterparties at a time when NEE is in need of liquidity to meet its own financial obligations. Funding such guarantees may materially adversely affect NEE's ability to meet its financial obligations or to pay dividends.
NEP may not be able to access sources of capital on commercially reasonable terms, which would have a material adverse effect on its ability to consummate future acquisitions and on the value of NEE’s limited partner interest in NEP OpCo.
NEE understands that NEP expects to finance acquisitions of clean energy projects partially or wholly through the issuance of additional common units. NEP needs to be able to access the capital markets on commercially reasonable terms when acquisition opportunities arise. NEP's ability to access the equity capital markets is dependent on, among other factors, the overall state of the capital markets and investor appetite for investment in clean energy projects in general and NEP's common units in particular. An inability to obtain equity financing on commercially reasonable terms could limit NEP's ability to consummate future acquisitions and to effectuate its growth strategy in the manner currently contemplated. Furthermore there may not be sufficient availability under NEP OpCo's subsidiaries' revolving credit facility or other financing arrangements on commercially reasonable terms when acquisition opportunities arise. If debt financing is available, it may be available only on terms that could significantly increase NEP's interest expense, impose additional or more restrictive covenants and reduce cash distributions to its unitholders. An inability to access sources of capital on commercially reasonable terms could significantly limit NEP's ability to consummate future acquisitions and to effectuate its growth strategy. NEP's inability to effectively consummate future acquisitions could have a material adverse effect on NEP's ability to grow its business and make cash distributions to its unitholders.
Through an indirect wholly owned subsidiary, NEE owns a limited partner interest in NEP OpCo. NEP's inability to access the capital markets on commercially reasonable terms and effectively consummate future acquisitions could have a material adverse effect on NEP's ability to grow its cash distributions to its unitholders, including NEE, and on the value of NEE’s limited partnership interest in NEP OpCo.
Disruptions, uncertainty or volatility in the credit and capital markets may exert downward pressure on the market price of NEE's common stock.
The market price and trading volume of NEE's common stock are subject to fluctuations as a result of, among other factors, general credit and capital market conditions and changes in market sentiment regarding the operations, business and financing strategies of NEE and its subsidiaries. As a result, disruptions, uncertainty or volatility in the credit and capital markets may, for example, have a material adverse effect on the market price of NEE's common stock.
Item 1B. Unresolved Staff Comments
None
Item 2. Properties
NEE and its subsidiaries maintain properties which are adequate for their operations; theFor a description of NEE's principal properties, are described below.
Generating Facilities
see Item 1. Business - FPL
At December 31, 2013, the electric generating, transmission, distribution and general facilities of FPL represented approximately 51%, 11%, 33% and 5%, respectively, of FPL's gross investment in electric utility plant in service and other property. At December 31, 2013, FPL had the following generating facilities:
|
| | | | | | | | | | |
| FPL Facilities | | Location | | No. of Units | | Fuel | | Net Capability (MW)(a) |
| Fossil | | | | | | | | | |
| Combined-cycle | | | | | | | | | |
| Cape Canaveral | | Cocoa, FL | | 1 | | Gas/Oil | | 1,210 |
| |
| Fort Myers | | Fort Myers, FL | | 1 | | Gas | | 1,432 |
| |
| Lauderdale | | Dania, FL | | 2 | | Gas/Oil | | 884 |
| |
| Manatee | | Parrish, FL | | 1 | | Gas | | 1,111 |
| |
| Martin | | Indiantown, FL | | 1 | | Gas/Oil/Solar Thermal | | 1,141 |
| (b) |
| Martin | | Indiantown, FL | | 2 | | Gas | | 938 |
| |
| Putnam | | Palatka, FL | | 2 | | Gas/Oil | | 498 |
| |
| Sanford | | Lake Monroe, FL | | 2 | | Gas | | 1,980 |
| |
| Turkey Point | | Florida City, FL | | 1 | | Gas/Oil | | 1,148 |
| |
| West County | | West Palm Beach, FL | | 3 | | Gas/Oil | | 3,657 |
| |
| | | | | | | | | | |
| Steam turbines | | | | | | | | | |
| Manatee | | Parrish, FL | | 2 | | Gas/Oil | | 1,618 |
| |
| Martin | | Indiantown, FL | | 2 | | Gas/Oil | | 1,652 |
| |
| St. Johns River Power Park | | Jacksonville, FL | | 2 | | Coal/Petroleum Coke | | 254 |
| (c) |
| Scherer | | Monroe County, GA | | 1 | | Coal | | 643 |
| (d) |
| Turkey Point | | Florida City, FL | | 1 | | Gas/Oil | | 396 |
| |
| | | | | | | | | | |
| Simple-cycle combustion turbines | | | | | | | | | |
| Fort Myers | | Fort Myers, FL | | 2 | | Gas/Oil | | 315 |
| |
| | | | | | | | | | |
| Gas turbines | | | | | | | | | |
| Fort Myers | | Fort Myers, FL | | 12 | | Oil | | 648 |
| |
| Lauderdale | | Dania, FL | | 24 | | Gas/Oil | | 840 |
| |
| Port Everglades | | Port Everglades, FL | | 12 | | Gas/Oil | | 420 |
| |
| | | | | | | | | | |
| Nuclear | | | | | | | | | |
| St. Lucie | | Hutchinson Island, FL | | 2 | | Nuclear | | 1,821 |
| (e) |
| Turkey Point | | Florida City, FL | | 2 | | Nuclear | | 1,632 |
| |
| | | | | | | | | | |
| Solar PV | | | | | | | | | |
| DeSoto | | Arcadia, FL | | 1 | | Solar PV | | 25 |
| |
| Space Coast | | Cocoa, FL | | 1 | | Solar PV | | 10 |
| |
| TOTAL | | | | | | | | 24,273 |
| (f) |
______________________
| |
(a) | Represents FPL's net ownership interest in warm weather peaking capability. |
| |
(b) | The megawatts generated by the 75 MW solar thermal hybrid facility replace steam produced by this unit and therefore are not incremental. |
| |
(c) | Represents FPL's 20% ownership interest in each of SJRPP Units Nos. 1 and 2, which are jointly owned with JEA. |
| |
(d) | Represents FPL's approximately 76% ownership of Scherer Unit No. 4, which is jointly owned with JEA. |
| |
(e) | Excludes Orlando Utilities Commission's and the Florida Municipal Power Agency's combined share of approximately 15% of St. Lucie Unit No. 2. |
| |
(f) | Substantially all of FPL's properties are subject to the lien of FPL's mortgage. |
NEER
At December 31, 2013, NEER had the following generating facilities:
|
| | | | | | | | | | | | |
| NEER Facilities | | Location | | Geographic Region | | No. of Units | | Fuel | | Net Capability (MW)(a) |
| Wind | | | | | | | | | | | |
Ashtabula Wind(b)(c) | | Barnes County, ND | | Midwest | | 99 |
| | Wind | | 148 | |
Ashtabula Wind II(c)(d) | | Griggs & Steele Counties, ND | | Midwest | | 80 |
| | Wind | | 120 | |
| Ashtabula Wind III | | Barnes County, ND | | Midwest | | 39 |
| | Wind | | 62 | |
Baldwin Wind(b) | | Burleigh County, ND | | Midwest | | 64 |
| | Wind | | 102 | |
Blackwell Wind(c)(d) | | Kay County, OK | | Other South | | 26 |
| | Wind | | 60 | |
Blue Summit(c) | | Wilbarger County, TX | | Texas | | 85 |
| | Wind | | 135 | |
| Buffalo Ridge | | Lincoln County, MN | | Midwest | | 73 |
| | Wind | | 26 | |
Butler Ridge Wind(b)(c) | | Dodge County, WI | | Midwest | | 36 |
| | Wind | | 54 | |
Cabazon(b) | | Riverside County, CA | | West | | 52 |
| | Wind | | 39 | |
Callahan Divide(b) | | Taylor County, TX | | Texas | | 76 |
| | Wind | | 114 | |
Capricorn Ridge(c) | | Sterling & Coke Counties, TX | | Texas | | 208 |
| | Wind | | 364 | |
Capricorn Ridge Expansion(c) | | Sterling & Coke Counties, TX | | Texas | | 199 |
| | Wind | | 298 | |
Cerro Gordo(b) | | Cerro Gordo County, IA | | Midwest | | 55 |
| | Wind | | 41 | |
Cimarron(b) | | Gray County, KS | | Other South | | 72 |
| | Wind | | 166 | |
Conestogo Wind(b) | | Wellington County, Ontario, Canada | | Canada | | 10 |
| | Wind | | 23 | |
Crystal Lake I(b)(c) | | Hancock County, IA | | Midwest | | 100 |
| | Wind | | 150 | |
| Crystal Lake II | | Winnebago County, IA | | Midwest | | 80 |
| | Wind | | 200 | |
| Crystal Lake III | | Winnebago County, IA | | Midwest | | 44 |
| | Wind | | 66 | |
Day County Wind(b) | | Day County, SD | | Midwest | | 66 |
| | Wind | | 99 | |
| Delaware Mountain | | Culberson County, TX | | Texas | | 38 |
| | Wind | | 28 | |
Diablo Wind(b) | | Alameda County, CA | | West | | 31 |
| | Wind | | 21 | |
Elk City Wind(b) | | Roger Mills & Beckham Counties, OK | | Other South | | 43 |
| | Wind | | 99 | |
| Elk City Wind II | | Roger Mills & Beckham Counties, OK | | Other South | | 66 |
| | Wind | | 101 | |
| Endeavor Wind | | Osceola County, IA | | Midwest | | 40 |
| | Wind | | 100 | |
| Endeavor Wind II | | Osceola County, IA | | Midwest | | 20 |
| | Wind | | 50 | |
| Ensign Wind | | Gray County, KS | | Other South | | 43 |
| | Wind | | 99 | |
| Ghost Pine Wind | | Kneehill County, Alberta, Canada | | Canada | | 51 |
| | Wind | | 82 | |
| Gray County | | Gray County, KS | | Other South | | 170 |
| | Wind | | 112 | |
Green Mountain(b) | | Somerset County, PA | | Northeast | | 8 |
| | Wind | | 10 | |
| Green Power | | Riverside County, CA | | West | | 22 |
| | Wind | | 17 | |
| Green Ridge Power | | Alameda & Contra Costa Counties, CA | | West | | 803 |
| | Wind | | 87 | |
Hancock County(b) | | Hancock County, IA | | Midwest | | 148 |
| | Wind | | 98 | |
High Winds(b) | | Solano County, CA | | West | | 90 |
| | Wind | | 162 | |
Horse Hollow Wind(b) | | Taylor County, TX | | Texas | | 142 |
| | Wind | | 213 | |
Horse Hollow Wind II(b) | | Taylor & Nolan Counties, TX | | Texas | | 130 |
| | Wind | | 299 | |
Horse Hollow Wind III(b) | | Nolan County, TX | | Texas | | 149 |
| | Wind | | 224 | |
| Indian Mesa | | Pecos County, TX | | Texas | | 125 |
| | Wind | | 83 | |
King Mountain(b) | | Upton County, TX | | Texas | | 214 |
| | Wind | | 278 | |
Lake Benton II(b) | | Pipestone County, MN | | Midwest | | 137 |
| | Wind | | 103 | |
Langdon Wind(b)(c) | | Cavalier County, ND | | Midwest | | 79 |
| | Wind | | 118 | |
Langdon Wind II(b)(c) | | Cavalier County, ND | | Midwest | | 27 |
| | Wind | | 41 | |
| Lee / DeKalb Wind | | Lee & DeKalb Counties, IL | | Midwest | | 145 |
| | Wind | | 217 | |
Limon I(c)(d) | | Lincoln, Elbert & Arapahoe Counties, CO | | West | | 125 |
| | Wind | | 200 | |
Limon II(c)(d) | | Lincoln, Elbert & Arapahoe Counties, CO | | West | | 125 |
| | Wind | | 200 | |
Logan Wind(c) | | Logan County, CO | | West | | 134 |
| | Wind | | 201 | |
Majestic Wind(b)(c) | | Carson County, TX | | Texas | | 53 |
| | Wind | | 80 | |
Majestic Wind II(c) | | Carson & Potter Counties, TX | | Texas | | 51 |
| | Wind | | 79 | |
Meyersdale(b) | | Somerset County, PA | | Northeast | | 20 |
| | Wind | | 30 | |
Mill Run(b) | | Fayette County, PA | | Northeast | | 10 |
| | Wind | | 15 | |
Minco Wind(b) | | Grady County, OK | | Other South | | 62 |
| | Wind | | 99 | |
Minco Wind II(b) | | Grady & Caddo Counties, OK | | Other South | | 63 |
| | Wind | | 101 | |
Minco Wind III(c)(d) | | Grady, Caddo & Canadian Counties, OK | | Other South | | 63 |
| | Wind | | 101 | |
| Mojave 3/4/5 | | Kern County, CA | | West | | 246 |
| | Wind | | 41 | |
Montezuma Wind(b) | | Solano County, CA | | West | | 16 |
| | Wind | | 37 | |
Montezuma Wind II(c)(d) | | Solano County, CA | | West | | 34 |
| | Wind | | 78 | |
Mount Copper(b) | | Gaspésie, Quebec, Canada | | Canada | | 30 |
| | Wind | | 54 | |
|
| | | | | | | | | | | | |
| NEER Facilities | | Location | | Geographic Region | | No. of Units | | Fuel | | Net Capability (MW)(a) |
Mount Miller(b) | | Gaspésie, Quebec, Canada | | Canada | | 30 |
| | Wind | | 54 | |
Mountaineer Wind(b) | | Preston & Tucker Counties, WV | | Northeast | | 44 |
| | Wind | | 66 | |
Mower County Wind(c) | | Mower County, MN | | Midwest | | 43 |
| | Wind | | 99 | |
New Mexico Wind(b) | | Quay & Debaca Counties, NM | | West | | 136 |
| | Wind | | 204 | |
North Dakota Wind(b) | | LaMoure County, ND | | Midwest | | 41 |
| | Wind | | 62 | |
North Sky River(b) | | Kern County, CA | | West | | 100 |
| | Wind | | 162 | |
Northern Colorado(b) | | Logan County, CO | | West | | 81 |
| | Wind | | 174 | |
Oklahoma / Sooner Wind(b) | | Harper & Woodward Counties, OK | | Other South | | 68 |
| | Wind | | 102 | |
Oliver County Wind I(c) | | Oliver County, ND | | Midwest | | 22 |
| | Wind | | 51 | |
Oliver County Wind II(c) | | Oliver County, ND | | Midwest | | 32 |
| | Wind | | 48 | |
Peetz Table Wind(c) | | Logan County, CO | | West | | 133 |
| | Wind | | 199 | |
Perrin Ranch Wind(b) | | Coconino County, AZ | | West | | 62 |
| | Wind | | 99 | |
| Pheasant Run I | | Huron County, MI | | Midwest | | 44 |
| | Wind | | 75 | |
Pubnico Point(b) | | Yarmouth County, Nova Scotia, Canada | | Canada | | 17 |
| | Wind | | 31 | |
Red Canyon Wind(b) | | Borden, Garza & Scurry Counties, TX | | Texas | | 56 |
| | Wind | | 84 | |
| Red Mesa Wind | | Cibola County, NM | | West | | 64 |
| | Wind | | 102 | |
Sky River(b) | | Kern County, CA | | West | | 322 |
| | Wind | | 73 | |
Somerset Wind Power(b) | | Somerset County, PA | | Northeast | | 6 |
| | Wind | | 9 | |
South Dakota Wind(b) | | Hyde County, SD | | Midwest | | 27 |
| | Wind | | 41 | |
Southwest Mesa(b) | | Upton & Crockett Counties, TX | | Texas | | 106 |
| | Wind | | 74 | |
Stateline(b) | | Umatilla County, OR and Walla Walla County, WA | | West | | 454 |
| | Wind | | 300 | |
Steele Flats(c)(d) | | Jefferson & Gage Counties, NE | | Other South | | 44 |
| | Wind | | 75 | |
Story County Wind(b)(c) | | Story County, IA | | Midwest | | 100 |
| | Wind | | 150 | |
Story County Wind II(b) | | Story & Hardin Counties, IA | | Midwest | | 100 |
| | Wind | | 150 | |
Summerhaven(b) | | Haldimand County, Ontario, Canada | | Canada | | 56 |
| | Wind | | 124 | |
Tuscola Bay(b) | | Tuscola, Bay & Saginaw Counties, MI | | Midwest | | 75 |
| | Wind | | 120 | |
| Tuscola II | | Tuscola & Bay Counties, MI | | Midwest | | 59 |
| | Wind | | 100 | |
Vansycle(b) | | Umatilla County, OR | | West | | 38 |
| | Wind | | 25 | |
| Vansycle II | | Umatilla County, OR | | West | | 43 |
| | Wind | | 99 | |
Vasco Winds(c)(d) | | Contra Costa County, CA | | West | | 33 |
| | Wind | | 78 | |
Waymart(b) | | Wayne County, PA | | Northeast | | 43 |
| | Wind | | 65 | |
Weatherford Wind(b) | | Custer & Washita Counties, OK | | Other South | | 98 |
| | Wind | | 147 | |
Wessington Springs Wind(b)(c) | | Jerauld County, SD | | Midwest | | 34 |
| | Wind | | 51 | |
White Oak(c)(d) | | McLean County, IL | | Midwest | | 100 |
| | Wind | | 150 | |
Wilton Wind(b) | | Burleigh County, ND | | Midwest | | 33 |
| | Wind | | 49 | |
Wilton Wind II(c)(d) | | Burleigh County, ND | | Midwest | | 33 |
| | Wind | | 50 | |
| Windpower Partners 1990 | | Alameda & Contra Costa Counties, CA | | West | | 141 |
| | Wind | | 14 | |
| Windpower Partners 1991 | | Alameda & Contra Costa Counties, CA | | West | | 162 |
| | Wind | | 16 | |
| Windpower Partners 1991-92 | | Alameda & Contra Costa Counties, CA | | West | | 223 |
| | Wind | | 22 | |
| Windpower Partners 1992 | | Alameda & Contra Costa Counties, CA | | West | | 300 |
| | Wind | | 30 | |
Windpower Partners 1993(c)(d) | | Riverside County, CA | | West | | 33 |
| | Wind | | 50 | |
| Windpower Partners 1994 | | Culberson County, TX | | Texas | | 107 |
| | Wind | | 39 | |
Wolf Ridge Wind(c) | | Cooke County, TX | | Texas | | 75 |
| | Wind | | 112 | |
| Woodward Mountain | | Upton & Pecos Counties, TX | | Texas | | 242 |
| | Wind | | 160 | |
| Total Wind | | | | | | | | | | 10,210 | |
| Contracted | | | | | | | | | | | |
Bayswater(b) | | Far Rockaway, NY | | Northeast | | 2 |
| | Gas | | 56 | |
| Duane Arnold | | Palo, IA | | Midwest | | 1 |
| | Nuclear | | 431 | (e) |
Genesis(b) | | Riverside County, CA | | West | | 1 |
| | Solar Thermal | | 125 | |
| Hatch Solar | | Hatch, NM | | West | | 1 |
| | Solar CPV | | 5 | |
Jamaica Bay(b) | | Far Rockaway, NY | | Northeast | | 2 |
| | Gas/Oil | | 54 | |
Marcus Hook 750(b) | | Marcus Hook, PA | | Northeast | | 4 |
| | Gas | | 744 | |
Moore Solar(b) | | Lambton County, Ontario, Canada | | Canada | | 1 |
| | Solar PV | | 20 | |
Planta Termosolar I & II(b) | | Madrigalejo, Spain | | Other | | 2 |
| | Solar Thermal | | 100 | |
| Point Beach | | Two Rivers, WI | | Midwest | | 2 |
| | Nuclear | | 1,190 | |
Sombra Solar(b) | | Lambton County, Ontario, Canada | | Canada | | 1 |
| | Solar PV | | 20 | |
| Investments in joint ventures: | | | | | | | | | | | |
Desert Sunlight(b) | | Riverside County, CA | | West | | 1 |
| | Solar PV | | 155 | |
SEGS III-IX(b) | | Kramer Junction & Harper Lake, CA | | West | | 7 |
| | Solar Thermal | | 147 | |
| Bellingham | | Bellingham, MA | | Northeast | | 3 |
| | Gas | | 149 | |
| Total Contracted | | | | | | | | | | 3,196 | |
|
| | | | | | | | | | | | |
| NEER Facilities | | Location | | Geographic Region | | No. of Units | | Fuel | | Net Capability (MW)(a) |
| | | | | | | | | | | | |
| Merchant | | | | | | | | | | | |
Forney(b) | | Forney, TX | | Texas | | 8 |
| | Gas | | 1,792 | |
Lamar Power Partners(b) | | Paris, TX | | Texas | | 6 |
| | Gas | | 1,000 | |
| Maine - Cape, Wyman | | Various - ME | | Northeast | | 6 |
| | Oil | | 796 | (f) |
| Marcus Hook 50 | | Marcus Hook, PA | | Northeast | | 1 |
| | Gas | | 50 | |
| Paradise Solar | | West Deptford, NJ | | Northeast | | 1 |
| | Solar PV | | 5 | |
| Seabrook | | Seabrook, NH | | Northeast | | 1 |
| | Nuclear | | 1,100 | (g) |
| Investment in joint venture | | Various | | Northeast | | 4 |
| | (h) | | 154 | |
| Total Merchant | | | | | | | | | | 4,897 | |
| TOTAL | | | | | | | | | | 18,303 | |
______________________
| |
(a) | Represents NEER's net ownership interest in plant capacity. |
| |
(b) | These generating facilities are encumbered by liens against their assets securing various financings. |
| |
(c) | NEER owns these wind facilities together with third-party investors with differential membership interests. See Note 1 - Sale of Differential Membership Interests. |
| |
(d) | Various financings are secured by the pledge of NEER's membership interests in the entities owning these wind facilities. |
| |
(e) | Excludes Central Iowa Power Cooperative and Corn Belt Power Cooperative's combined share of 30%. |
| |
(f) | Excludes six other energy-related partners' combined share of 16%. Also, see Note 6. |
| |
(g) | Excludes Massachusetts Municipal Wholesale Electric Company's, Taunton Municipal Lighting Plant's and Hudson Light & Power Department's combined share of 11.77%. |
| |
(h) | Represents plants with no more than 50% ownership using fuels such as natural gas and waste coal. |
Transmission and Distribution
At December 31, 2013, FPL owned and operated 589 substations and the following electric transmission and distribution lines:
|
| | | | | | | |
Nominal Voltage | | Overhead Lines Circuit/Pole Miles | | Trench and Submarine Cables Miles |
| 500 | kV | | 1,106 |
| (a) | — |
|
| 230 | kV | | 3,127 |
| | 25 |
|
| 138 | kV | | 1,580 |
| | 52 |
|
| 115 | kV | | 757 |
| | — |
|
| 69 | kV | | 164 |
| | 14 |
|
| Total circuit miles | | 6,734 |
| | 91 |
|
| Less than 69 kV (pole miles) | | 42,327 |
| | 25,322 |
|
______________________
(a) Includes approximately 75 miles owned jointly with JEA.
At December 31, 2013, NEER owned and operated 154 substations and approximately 839 circuit miles of transmission lines ranging from 115 kV to 345 kV and NEET owned and operated 6 substations and approximately 624 circuit miles of 345 kV transmission lines.Item 1. Business - NEER.
Character of Ownership
Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. The majority of FPL's real property is held in fee and is free from other encumbrances, subject to minor exceptions which are not of a nature as to substantially impair the usefulness to FPL of such properties. Some of FPL's electric lines are located on parcels of land which are not owned in fee by FPL but are covered by necessary consents of governmental authorities or rights obtained from owners of private property. The majority of NEER's generatinggeneration facilities, pipeline facilities and transmission assets are owned by NEER subsidiaries and a number of those facilities and assets, including all of the Texas pipelines, are encumbered by liens securing various financings. Additionally, somethe majority of NEER's generatinggeneration facilities, pipeline facilities and transmission lines are located on land leased from owners of private property. NEET’s transmission assets are encumbered by liens securing financings and some of its transmission lines are located on land leasedor under easement from owners of private property. See Generating Facilities and Note 1 - Electric Plant, Depreciation and Amortization.
Item 3. Legal Proceedings
None
Item 4. Mine Safety Disclosures
Not applicable
Item 3. Legal Proceedings
NEE and FPL are parties to various legal and regulatory proceedings in the ordinary course of their respective businesses. For information regarding legal proceedings that could have a material adverse effect on NEE or FPL, see Note 13 - Spain Solar Projects and - Legal Proceedings. Such descriptions are incorporated herein by reference.
Item 4. Mine Safety Disclosures
Not applicable
PART II
Item 5. Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Common Stock Data.All of FPL's common stock is owned by NEE. NEE's common stock is traded on the New York Stock Exchange under the symbol "NEE." The high and low sales prices for the common stock of NEE as reported in the consolidated transaction reporting system of the New York Stock Exchange and the cash dividends per share declared for each quarter during the past two years are as follows:
| | | | | 2013 | | 2012 | | 2016 | | 2015 |
| Quarter | | High | | Low | | Cash Dividends | | High | | Low | | Cash Dividends | | High | | Low | | Cash Dividends | | High | | Low | | Cash Dividends |
| First | | $ | 77.79 |
| | $ | 69.81 |
| | $ | 0.66 |
| | $ | 61.21 |
| | $ | 58.57 |
| | $ | 0.60 |
| | $ | 119.37 |
| | $ | 102.20 |
| | $ | 0.87 |
| | $ | 112.64 |
| | $ | 97.48 |
| | $ | 0.77 |
|
| Second | | $ | 82.65 |
| | $ | 74.78 |
| | $ | 0.66 |
| | $ | 68.96 |
| | $ | 61.20 |
| | $ | 0.60 |
| | $ | 130.43 |
| | $ | 112.44 |
| | $ | 0.87 |
| | $ | 106.63 |
| | $ | 97.23 |
| | $ | 0.77 |
|
| Third | | $ | 88.39 |
| | $ | 78.81 |
| | $ | 0.66 |
| | $ | 72.22 |
| | $ | 65.95 |
| | $ | 0.60 |
| | $ | 131.98 |
| | $ | 120.22 |
| | $ | 0.87 |
| | $ | 109.98 |
| | $ | 93.74 |
| | $ | 0.77 |
|
| Fourth | | $ | 89.75 |
| | $ | 78.97 |
| | $ | 0.66 |
| | $ | 72.21 |
| | $ | 66.05 |
| | $ | 0.60 |
| | $ | 128.46 |
| | $ | 110.49 |
| | $ | 0.87 |
| | $ | 105.85 |
| | $ | 95.84 |
| | $ | 0.77 |
|
The amount and timing of dividends payable on NEE's common stock are within the sole discretion of NEE's Board of Directors. The Board of Directors reviews the dividend rate at least annually (generally in February) to determine its appropriateness in light of NEE's financial position and results of operations, legislative and regulatory developments affecting the electric utility industry in general and FPL in particular, competitive conditions, change in business mix and any other factors the Board of Directors deems relevant. The ability of NEE to pay dividends on its common stock is dependent upon, among other things, dividends paid to it by its subsidiaries. There are no restrictions in effect that currently limit FPL's ability to pay dividends to NEE. In February 2014,2017, NEE announced that it would increase its quarterly dividend on its common stock from $0.66$0.87 per share to $0.725$0.9825 per share. See Management's Discussion - Liquidity and Capital Resources - Covenants with respect to dividend restrictions and Note 10 - Common Stock Dividend Restrictions regarding dividends paid by FPL to NEE.
As of the close of business on January 31, 2014,2017, there were 23,26219,737 holders of record of NEE's common stock.
Issuer Purchases of Equity Securities.Information regarding purchases made by NEE of its common stock during the three months ended December 31, 20132016 is as follows:
|
| | | | | | | | | | | |
| Period | | Total Number of Shares Purchased (a) | | Average Price Paid Per Share | | Total Number of Shares Purchased as Part of a Publicly Announced Program | | Maximum Number of Shares that May Yet be Purchased Under the Program(b) |
| 10/1/2013 - 10/31/13 | | — |
| | $ | — |
| | — | | 13,274,748 |
| 11/1/2013 - 11/30/13 | | 885 |
| | $ | 88.57 |
| | — | | 13,274,748 |
| 12/1/2013 - 12/31/13 | | 1,037 |
| | $ | 84.15 |
| | — | | 13,274,748 |
| Total | | 1,922 |
| | $ | 86.19 |
| | — | | |
|
| | | | | | | | | | | |
| Period | | Total Number of Shares Purchased(a) | | Average Price Paid Per Share | | Total Number of Shares Purchased as Part of a Publicly Announced Program | | Maximum Number of Shares that May Yet be Purchased Under the Program(b) |
| 10/1/2016 - 10/31/16 | | — |
| | — |
| | — | | 13,274,748 |
| 11/1/2016 - 11/30/16 | | 359 |
| | $ | 115.03 |
| | — | | 13,274,748 |
| 12/1/2016 - 12/31/16 | | 511 |
| | $ | 115.95 |
| | — | | 13,274,748 |
| Total | | 870 |
| | $ | 115.57 |
| | — | | |
______________________
| |
| (a) | Includes: (1) in November and December 2013,2016, 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 (2011 LTIP) and the NextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan (former LTIP);Plan; and (2) in December 2013,2016, 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 LTIPNextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan (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. |
Item 6. Selected Financial Data
|
| | | | | | | | | | | | | | | | | | | |
| | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | | 2010 | | 2009 |
| SELECTED DATA OF NEE (millions, except per share amounts): | | | | | | | | | |
| Operating revenues | $ | 15,136 |
| | $ | 14,256 |
| | $ | 15,341 |
| | $ | 15,317 |
| | $ | 15,643 |
|
Income from continuing operations(a) | $ | 1,720 |
| | $ | 1,911 |
| | $ | 1,923 |
| | $ | 1,957 |
| | $ | 1,615 |
|
Net income(a)(b) | $ | 1,908 |
| | $ | 1,911 |
| | $ | 1,923 |
| | $ | 1,957 |
| | $ | 1,615 |
|
| Earnings per share of common stock - basic: | | | | | | | | | |
Continuing operations(a) | $ | 4.06 |
| | $ | 4.59 |
| | $ | 4.62 |
| | $ | 4.77 |
| | $ | 3.99 |
|
Net income(a)(b) | $ | 4.50 |
| | $ | 4.59 |
| | $ | 4.62 |
| | $ | 4.77 |
| | $ | 3.99 |
|
| Earnings per share of common stock - assuming dilution: | | | | | | | | | |
Continuing operations(a) | $ | 4.03 |
| | $ | 4.56 |
| | $ | 4.59 |
| | $ | 4.74 |
| | $ | 3.97 |
|
Net income(a)(b) | $ | 4.47 |
| | $ | 4.56 |
| | $ | 4.59 |
| | $ | 4.74 |
| | $ | 3.97 |
|
| Dividends paid per share of common stock | $ | 2.64 |
| | $ | 2.40 |
| | $ | 2.20 |
| | $ | 2.00 |
| | $ | 1.89 |
|
Total assets(c) | $ | 69,306 |
| | $ | 64,439 |
| | $ | 57,188 |
| | $ | 52,994 |
| | $ | 48,458 |
|
| Long-term debt, excluding current maturities | $ | 23,969 |
| | $ | 23,177 |
| | $ | 20,810 |
| | $ | 18,013 |
| | $ | 16,300 |
|
| SELECTED DATA OF FPL (millions): | | | | | | | | | |
| Operating revenues | $ | 10,445 |
| | $ | 10,114 |
| | $ | 10,613 |
| | $ | 10,485 |
| | $ | 11,491 |
|
| Net income | $ | 1,349 |
| | $ | 1,240 |
| | $ | 1,068 |
| | $ | 945 |
| | $ | 831 |
|
| Total assets | $ | 36,488 |
| | $ | 34,853 |
| | $ | 31,816 |
| | $ | 28,698 |
| | $ | 26,812 |
|
| Long-term debt, excluding current maturities | $ | 8,473 |
| | $ | 8,329 |
| | $ | 7,483 |
| | $ | 6,682 |
| | $ | 5,794 |
|
| Energy sales (kWh) | 107,643 |
| | 105,109 |
| | 106,662 |
| | 107,978 |
| | 105,414 |
|
| Energy sales: | | | | | | | | | |
| Residential | 50.1 | % | | 50.8 | % | | 51.2 | % | | 52.2 | % | | 51.2 | % |
| Commercial | 42.1 |
| | 43.0 |
| | 42.2 |
| | 41.3 |
| | 42.7 |
|
| Industrial | 2.7 |
| | 2.9 |
| | 2.9 |
| | 2.9 |
| | 3.1 |
|
| Interchange power sales | 2.3 |
| | 0.7 |
| | 0.9 |
| | 0.8 |
| | 1.4 |
|
Other(d) | 2.8 |
| | 2.6 |
| | 2.8 |
| | 2.8 |
| | 1.6 |
|
| Total | 100.0 | % | | 100.0 | % | | 100.0 | % | | 100.0 | % | | 100.0 | % |
Approximate 60-minute peak load (MW):(e) | | | | | | | | | |
| Summer season | 21,576 |
| | 21,440 |
| | 21,619 |
| | 22,256 |
| | 22,351 |
|
| Winter season | 17,500 |
| | 16,025 |
| | 17,934 |
| | 21,153 |
| | 24,346 |
|
| Average number of customer accounts (thousands): | | | | | | | | | |
| Residential | 4,097 |
| | 4,052 |
| | 4,027 |
| | 4,004 |
| | 3,984 |
|
| Commercial | 517 |
| | 512 |
| | 508 |
| | 504 |
| | 501 |
|
| Industrial | 10 |
| | 9 |
| | 9 |
| | 9 |
| | 10 |
|
| Other | 3 |
| | 3 |
| | 3 |
| | 3 |
| | 4 |
|
| Total | 4,627 |
| | 4,576 |
| | 4,547 |
| | 4,520 |
| | 4,499 |
|
| Average price billed to customers (cents per kWh) | 9.47 |
| | 9.51 |
| | 9.83 |
| | 9.34 |
| | 11.19 |
|
|
| | | | | | | | | | | | | | | | | | | |
| | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 | | 2013 | | 2012 |
| SELECTED DATA OF NEE (millions, except per share amounts): | | | | | | | | | |
| Operating revenues | $ | 16,155 |
| | $ | 17,486 |
| | $ | 17,021 |
| | $ | 15,136 |
| | $ | 14,256 |
|
Income from continuing operations(a) | $ | 3,005 |
| | $ | 2,762 |
| | $ | 2,469 |
| | $ | 1,677 |
| | $ | 1,911 |
|
Net income(a)(b) | $ | 3,005 |
| | $ | 2,762 |
| | $ | 2,469 |
| | $ | 1,908 |
| | $ | 1,911 |
|
| Net income attributable to NEE: | | | | | | | | | |
Income from continuing operations(a) | $ | 2,912 |
| | $ | 2,752 |
| | $ | 2,465 |
| | $ | 1,677 |
| | $ | 1,911 |
|
Gain from discontinued operations(b) | — |
| | — |
| | — |
| | 231 |
| | — |
|
| Total | $ | 2,912 |
| | $ | 2,752 |
| | $ | 2,465 |
| | $ | 1,908 |
| | $ | 1,911 |
|
| Earnings per share attributable to NEE - basic: | | | | | | | | | |
Continuing operations(a) | $ | 6.29 |
| | $ | 6.11 |
| | $ | 5.67 |
| | $ | 3.95 |
| | $ | 4.59 |
|
Net income(a)(b) | $ | 6.29 |
| | $ | 6.11 |
| | $ | 5.67 |
| | $ | 4.50 |
| | $ | 4.59 |
|
| Earnings per share attributable to NEE - assuming dilution: | | | | | | | | | |
Continuing operations(a) | $ | 6.25 |
| | $ | 6.06 |
| | $ | 5.60 |
| | $ | 3.93 |
| | $ | 4.56 |
|
Net income(a)(b) | $ | 6.25 |
| | $ | 6.06 |
| | $ | 5.60 |
| | $ | 4.47 |
| | $ | 4.56 |
|
| Dividends paid per share of common stock | $ | 3.48 |
| | $ | 3.08 |
| | $ | 2.90 |
| | $ | 2.64 |
| | $ | 2.40 |
|
Total assets(c) | $ | 89,993 |
| | $ | 82,479 |
| | $ | 74,605 |
| | $ | 69,007 |
| | $ | 64,144 |
|
| Long-term debt, excluding current maturities | $ | 27,818 |
| | $ | 26,681 |
| | $ | 24,044 |
| | $ | 23,670 |
| | $ | 22,881 |
|
Capital expenditures, independent power and other investments and nuclear fuel purchases: | | | | | | | | | |
| FPL | $ | 3,934 |
| | $ | 3,633 |
| | $ | 3,241 |
| | $ | 2,903 |
| | $ | 4,285 |
|
| NEER | 5,521 |
| | 4,661 |
| | 3,701 |
| | 3,637 |
| | 4,681 |
|
| Corporate and Other | 181 |
| | 83 |
| | 75 |
| | 142 |
| | 495 |
|
| Total | $ | 9,636 |
| | $ | 8,377 |
| | $ | 7,017 |
| | $ | 6,682 |
| | $ | 9,461 |
|
______________________
| |
| (a) | Includes net unrealized mark-to-market after-tax gains (losses) associated with non-qualifying hedges of approximately $(92) million, $183 million, $153 million, $(53) million and $(34) million, $190 million, $175 million and $(20) million and OTTI after-tax income (losses), net of OTTI reversals of $1 million, $31 million, $(6) million, $4 million and $(13) million for the years ended December 31, 2013, 2012, 2011, 2010 and 2009, respectively. Additionally, 2013 includes,Also, on an after-tax basis, 2013 includes impairment and other related charges related to the Spain Solar projects of approximately $342 million (see Note 4 - Nonrecurring Fair Value Measurements) and an operating loss of the Spainrelated to solar projects of $4 million. Also, 2011 includes an after-tax loss on the sale of natural gas-fired generating assets of approximately $98 million. See Note 4 - Nonrecurring Fair Value Measurements.in Spain. |
| |
| (b) | 2013 includes an after-tax net gain from discontinued operations of $188 million. See Note 6.$231 million related to the sale of hydropower generation plants. |
| |
| (c) | 2012 includesIncludes assets held for sale of approximately $452 million in 2016, $1,009 million in 2015 and $335 million.million in 2012. See Note 6. |
| |
(d) | Includes the net change in unbilled sales. |
| |
(e) | Winter season includes November1 - Assets and December of the current year and January to March of the following year (for 2013, through February 21, 2014).Liabilities Associated with Assets Held for Sale. |
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
OVERVIEW
NEE’s operating performance is driven primarily by the operations of its two principal subsidiaries, FPL, which serves approximately 4.74.9 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 Americathe world of renewable energy from the wind and sun.sun based on MWh produced in 2016. The table below presents NEE’s net income (loss) attributable to NEE and earnings (loss) per share attributable to NEE, assuming dilution, by reportable segment, - FPL and NEER, and by 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 14 for additional segment information, including reported results from continuing operations)information).The following discussions should be read in conjunction with the Notes to the Consolidated Financial Statements contained herein and all comparisons are with the corresponding items in the prior year.
| | | | Net Income (Loss) | | Earnings (Loss) Per Share, assuming dilution | Net Income (Loss) Attributable to NEE | | Earnings (Loss) Per Share Attributable to NEE, Assuming Dilution |
| | Years Ended December 31, | | Years Ended December 31, | Years Ended December 31, | | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 | | 2016 | | 2015 | | 2014 |
| | (millions) | | | (millions) | | |
| FPL | $ | 1,349 |
| | $ | 1,240 |
| | $ | 1,068 |
| | $ | 3.16 |
| | $ | 2.96 |
| | $ | 2.55 |
| $ | 1,727 |
| | $ | 1,648 |
| | $ | 1,517 |
| | $ | 3.71 |
| | $ | 3.63 |
| | $ | 3.45 |
|
NEER(a) | 556 |
| | 687 |
| | 774 |
| | 1.30 |
| | 1.64 |
| | 1.85 |
| 1,125 |
| | 1,092 |
| | 989 |
| | 2.41 |
| | 2.41 |
| | 2.25 |
|
| Corporate and Other | 3 |
| | (16 | ) | | 81 |
| | 0.01 |
| | (0.04 | ) | | 0.19 |
| 60 |
| | 12 |
| | (41 | ) | | 0.13 |
| | 0.02 |
| | (0.10 | ) |
| NEE | $ | 1,908 |
| | $ | 1,911 |
| | $ | 1,923 |
| | $ | 4.47 |
| | $ | 4.56 |
| | $ | 4.59 |
| $ | 2,912 |
| | $ | 2,752 |
| | $ | 2,465 |
| | $ | 6.25 |
| | $ | 6.06 |
| | $ | 5.60 |
|
| |
| (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.debt. |
For the five years ended December 31, 2013,2016, NEE delivered a total shareholder return of approximately 105%130.3%, belowabove the S&P 500’s 128%98.2% return, but well above the S&P 500 Utilities' 62%63.7% return and the Dow Jones U.S. Electricity's 53%59.8% return. The historical stock performance of NEE's common stock shown in the performance graph below is not necessarily indicative of future stock price performance.
Adjusted Earnings
NEE prepares its financial statements under GAAP. However, management uses earnings excluding certain items (adjusted earnings), a non-GAAP financial measure, internally for financial planning, for analysis of performance, for reporting of results to the Board of Directors and as an input in determining performance-based compensation under NEE’s employee incentive compensation plans. NEE also uses adjusted earnings when communicating its financial results and earnings outlook to analysts and investors. NEE’s management believes adjusted earnings provides a more meaningful representation of the company’sNEE's fundamental earnings power. Although the excluded amounts are properly included in the determination of net income under GAAP, management believes that the amount and/or nature of such items make period to period comparisons of operations difficult and potentially confusing. Adjusted earnings do not represent a substitute for net income, as prepared under GAAP.
Adjusted earnings exclude the unrealized mark-to-market effect of non-qualifying hedges (as described below) and 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 segregatesegregates 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 2013, certain interest rate derivative and foreign currency transactions entered into as economic hedges, which do not meet the requirements for hedge accounting, or for which hedge accounting treatment is not elected or has been discontinued.Changes in the fair value of those transactions are marked to market and reported in the consolidated statements of income, resulting in earnings volatility because the economic offset to certain of the positions are generally 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. In January 2016, NEE discontinued hedge accounting for all of its remaining interest rate and foreign currency derivative instruments, which could result in increased volatility in the non-qualifying hedge category. In connection with discontinuing hedge accounting for all of its remaining interest rate and foreign currency derivative instruments, in May 2016, NEE also began recording changes in the fair value of interest rate derivatives entered into as economic hedges to offset expected future debt issuances as non-qualifying hedges. At FPL, substantially all changes in the fair value of energy derivative transactions are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel clause.See Note 3.
During 2014, NEER decided not to pursue the sale of NEER's ownership interests in oil-fired generation plants located in Maine (Maine fossil) and recorded an after-tax gain of $12 million to increase Maine fossil's carrying value to its estimated fair value. See Note 4 - Nonrecurring Fair Value Measurements. In 2011,2016, subsidiaries of NEER completed the sales of their ownership interests in fivecertain natural gas-fired generating plants with a total generating capacity of approximately 2,700 MW located in California, Virginia, Alabama, South Carolina and Rhode Island.gas generation facilities. In connection with thesethe sales a loss ofand the related consolidating state income tax effects, gains totaling approximately $151$445 million ($98219 million total after-tax with $92 million of this loss recorded by NEER) wasafter tax) were recorded in NEE's consolidated statements of income which was excluded from adjusted earnings.and are included in losses (gains) on disposal of assets - net. See Note 41 - Nonrecurring Fair Value Measurements.
In 2013, an after-tax net gain from discontinued operations of $188 million ($175 million recorded at NEERAssets and $13 million recorded at Corporate and Other) was recorded in NEE's consolidated statements of income. The after-tax net gain from discontinued operations consisted of $231 million related to the 2013 sale of the ownership interest in a portfolio of hydropower generation plants and related assets located in Maine and New Hampshire, partly offset by a $43 million write down associatedLiabilities Associated with the plan to sell ownership interests in oil-fired generating plants located in Maine. The operations of these projects were not material to NEE's consolidated statements of incomeAssets Held for 2013, 2012 and 2011. See Note 6. Also in 2013, NEER recorded an impairment of $300 million and other related charges ($342 million after-tax) related to the Spain solar projects in NEE's consolidated statements of income. See Note 4 - Nonrecurring Fair Value Measurements and Note 13 - Spain Solar Projects.Sale. In order to make period to period comparisons more meaningful, in 2013 adjusted earnings also exclude the after-tax net gain from discontinued operations, the after-tax chargesitems discussed above, as well as costs incurred in 2016 and 2015 associated with the impairmentterminated HEI merger agreement (see Note 1 - Merger Termination), costs incurred in 2016 associated with the EFH merger agreement and related transactions (see Note 7 - Pending Oncor-Related Transactions), the resolution of contingencies related to a previous asset sale, the Spain solar projectspretax amount of which totaled $9 million and beginningwas recorded in the third quarter2016 as gains on disposal of 2013,investments and other property - net in NEE's consolidated statements of income, and, for all periods, the after-tax operating results associated with the Spain solar projects.projects in Spain.
The following table provides details of the after-tax adjustments to net income considered in computing NEE's adjusted earnings discussed above.
|
| | | | | | | | | | | | | |
| | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 |
| | | | (millions) | | |
Net unrealized mark-to-market after-tax gains (losses) from non-qualifying hedge activity(a) | $ | (53 | ) | | $ | (34 | ) | | $ | 190 | |
| Income (loss) from OTTI after-tax losses on securities held in NEER's nuclear decommissioning funds, net of OTTI reversals | $ | 1 |
| | $ | 31 | | | $ | (6 | ) |
After-tax loss on sale of natural gas-fired generating assets(b) | $ | — |
| | $ | — | | | $ | (98 | ) |
After-tax net gain from discontinued operations(c) | $ | 188 |
| | $ | — | | | $ | — | |
| After-tax charges recorded by NEER associated with the impairment of the Spain solar projects | $ | (342 | ) | | $ | — | | | $ | — | |
| After-tax operating loss of NEER's Spain solar projects | $ | (4 | ) | | $ | — | | | $ | — | |
|
| | | | | | | | | | | | | |
| | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 |
| | | | (millions) | | |
Net unrealized mark-to-market gains (losses) from non-qualifying hedge activity(a) | $ | (92 | ) | | $ | 183 | | | $ | 153 | |
| Merger-related expenses - Corporate and Other | $ | (92 | ) | | $ | (20 | ) | | $ | — | |
| Operating results of solar projects in Spain - NEER | $ | (11 | ) | | $ | 5 | | | $ | (32 | ) |
Losses from OTTI on securities held in NEER's nuclear decommissioning funds, net of OTTI reversals(b) | $ | (1 | ) | | $ | (15 | ) | | $ | (2 | ) |
| Gain associated with Maine fossil - NEER | $ | — |
| | $ | — | | | $ | 12 | |
Gains on sale of natural gas generation facilities(c) | $ | 219 |
| | $ | — | | | $ | — | |
| Resolution of contingencies related to a previous asset sale - NEER | $ | 5 |
| | $ | — | | | $ | — | |
______________________
| |
| (a) | For 2013, 20122016, 2015 and 2011, $542014, approximately $233 million of losses, $37$175 million of lossesgains and $193$171 million of gains, respectively, are included in NEER's net income; the balance is included in Corporate and Other. |
| |
| (b) | $92For 2016, 2015 and 2014, approximately $2 million of the loss islosses, $14 million of losses and $1 million of income, respectively, are included in NEER's net income; the balance is included in Corporate and Other. |
| |
| (c) | $175Approximately $276 million of the gaingains is included in NEER's net income; the balance is included in Corporate and Other. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale and Note 5. |
The change in unrealized mark-to-market activity from non-qualifying hedges is primarily attributable to changes in forward power and natural gas prices, interest rates and foreign currency exchange rates, as well as the reversal of previously recognized unrealized mark-to-market gains or losses as the underlying transactions were realized.
20132016 Summary
NEE's netNet income attributable to NEE for 20132016 was lowerhigher than 20122015 by $3$160 million, or 9 cents per share, primarily due to lower results at NEER, partly offset by higher results at FPL.The decline in earnings$0.19 per share, assuming dilution, also reflects additional shares outstanding.due to higher results at FPL, NEER and Corporate and Other.
During 2013, NEE and its subsidiaries commenced an enterprise-wide initiative focused mainly on improving productivity and reducing O&M expenses (cost savings initiative), and management expects to continue those efforts over the near term. The transition costs associated with the cost savings initiative recorded by NEE in 2013 amounted to approximately $72 million ($44 million after-tax), of which $32 million of such after-tax costs were recorded by FPL and $12 million by NEER.
FPL's increase in net income in 20132016 was primarily driven by continued investments in plant in service while earning a 10.96%an 11.50% regulatory ROE on its retail rate base. In 2013, FPL began operating underbase.
NEER's results increased in 2016 primarily reflecting earnings from new investments, gains from the 2012 rate agreement which increased revenues and cash flows without a material change in the earned regulatory ROE. FPL completed the final stagesales of its generation uprate project at Turkey Point Unit No. 4, completed the installation of approximately 4.5 million smart meters and placed in service the approximately 1,210 MW natural gas-fired combined-cycle Cape Canaveral power plant. The FPSC approved 25-year natural gas transportation agreements, pending completion of pipeline construction by Sabal Trailgeneration facilities and Florida Southeast Connection (see below). In 2013, FPL maintained a typical residential 1,000 kWh bill that was the lowest among reporting electric utilities within Florida and 28% below the national average based on a rate per kWh as of July 2013.
NEER's results decreased in 2013 primarily duefair value adjustments related to the $342 million of after-tax charges associated with the impairment of the Spain solar projects,contingent consideration, partly offset by the $175 million net after-tax gainunrealized losses from discontinued operationsnon-qualifying hedge activity compared to gains from such hedges in 2015, higher growth-related interest and higher results from new investments.general and administrative expenses and lower earnings on gas infrastructure and existing assets. In 2013,2016, NEER added approximately 3741,465 MW of wind capacity in the U.S. and Canada and 280980 MW of solar capacity in the U.S., completed the sales of its ownership interests in certain natural gas generation facilities with total generating capacity of 3,724 MW and increased its backlog of contracted renewable development projects.
Corporate and Other's results in 2013 improved2016 increased primarily due to higher resultsreflecting net unrealized gains from NEETnon-qualifying hedge activity primarily associated with interest rate and higher investment gains, foreign currency derivative instruments, partly offset by higher interest expense. In 2013, Lone Star achieved full commercial operation of approximately 330 miles of new transmission linesmerger-related expenses and associated transmission facilities in Texas. Sabal Trail and Florida Southeast Connection were selected to build, own and operate pipelines that would supply natural gas to FPL. The natural gas pipeline system is subject to certain conditions, including FERC approval. A FERC decision is expected in 2015.unfavorable consolidating income tax adjustments.
NEE and its subsidiaries including FPL, require funds to support and grow their businesses.These funds are primarily provided by cash flow from operations, borrowings or issuances of short- and long-term borrowingsdebt and proceeds from the sale of differential membership interestsinvestors and, from time to time, issuanceissuances of equity securities.As of December 31, 2013, NEE's total net available liquidity was approximately $6.7 billion, of which FPL's portion was approximately $3.0 billion. See Liquidity and Capital Resources - Liquidity.
Outlook
FPL's 2012 rate agreement continues to provide, among other things, a high degree of base rate predictability through December 2016, including allowances for rate increases when the modernized Cape Canaveral, Riviera Beach and Port Everglades power plants are placed in service, and permits FPL to record reserve amortization up to $400 million over the 2013 to 2016 period (see Item 1. Business - FPL - FPL Regulation - FPL Rate Regulation - Base Rates - Rates Effective January 1, 2013 - December 31,
2016). FPL's allowed regulatory ROE over this period is 10.50%, with a range of plus or minus 100 basis points. In 2013, FPL amortized $155 million of the reserve and the Cape Canaveral power plantwas placed in service in April 2013. FPL expects that the use of reserve amortization in 2013 will be more than in any of the remaining years of the 2012 rate agreement.
NEE's strategy at both of its principal businesses seeks to meet customer needs more economically and reliably than competitors. Meeting customer needs frequently requires the commitment of large capital expenditures to projects that have long lives and such commitments are difficult to reverse once made. Subsidiaries of NEE have made commitments to a variety of major capital projects that are expected to be completed over the next several years. While NEE management believes that these projects individually and collectively are attractive investments with the potential to create value for shareholders, there can be no guarantee that all or any of these projects will be successful. Because of their importance, management focuses particular attention on these large projects.
In 2014, NEE expects to focus efforts in particular on the following initiatives:
At FPL:
Sustaining FPL's customer value proposition: The combination of low bills, good reliability and excellent customer service that FPL currently provides its customers is both an objective of FPL's strategy and an important contributor to its long-term business success. FPL seeks to, at a minimum, maintain and ideally improve its overall customer value proposition.
Major capital projects: FPL is currently engaged in a large capital expansion program and its objective is to bring these projects in on schedule and within budget. This program includes modernizing its Riviera Beach and Port Everglades power plants to high-efficiency natural gas-fired units (approximately 1,200 MW at Riviera Beach and 1,240 MW at Port Everglades) to be placed in service in the second quarter of 2014 and mid-2016, respectively.
Storm hardening and reliability: FPL plans to continue to invest in storm hardening and reliability efforts.
At NEER:
Maintaining excellence in day-to-day operations: NEER has developed a track record of generally running its facilities reliably and cost-effectively. The company seeks to, at a minimum, maintain and ideally improve its operating performance.
Solar: Add approximately 805 MW of new solar generation during 2014 through 2016, including a 20 MW solar PV project completed in January 2014, the 125 MW to complete the Genesis solar project in California, the 120 MW to complete NEER's portion of the Desert Sunlight solar PV project in California, the 250 MW McCoy solar PV project in California and the pending acquisition of development rights for a 250 MW solar PV project in Nevada which is expected to close in March 2014 and complete construction in 2016.
Wind: Add approximately 600 MW of new Canadian wind generation and 2,000 to 2,500 MW of new U.S. wind generation during 2013 through 2015, of which 125 MW and 250 MW was placed in service in 2013 in Canada and the U.S., respectively.
Nuclear: Complete the four planned nuclear refueling outages in 2014.
At Sabal Trail and Florida Southeast Connection: Continue to pursue FERC approval to build, own and operate the northern and southern portions of the natural gas pipeline system.
In addition, NEE and FPL devote effort to numerous other initiatives designed to support their long-term growth and development. There can be no guarantees that NEE or FPL will be successful in attaining their goals with respect to any of these initiatives.
For additional information on certain of the above matters, see Item 1. Business.
RESULTS OF OPERATIONS
NEE’s netNet income attributable to NEE for 20132016 was $1.91$2.91 billion, compared to $1.91$2.75 billion in 20122015 and $1.92$2.47 billion in 2011.2014. In 2013,2016 and 2015, net income was unfavorably affected by lower results at NEER offset byattributable to NEE improved due to higher results at FPL, NEER and Corporate and Other.The decrease in NEE’s 2012 net income was primarily due to the absence of certain income tax benefits at Corporate and Other recorded in 2011 and lower results at NEER, partly offset by improved results at FPL.
NEE's effective income tax rates for 2016, 2015 and 2014 of approximately 31.5%, 30.8% and 32.3%, respectively, primarily reflect income tax expense at the statutory rate for all periods presented reflectsof 35% and state income taxes, partly offset by the benefit of PTCs for NEER's wind projects, at NEERas well as ITCs and deferred income tax benefits associated with convertible ITCs under the American Recoveryfor solar and Reinvestment Act of 2009, as amended (Recovery Act).certain wind projects at NEER. PTCs, ITCs and deferred income tax benefits associated with convertible ITCs can significantly affect NEE's effective income tax rate depending on the amount of pretax income. The amount of PTCs recognized can be significantly affected by wind generation and by the roll off of PTCs on certain wind projects after ten years of production (PTC roll off). In addition, NEE's effective income tax rate for 20132014 was unfavorably affected by the establishmenta noncash income tax charge of a full valuation allowance on the deferred tax assetsapproximately $45 million associated with structuring Canadian assets in connection with the Spain solar projects.creation of NEP. In April 2016, a court approved a reorganization of certain Canadian assets that provided for tax bases in certain of these assets. NEE recorded approximately $30 million of associated income tax adjustments in 2016, which effectively reversed a portion of the charge recorded in 2014. See Note 1 - Income Taxes Note 1 - Sale of Differential Membership Interests, Note 4 - Nonrecurring Fair Value Measurements and Note 5. Also see Item 1. Business - NEER - Generation and Other Operations - NEER Fuel/Technology Mix - Policy Incentives for Renewable Energy Projects, for a discussion of the Taxpayer Relief Act.
FPL: Results of Operations
FPL obtains its operating revenues primarily from the sale of electricity to retail customers at rates established by the FPSC through base rates and cost recovery clause mechanisms. FPL’s net income for 2013, 20122016, 2015 and 20112014 was $1,349$1,727 million, $1,240$1,648 million and $1,068$1,517 million, respectively, representing an increase in 20132016 of $109$79 million and an increase in 20122015 of $172$131 million. The primary drivers, on an after-tax basis, of these changes are in the following table.
|
| | | | | | | | | |
| | Increase (Decrease) From Prior Period |
| | Years Ended December 31, |
| | 2016 | | 2015 |
| | (millions) |
Investment in plant in service(a) | $ | 131 | | | $ | 77 | |
| Change in amount of equity used to finance investments | (42 | ) | | 22 | |
| Nonrecoverable expenses | (16 | ) | | (15 | ) |
| Woodford shale investment | (10 | ) | | 5 | |
| Cost recovery clause earnings | 11 | | | 5 | |
| AFUDC - equity | 6 | | | 32 | |
| Other | (1 | ) | | 5 | |
| Increase in net income | $ | 79 | | | $ | 131 | |
______________________
| |
| (a) | Investment in plant in service grew FPL's average retail rate base by approximately $2.4 billion and $1.0 billion in 2016 and 2015, respectively. For 2016, the increase primarily reflects the modernized Port Everglades Clean Energy Center that was placed in service in April 2016 and ongoing transmission and distribution additions. For 2015, the increase primarily reflects ongoing transmission and distribution additions and the modernized Riviera Beach Clean Energy Center placed in service in April 2014. |
The use of reserve amortization in 2013 iswas permitted byunder the 2012 rate agreement and for 2012 and 2011,continues during the 2010term of the 2016 rate agreement, subject to limitations provided in the rate agreements.agreement. See Item 1. Business - FPL - FPL Regulation - FPL Rate Regulation - Base Rates for additional information on the 2012 and 20102016 rate agreements.In order to earn a targeted regulatory ROE, in each reporting period undersubject to limitations associated with the 2012 and 20102016 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 and tax expenses. In general, the net impact of these income statement line items ismust be adjusted, in part, by reserve amortization to earn a targeted regulatory ROE. In certain periods, reserve amortization must beis reversed so as not to exceed the targeted regulatory ROE. The drivers of FPL's net income not reflected in the reserve amortization calculation typically include wholesale and transmission service revenues and expenses, cost recovery clause revenues and expenses, AFUDC - equity and costs not allowed to be recovered from retail customers by the FPSC. During 2013, 2012 and 2011, In 2016, FPL recorded reserve amortization of $155 million, $480$13 million, and, $187in2015 and 2014, FPL recorded the reversal of reserve amortization of approximately $15 million and $33 million, respectively.
FPL's regulatory ROE for 20132016, 2015 and 2014 was 10.96%, compared to 11.0% in 2012 and 2011. The 2013 regulatory ROE of 10.96% reflects approximately $32 million of after-tax charges associated with the cost savings initiative (see 2013 Summary above)11.50%. These charges were not offset by additional reserve amortization. Excluding the impact of these charges, FPL's regulatory ROE for 2013 would have been approximately 11.25%. In 2013 and 2012, the growth in earnings for FPL was primarily driven by:
higher earnings on investment in plant in service of approximately $175 million and $99 million, respectively. Average investment in plant in service grew FPL's retail rate base in 2013 and 2012 by approximately $3.4 billion and $2.1 billion, respectively, reflecting, among other things, the generation power uprates at FPL's nuclear units, ongoing transmission and distribution additions and, for 2013, themodernized Cape Canaveral power plant,
higher AFUDC - equity of $3 million and $17 million, respectively, and
in 2012, higher cost recovery clause results of $52 million,
partly offset, in 2013, by,
lower cost recovery clause results of $45 million primarily due to the transfer of new nuclear capacity to retail rate base as discussed below under Retail Base, Cost Recovery Clauses and Interest Expense, and
the $32 million of after-tax charges associated with the cost savings initiative.
FPL's operating revenues consisted of the following:
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 |
| | | | (millions) | | |
| Retail base | $ | 5,807 |
| | $ | 5,653 |
| | $ | 5,347 |
|
| Fuel cost recovery | 3,120 |
| | 3,875 |
| | 3,876 |
|
| Net deferral of retail fuel revenues | — |
| | (1 | ) | | — |
|
| Net recognition of deferred retail fuel revenues | 6 |
| | — |
| | — |
|
| Other cost recovery clauses and pass-through costs, net of any deferrals | 1,467 |
| | 1,645 |
| | 1,766 |
|
| Other, primarily wholesale and transmission sales, customer-related fees and pole attachment rentals | 495 |
| | 479 |
| | 432 |
|
| Total | $ | 10,895 |
| | $ | 11,651 |
| | $ | 11,421 |
|
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 |
| | | | (millions) | | |
| Retail base | $ | 4,951 |
| | $ | 4,246 |
| | $ | 4,217 |
|
| Fuel cost recovery | 3,334 |
| | 3,815 |
| | 4,416 |
|
| Net deferral of retail fuel revenues | — |
| | (44 | ) | | — |
|
| Net recognition of previously deferred retail fuel revenues | 44 |
| | — |
| | — |
|
| Other cost recovery clauses and pass-through costs, net of any deferrals | 1,837 |
| | 1,858 |
| | 1,751 |
|
| Other, primarily wholesale and transmission sales, customer-related fees and pole attachment rentals | 279 |
| | 239 |
| | 229 |
|
| Total | $ | 10,445 |
| | $ | 10,114 |
| | $ | 10,613 |
|
Retail Base
FPSC Rate Orders
In 2013, FPL’s retail base revenues benefited fromfor all years presented reflect the 2012 rate agreement as retailagreement. Retail base rates and charges were designed to increaserevenues increased approximately $350$175 million on an annualized basis, as well asin 2016 through a $164$216 million annualized retail base rate increase associated with the Cape Canaveral power plant,modernized Port Everglades Clean Energy Center which was placed in service in April 2013. The 20122016, and, in 2015, increased $43 million through a $234 million annualized retail base rate agreement:increase associated with the modernized Riviera Beach Clean Energy Center which was placed in service in April 2014.
remainsIn December 2016, the FPSC issued a final order approving the 2016 rate agreement which became effective January 2017 and will remain in effect until at least December 2016,
2020, establishes FPL's allowed regulatory ROE at 10.50%10.55%, with a range of plus or minus 100 basis points,9.60% to 11.60%, and
allows for additional retail rate base increases in 2017, 2018 and upon commencement of commercial operations at the Okeechobee Clean Energy Center. In January 2017, the Sierra Club filed a notice of appeal challenging the FPSC’s final order approving the 2016 rate increases asagreement, which notice of appeal is pending before the modernized Riviera Beach and Port Everglades projects become operational (which is expected in the second quarter of 2014 and mid-2016, respectively).
In 2012 and 2011, FPL's retail base revenues were impacted by the 2010 rate agreement.Florida Supreme Court. See Item 1. Business - FPL - FPL Regulation - FPL Rate Regulation - Base Rates for additional information on the 2012 and 20102016 rate agreements.
Included in retail base revenues for 2013 and 2012 were approximately $302 million and $11 million, respectively, of additional revenues associated with new retail base rates under the 2012 rate agreement and, for 2013, $129 million of additional retail base revenues related to the Cape Canaveral power plant which was placed in service in April 2013. FPL collected in 2012 approximately $52 million of additional retail base revenues related to the placement in service of WCEC Unit No. 3 in May 2011, as permitted by the 2010 rate agreement. Additional retail base revenues of approximately $233 million and $29 million were recorded in 2013 and 2012, respectively, primarily related to new nuclear capacity which was placed in service in 2012 and 2011, respectively, as permitted by the FPSC's nuclear cost recovery rule. In 2014, FPL expects to collect approximately $113 million of additional base revenues, of which $4 million was recorded in 2013 as unbilled revenues, related to new nuclear capacity of approximately 125 MW which was placed in service in 2013. See Cost Recovery Clauses below for discussion of the nuclear cost recovery rule.
In September 2013, the Florida Supreme Court heard oral argument on the OPC'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
A portion of the increase in the average number of customer accounts of 1.1% in 2013 can be attributed to the remote disconnection of inactive meters (meters at premises where electric service is available but no customer is requesting service) through the use of smart metersIn 2016 and the subsequent establishment of valid customer accounts (reactivated customers). Generally these reactivated customers were lower than average usage customers and, accordingly, did not increase revenues proportionally. The 1.1% increase in the average number of customer accounts increased retail base revenues by approximately $27 million.
In 2013, although2015, FPL experienced a 0.2% decrease in average usage per retail customer, the effect was to1.4% increase retail base revenues, after adjusting for the reactivated customers, by approximately $10 million, reflecting an improved economy and weather conditions, partly offset by increased efficiency measures and one less day of sales in 2013, as 2012 was a leap year. In 2012, FPL experienced a 2.0% decrease in average usage per retail customer and the average number of customer accounts increased 0.6%, which collectively decreased retail base revenues by approximately $63 million. The decrease in average usage per retail customer was primarily due to weather conditions and the absence of three extra days of sales that occurred in 2011 for a change from a fiscal month to a calendar month, partly offset by higher non-weather related usage per retail customer. Non-weather related usage per retail customer increased in 2013 and 2012 mirroring the continued gradual improvements in the Florida economy.
FPL has now experienced four consecutive years of moderately positive growtheach year in the average number of customer accounts and expects a continuation of this trend2.1% decrease and 4.2% increase, respectively, in 2014, assuming no significantthe average usage per retail customer, which collectively, together with other factors, decreased revenues by approximately $21 million and increased revenues by $263 million, respectively. The decline in 2016 usage per retail customer is primarily due to milder weather and customer service interruptions as a result of hurricanes that impacted FPL's service territory in 2016 which had a modest negative impact on 2016 base revenue (see Note 1 - Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve), while the overall state of Florida'sincrease in 2015 usage per retail customer was due to favorable weather. An improvement in the Florida economy and excluding any impact from reactivated customers.contributed to increased revenues in both periods.
Cost Recovery Clauses
Revenues from fuel and other cost recovery clauses and pass-through costs, such as franchise fees, revenue taxes and storm-related surcharges, are largely a pass-through of costs. Such revenues also include a return on investment allowed to be recovered through the cost recovery clauses on certain assets, primarily related to nuclear capacity, solar and environmental projects. In 2013, 2012 and 2011, cost recovery clauses contributed $115 million, $160 million and $108 million, respectively, to FPL’s net income. The decrease in 2013 in cost recovery clause results is primarily due to the collection in 2013 of retail base revenues related to new nuclear capacity which was placed in service in 2012 (see Retail Base above), while the increase in 2012 reflects the return on additional nuclear capacity investments prior to recovery through retail base rates (see nuclear cost recovery rule discussion below). In 2014, there will be minimal contributions to net income from the nuclear cost recovery rule as all nuclear uprate costs have been placed in service and are now collected through base rates. Fluctuations in fuel cost recovery revenues are primarily driven by changes in fuel and energy charges which are included in fuel, purchased power and interchange expense in the consolidated statements of income, as well as by changes in energy sales. Fluctuations in revenues from other cost recovery clauses and pass-through costs are primarily driven by changes in storm-related surcharges, capacity charges, franchise fee costs, the impact of changes in O&M and depreciation expenses on the underlying cost recovery clause, investment incertain solar and environmental projects investment in nuclear capacity until such capacity goes into service and is recovered in base rates, pre-construction coststhe unamortized balance of the regulatory asset associated with FPL's acquisition of the development of two additional nuclear units at the Turkey Point site and changes in energy sales. Capacity charges are included in fuel, purchased power and interchange and franchise fee costs are included in taxes other than income taxes and other in the consolidated statements of income. Cedar Bay generation facility. See Item 1. Business - FPL - FPL Regulation - FPL Rate Regulation - Cost Recovery Clauses. Underrecovery or overrecovery of cost recovery clause and other pass-through costs (deferred clause and franchise expenses and revenues) can significantly affect NEE's and FPL's operating cash flows. The change from December 31, 2012 to December 31, 2013 in deferred clause2016 and franchise expenses and in deferred clause and franchise revenues was2015 net overrecoveries were approximately $166$94 million and negatively$176 million, respectively, and positively affected NEE’s and FPL’s cash flows from operating activities in 2013.activities.
The decrease in fuel cost recovery revenues in 20132016 is primarily due to a decrease of approximately $737 million related to a lower average fuel factor. The slight decrease in fuel cost recovery revenues in 2015 reflects lower revenues totaling approximately $118 million from the incentive mechanism and from interchange power sales and $96 million related 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) andincreased revenues of $213 million related to higher interchange power sales (collectively, approximately $200 million). The decrease in fuel cost recovery revenues in 2012 is primarily due to a lower average fuel factor of approximately $558 million and lower energy sales of $43 million.sales.
The changeDeclines in 2016 revenues from other cost recovery clauses and pass-through costs were largely due to reductions in 2013purchased power and 2012 reflects higher revenues in 2012capacity expenses associated with the FPSC’s nuclearcapacity clause. The declines in 2015 revenues from other cost recovery rule reflectiveclauses and pass-through costs were largely due to reductions in expenses associated with energy conservation programs and the capacity clause.
In 2016, 2015 and 2014, cost recovery clauses contributed $112 million, $103 million and $93 million, respectively, to FPL’s net income. The increase in 2016 primarily relates to the acquisition of higher earnings on additional nuclearthe Cedar Bay generation facility. The increase in 2015 primarily relates to gains associated with the incentive mechanism, investments in gas reserves and the acquisition of the Cedar Bay generation facility.
In September 2015, FPL assumed ownership of the Cedar Bay generation facility and terminated its long-term purchased power agreement for substantially all of the facility’s capacity investmentsand energy for a purchase price of approximately $521 million. FPL will recover the purchase price and associated income tax gross-up as a regulatory asset which will be amortized over approximately nine years. See Note 1 - Rate Regulation for further discussion. Additionally, in January 2017, FPL purchased the Indiantown generation facility (see Note 13 - Contracts).
Woodford Shale Investment
In March 2015, after receiving FPSC approval, a wholly owned subsidiary of FPL partnered with a third party to develop up to 38 natural gas production wells in the Woodford Shale region in southeastern Oklahoma and in return began receiving its ownership share of the natural gas produced from these wells. In May 2016, the Florida Supreme Court (Court) reversed the FPSC’s order approving FPL’s investment in the Woodford Shale wells concluding that the FPSC exceeded its statutory authority when approving recovery of FPL’s costs and investment in these wells. During 2016, FPL recorded a provision for refund of approximately $13 million (after tax) associated with the Court’s decision. FPL’s wholly owned subsidiary, which is not subject to FPSC authority, sells its share of the natural gas produced from the Woodford Shale wells to third parties at market prices. Also, in response to the Court's
anddecision on the shift,Woodford Shale order, the FPSC vacated its July 2015 order approving a set of guidelines under which FPL could participate in 2013, to the collection of nuclear capacity recovery through retail base revenues (see Retail Base above). The nuclear cost recovery rule provides for the recovery of prudently incurred pre-construction costs and carrying charges (equal to the pretax AFUDC rate) on construction costs and a return on investment for new nuclear capacity through levelized charges under the capacity clause. The same rule provides for the recovery of construction costs, once property related to the new nuclear capacity goes into service, through a retail base rate increase effective beginning the following January.additional natural gas production projects.
Other
The increase in other revenues for 2016 is primarily due to anrevenues related to sales of natural gas produced from the Woodford Shale wells discussed above. The increase in customer-related fees associatedother revenues for 2015, which did not result in a significant contribution to earnings, primarily reflects higher wholesale and transmission service revenues along with the 2012 rate agreement. FPL expects revenues from wholesale sales to increase approximately $100 million in 2014 primarily due an increase in contracted load served under existing wholesale contracts.other miscellaneous service revenues.
Other Items Impacting FPL's Consolidated Statements of Income
Fuel, Purchased Power and Interchange Expense
The major components of FPL's fuel, purchased power and interchange expense are as follows:
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| | | | (millions) | | | | | (millions) | | |
| Fuel and energy charges during the period | $ | 3,519 | | | $ | 3,657 | | | $ | 4,237 | | $ | 3,113 | | | $ | 3,593 | | | $ | 3,951 | |
| Net deferral of retail fuel costs | (148 | ) | | — | | | — | | (11 | ) | | — | | | (109 | ) |
| Net recognition of previously deferred retail fuel costs | — | | | 103 | | | 159 | | |
| Net recognition of deferred retail fuel costs | | — | | | 220 | | | — | |
| Other, primarily capacity charges, net of any capacity deferral | 554 | | | 505 | | | 581 | | 195 | | | 463 | | | 533 | |
| Total | $ | 3,925 | | | $ | 4,265 | | | $ | 4,977 | | $ | 3,297 | | | $ | 4,276 | | | $ | 4,375 | |
The decrease in fuel and energy charges in 20132016 primarily reflects approximately $453 million of lower fuel and energy prices and $27 million related to lower energy sales. The decrease in fuel and energy charges in 2015 was primarily due to lower fuel and energy prices of approximately $306$491 million reflecting additional nuclear generationand a decrease of $68 million in 2013, which has a lower fuel cost,costs related to the incentive mechanism, partly offset by gas purchased for incentive gas sales of $88 million and higher energy sales of $80approximately $201 million. In addition, FPL deferred approximately $11 million and $109 million of retail fuel costs in 2016 and 2014, respectively, compared to the recognition of deferred retail fuel costs of $220 million in 2015. The additional nuclear generationdecrease in 2013 wasother in both periods is primarily due to increasedlower capacity fees in part related to the termination of the nuclear units as a resultCedar Bay generation facility long-term purchased power agreement after FPL assumed ownership of the nuclear uprate project and higher nuclear production reflecting lower outage durationCedar Bay generation facility in 2013. The decrease in fuel and energy charges in 2012 reflects lower fuel and energy prices of $526 million and lower energy sales of $54 million.September 2015.
O&M Expenses
FPL's O&M expenses decreased $74 million in 2013, reflecting lower cost recovery clause costs, which are essentially pass-through costs, of approximately $54 million, the absence of nuclear outage costs incurred during an outage in the prior year and company-wide reductions in O&M expenses, partly offset by $52 million of transition costs associated with the cost savings initiative. The ideas generated from the cost savings initiative are expected to keep FPL's O&M expenses recovered through base rates flat through 2016 as compared to 2012. FPL's O&M expenses increased $74 million in 2012 primarily due to higher employee-related and insurance costs, higher fossil plant outage costs primarily due to outage timing and higher cost recovery clause costs of approximately $21 million.
Depreciation and Amortization Expense
The major components of FPL’s depreciation and amortization expense are as follows:
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| | | | (millions) | | | | | (millions) | | |
| Reserve amortization recorded under the 2012 and 2010 rate agreements | $ | (155 | ) | | $ | (480 | ) | | $ | (187 | ) | |
| Reserve reversal (amortization) recorded under the 2012 rate agreement | | $ | (13 | ) | | $ | 15 |
| | $ | 33 |
|
| Other depreciation and amortization recovered under base rates | 1,105 |
| | 1,013 |
| | 944 |
| 1,366 |
| | 1,359 |
| | 1,211 |
|
| Depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization | 209 |
| | 126 |
| | 41 |
| |
| Depreciation and amortization primarily recovered under cost recovery clauses and securitized storm-recovery cost amortization | | 298 |
| | 202 |
| | 188 |
|
| Total | $ | 1,159 |
| | $ | 659 |
| | $ | 798 |
| $ | 1,651 |
| | $ | 1,576 |
| | $ | 1,432 |
|
The reserve amortization, recorded in 2013 was lower thanor reversal of such amortization, recorded inreflects adjustments to the prior year primarily due to additional base revenues collected in 2013 associated with new retail base ratesdepreciation and fossil dismantlement reserve provided under the 2012 rate agreement.At December 31, 2013 approximately $245 million ofagreement in order to achieve the reserve remains available for future amortization over the term of the 2012 rate agreement. Beginning in 2013, reservetargeted regulatory ROE. Reserve amortization is recorded as a reduction of regulatory liabilities -to (or when reversed as an increase to) accrued asset removal costs which is reflected in noncurrent regulatory liabilities on the consolidated balance sheets. ReserveSee Note 1 - Rate Regulation regarding a $30 million reduction in the reserve available for amortization in 2013 did not offsetunder the charges associated with2012 rate agreement. Subject to certain conditions, FPL may amortize, over the cost savings initiative. term of the 2016 rate agreement, up to $1.0 billion of depreciation reserve surplus plus the reserve amount remaining under FPL's 2012 rate agreement (approximately $250 million at December 31, 2016).
The increase in other depreciation and amortization expense recovered under base rates for 2013 and 2012 isin 2016 primarily duerelates to higher plant in service balances, including investments in transmission and distribution assets and the modernized Port Everglades Clean Energy Center that was placed in service in April 2016, partly offset by the absence of 2015 amortization expenses associated with analog meters. The increase in other depreciation and amortization expense recovered under base rates in 2015 is due to higher amortization expenses primarily associated with analog meters and higher plant in service balances.The increase in depreciation and amortization primarily recovered under cost recovery clauses and securitized storm-recovery cost amortization in 2013 and 2012 is2016 primarily duerelates to recoveriesamortization of prior year investment undera regulatory asset associated with the September 2015 acquisition of the Cedar Bay generation facility.
FPSC's nuclear cost recovery rule and higher plant in service balances associated with environmental projects under the environmental clause.
Taxes Other Than Income Taxes and Other
TaxesTaxes other than income taxes and other increased $63decreased $16 million in 20132016 primarily due to lower franchise and revenue taxes, neither of which impacts net income, partly offset by higher property taxes reflecting growth in plant in service balances. The increase in 2015 of $39 million was primarily due to higher property taxes reflecting growth in plant in service balances, and higher payroll taxes. The decrease of $3 million in 2012 was primarily due to lower franchise fees and revenue taxes (collectively, approximately $31 million), both of which are pass-through costsand reflect the decrease in fuel cost recovery clause revenues, partly offset byhigher property taxes of $28 million reflecting growth in plant in service balances.
Interest Expense
The decrease in interest expense in 2013 is primarily due to lower average interest rates and higher AFUDC - debt, partly offset by higher average debt balances. The increase in interest expense in 2012 is2016 and 2015 primarily due toreflects higher average debt balances, partly offset by lower average interest rates, lower interest expense on customer deposits reflecting lower rates and lower average customer deposit balances and higher AFUDC - debt. The change in AFUDC - debt is due to the same factors as described below in AFUDC - Equity.rates. Interest expense on storm-recovery bonds, as well as certain other interest expense on clause-recoverable investments (collectively, clause interest), are essentially pass-through amounts and do not significantly affect net income, as the clause interest is recovered either under cost recovery clause mechanisms or through a storm-recovery bond surcharge. Clause interest for 2013, 20122016, 2015 and 20112014 amounted to approximately $58$41 million, $81$41 million and $65$42 million, respectively.respective The change in revenues from other cost recovery clauses and pass-through costs in 2013 and 2012 reflects higher interest in 2012 associated with additional nuclear capacity investments and the shift in 2013 of nuclear capacity recovery through retail base revenues (see Retail Base and Cost Recovery Clauses above).ly.
AFUDC - Equity
The increase in AFUDC - equity in 20132016 is primarily due to additional AFUDC - equity recorded on construction expenditures associated with the Riviera Beachreplacement of certain gas turbines with high efficiency, low-emission turbines (peaker upgrade project) and Port Everglades modernization projects,a solar PV project constructed on three sites, partly offset by lower AFUDC - equity associated with the Cape Canaveral power plant Port Everglades Clean Energy Center which was placed in service in April 2013.2016. The increase in AFUDC - equity in 20122015 is primarily due to additional AFUDC - equity recorded on construction expenditures associated with the Cape Canaveralmodernization project at the Port Everglades Clean Energy Center, the investments in new compressor parts technology at select combined-cycle units and Riviera Beach modernization projects,the peaker upgrade project, partly offset by the absence oflower AFUDC - equity on WCEC Unit No. 3,associated with the modernized Riviera Beach Clean Energy Center which was placed in service in May 2011.
Capital Initiatives
FPL plans to add approximately 1,750 MW of capacity in mid-2019 when the Okeechobee Clean Energy Center is expected to be placed in service, to add up to 300 MW annually in each of 2017 through 2020 of new solar generation and to continue to strengthen its transmission and distribution infrastructure.
NEER: Results of Operations
NEER owns, develops, constructs, manages and operates electric generatinggeneration facilities in wholesale energy markets primarily in the U.S. and Canada. NEER also provides full energy and capacity requirements services, engages in power and gas marketing and trading activities and invests in natural gas, natural gas liquids and oil production and pipeline infrastructure assets. NEER’s net income less net income attributable to noncontrolling interests for 2013, 20122016, 2015 and 20112014 was $556$1,125 million, $687$1,092 million and $774$989 million, respectively, resulting in aan decreaseincrease in 2013 of $1312016 of $33 million and a decreasean increase in 20122015 of $87$103 million. The primary drivers, on an after-tax basis, of these decreaseschanges are in the following table. The 99.8 MW associated with the Spain solar projects and the related operating results are not included in the new investments data below.
|
| | | | | | | | | |
| | Increase (Decrease) From Prior Period |
| | Years Ended December 31, |
| | 2013 | | 2012 |
| | (millions) |
New investments(a) | $ | 132 | | | $ | 91 | |
Existing assets(a) | (13 | ) | | (178 | ) |
Gas infrastructure(b) | 17 | | | 24 | |
Customer supply and proprietary power and gas trading(b) | (4 | ) | | 44 | |
| Asset sales and restructuring activities | (12 | ) | | 20 | |
2011 impairment charges associated with certain wind and oil-fired generation assets(c) | — | | | 31 | |
| Interest expense, differential membership costs and other | (33 | ) | | (18 | ) |
Change in unrealized mark-to-market non-qualifying hedge activity(d)(e) | (17 | ) | | (230 | ) |
Change in OTTI losses on securities held in nuclear decommissioning funds, net of OTTI reversals(e) | (30 | ) | | 37 | |
Loss on sale of natural gas-fired generating assets(f) | — | | | 92 | |
Net gain on discontinued operations(g) | 175 | | | — | |
Charges associated with the impairment of the Spain solar projects(f) | (342 | ) | | — | |
Operating loss of the Spain solar projects(f) | (4 | ) | | — | |
| Net income decrease | $ | (131 | ) | | $ | (87 | ) |
|
| | | | | | | | | |
| | Increase (Decrease) From Prior Period |
| | Years Ended
December 31, |
| | 2016 | | 2015 |
| | (millions) |
New investments(a) | $ | 293 | | | $ | 138 | |
Existing assets(a) | (55 | ) | | (29 | ) |
Gas infrastructure(b) | (75 | ) | | (7 | ) |
Customer supply and proprietary power and gas trading(b) | (16 | ) | | 110 | |
| Revaluation of contingent consideration | 80 | | | — | |
Interest and other general and administrative expenses(c) | (99 | ) | | (99 | ) |
| Other | 36 | | | (24 | ) |
Change in unrealized mark-to-market non-qualifying hedge activity(d) | (408 | ) | | 4 | |
Change in OTTI losses on securities held in nuclear decommissioning funds, net of OTTI reversals(d) | 12 | | | (15 | ) |
Maine fossil gain in 2014(d) | — | | | (12 | ) |
Operating results of the solar projects in Spain(d) | (16 | ) | | 37 | |
Gains on sale of natural gas generation facilities(d) | 276 | | | — | |
Resolution of contingencies related to a previous asset sale(d) | 5 | | | — | |
| Increase in net income less net income attributable to noncontrolling interests | $ | 33 | | | $ | 103 | |
| |
| (a) | Includes PTCs, and state ITCs on wind projects and for new investments, deferred income tax and other benefits associated with convertible ITCs for wind and solar projects, as applicable, (see Note 1 -Electric- Electric Plant, Depreciation and Amortization, Note 1 - Income Taxes Note 1and - Sale of Differential Membership Interests and Note 5), as well as income tax benefits related to the Canadian tax restructuring, but excludes allocation of interest expense or corporate general and administrative expenses. Results from new projects are included in new investments during the first twelve months of operation. A project'soperation or ownership. Project results are included in existing assets beginning with the thirteenth month of operation. |
| |
| (b) | Excludes allocation of interest expense and corporate general and administrative expenses. |
| |
| (c) | See Note 4 - Nonrecurring Fair Value Measurements.Includes differential membership interest costs. |
| |
| (d) | See Note 3 and Overview - Adjusted Earnings related to derivative instruments. |
| |
(e) | See table in Overview - Adjusted Earnings for additional detail. |
| |
(f) | See Note 4 - Nonrecurring Fair Value Measurements and Overview - Adjusted Earnings for additional information. |
| |
(g) | See Note 6 and Overview - Adjusted Earnings for additional information. |
New Investments
In 2013,2016, results from new investments increased due to:
higher earnings of approximately $223 million, including deferred income tax and other benefits associated with ITCs and convertible ITCs, related to the addition of approximately 2,819 MW of wind generation and 1,226 MW of solar generation during or after 2015, and
higher earnings of approximately $70 million related to the acquisition of the Texas pipelines in October 2015 and additional investments in other natural gas pipeline projects.
In 2015, results from new investments increased primarily due to:
higher earnings of approximately $146 million related to the addition of approximately 1,8972,571 MW of wind generation and 910 MW of solar generation during or after 2012,2014, and
higher earnings of approximately $16 million related to the acquisition of the Texas pipelines and the development of three additional natural gas pipelines,
partly offset by,
lower deferred income tax and other benefits associated with convertible ITCs of $18$21 million
partly offset by,
lower state and ITCs of $8$3 million.
In 2012, results from new investments increased primarily due to:
the addition of approximately 1,899 MW of wind and 45 MW of solar generation during or after 2011,
higher deferred income tax and other benefits associated with convertible ITCs of $16 million, and
higher state ITCs of $10 million.
Existing Assets
In 2013,2016, results from NEER's existing asset portfolio decreased primarily due to:
lower results from wind generationand solar assets of approximately $26$40 million
primarily due to lower state tax credits, PTC roll off, higher project O&M expenses and an increase in the amount of $26 million,earnings attributable to noncontrolling interest, offset in part by higher wind generation and income tax benefits related to the Canadian tax restructuring, and
lower results of $25$6 million related to the sale of certain natural gas generation facilities (see Note 1 - Assets and Liabilities Associated with Assets Held for Sale).
In 2015, results from NEER's existing asset portfolio decreased primarily due to:
lower results from wind assets of $122 million primarily due to the absence of the hydro assets which were soldweaker wind resource offset in the first quarter of 2013,part by a favorable ITC impact related to changes in state income tax laws and favorable pricing,
partly offset by,
increased generation at Seabrook,the absence of a $45 million non cash income tax charge associated with structuring Canadian assets and $22 million in NEP IPO transaction costs recorded in 2014, and
higher results from merchant assets in the ERCOT region of approximately $27 million primarily due to the absence of a 2012 reduction in capacity, as well as lower operating
costs at that facility,
improved results of $16 million at Duane Arnold, primarily due to the absence of a 2012 refueling outage and favorable pricing, and
improved results of $11 million in the ERCOT region, primarily due to the absence of outages that occurred in 2012 at the natural gas facilities, and favorable market conditions.
In 2012, results from NEER's existing asset portfolio decreased due to:
Lower wind results of approximately $86 million primarily due to:
PTC roll off of $37 million,
the absence of $33 million of income tax benefits related to a valuation allowance reversal for certain state ITCs recorded in 2011, and
the balance primarily attributable to a lower wind resource, partly offset by certain state tax benefits.
Lower merchant results of approximately $59 million primarily due to:
lower results at Seabrook of $23 million primarily due to lower priced hedges,
lower results of $22 million in the ERCOT region, primarily due to market conditions as the prior year benefited from high market prices in August 2011, and higher O&M expenses and
lower hydro results of $13 million primarily due to lower priced hedges and a lower water resource.
Lower contracted results of approximately $33 million primarily due to:
the absence of earnings of $39 million from the natural gas-fired generating plants which were sold in the fourth quarter of 2011, and
lower results of $19 million related to the expiration of power sales agreements at certain joint venture projects, which is reflected in equity in earnings of equity method investees in NEE's consolidated statements of income,
partly offset by,
higher results of $25 million at Point Beach primarily due to the absence of a planned outage which occurred in the prior year and the addition of 167 MW of capacity, approximately one-half of which was completed in June 2011 and the other half of which was completed in December 2011, partly offset by higher O&M and depreciation expenses.2014 outage.
Gas Infrastructure
The increasedecrease in gas infrastructure results in 20132016 is primarily due to income from additionalincreased depreciation expense reflecting higher depletion rates as well as lower commodity prices. The decrease in gas infrastructure results in 2015 reflects increased depreciation expense mainly related to both higher depletion rates and increased production in 2013,2015, as well as the absence of 2014 gains on the sale of investments in certain wells (collectively, approximately $46 million), partly offset by the absencegains of gains recorded in 2012 from$42 million related to exiting the hedged positions on a number of future gas production opportunities. The increaseopportunities; such gains were previously reflected in unrealized mark-to-market non-qualifying hedge activity. NEER continues to monitor its oil and gas producing properties for potential impairments due to low prices for oil and natural gas commodity products. However, an impairment analysis performed under GAAP does not take into consideration the mark-to-market value of hedged positions. NEER hedges the expected output from its oil and gas producing properties for a period of time to help protect against price movements; the fair value of such hedged positions at December 31, 2016 was approximately $144 million. At December 31, 2016, approximately $2.2 billion of NEE’s property, plant and equipment, net relates to the gas infrastructure resultsbusiness' ownership interests in 2012 is primarily due to income from additional production, partly offset by lower gains from exiting the hedged positions on a number of futureinvestments located in oil and gas production opportunities.shale formations.
Customer Supply and Proprietary Power and Gas Trading
Results from customer supply and proprietary power and gas trading decreased in 20132016 primarily due to lower results in the customer supply business reflecting lower margins and mild weatherless favorable market conditions partly offset by higher power and gas trading results. In 2012, resultscompared to 2015. Results from customer supply and proprietary power and gas trading increased in 2015 primarily due to improved margins and favorable market conditions favorable weather and the absence of certain losses incurredcompared to lower results in the prior year.full requirements business in 2014 due to the impact of extreme winter weather.
Asset Sales and Restructuring ActivitiesRevaluation of Contingent Consideration
Asset sales and restructuring activities in 2013 primarily include anFor 2016, NEER's results reflect approximately $80 million of after-tax gainfair value adjustments, net of approximately $8 million onamounts attributable to noncontrolling interests, to reduce the salecontingent holdback associated with the acquisition of a portfolio of wind projects with net generating capacity totaling 223 MW. Asset sales and restructuring activities in 2012 primarily include an after-tax gain of approximately $8 million on the sale of a 30 MW wind project, an after-tax gain of $6 million on the sale of solar development rights and a $5 million after-tax gain related to an investment previously accounted for under the equity method in which NEER obtained a controlling interest (controlling interest gain)Texas pipelines (see Note 7 - Texas Pipeline Business).
2011 Impairment Charges Associated with Certain Wind and Oil-Fired Generation Assets44
In 2011, NEER recorded impairment charges primarily to write down the value of certain wind and oil-fired generation assets deemed to be unrecoverable. As a result of a fair value analysis, long-lived assets held and used with a carrying amount of approximately $79 million were written down to their fair value of $28 million, resulting in an impairment charge of $51 million or $31 million after-tax. See Note 4 - Nonrecurring Fair Value Measurements.
Interest Expense, Differential Membership Costs and OtherGeneral and Administrative Expenses
In 2013,Interest and general and administrative expenses includes interest expense, differential membership costs and other reflectscorporate general and administrative expenses. In 2016 and 2015, interest and general and administrative expenses reflect higher borrowing and other costs to support the growth of the business and transition costs associated with the cost savings initiative (approximately $12 million after-tax), partly offset by lower average interest rates and favorable income tax benefits. In 2012, interest expense, differential membership costs and other reflects higher employee-related costs and higher borrowing costs to support the growth of the business substantially offset by
lower average interest rates and the absence of interest expense on debt associated with the natural gas-fired generating plants sold in the fourth quarter of 2011.business.
Other Factors
Supplemental to the primary drivers of the changes in NEER's net income less net income attributable to noncontrolling interests discussed above, the discussion below describes changes in certain line items set forth in NEE's consolidated statements of income as they relate to NEER.
Operating Revenues
Operating revenues for 2013 increased $4382016 decreased $551 million primarily due to:
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 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, $419 million), and
higher revenues from new investments of approximately $262 million, including $56 million associated with the Spain solar projects,
partly offset by,
higher unrealized mark-to-market losses from non-qualifying hedges ($116of $273 million in 2013for 2016 compared to $115$275 million of gains on such hedges for 2015, and
lower revenues from existing assets of $409 million reflecting lower revenues from the natural gas generation facilities sold in 2012).
Operating2016, offset in part by higher wind generation due to stronger wind resource and higher revenues for 2012 decreased $607 million primarily due to:
at Seabrook reflecting the absence of revenues of approximately $469 million associated with five natural gas-fired generating plants sold in the fourth quarter of 2011,
lower unrealized mark-to-market gains from non-qualifying hedges ($115 million in 2012 compared to $414 million in 2011), and
unfavorable market conditions in the ERCOT and NEPOOL regions and lower revenues at PMI (collectively, $215 million),a 2015 refueling outage,
partly offset by,
higher revenues from new investments of approximately $384 million.
Operating revenues for 2015 increased $248 million primarily due to:
higher revenues from new investments of approximately $225 million,
higher revenues from the customer supply business and proprietary power and gas infrastructure (collectively, $228 million),trading business of $218 million reflecting favorable market conditions, and
higher revenues from the gas infrastructure business of $120$96 million primarily reflecting gains recorded upon exiting the hedged positions on a number of future gas production opportunities and the acquisition of the Texas pipelines,
partly offset by,
lower unrealized mark-to-market gains from non-qualifying hedges ($275 million for 2015 compared to $372 million of gains on such hedges for 2014), and
lower revenues from existing assets of $195 million reflecting lower wind generation due to weaker wind resource, lower revenues at NEER's contracted nuclear facilities primarilythe natural gas generation facility in Pennsylvania and in the ERCOT region due to lower gas prices and lower revenues at Seabrook reflecting a refueling outage, offset in part by higher revenues at Point Beach due to the absence of a 2011 planned2014 outage and price escalation under the addition of capacity at Point Beachpower sales agreement, higher dispatch in Maine due to 2015 weather conditions and favorable contract pricing.higher revenues from the solar projects in Spain.
Operating Expenses - net
Operating expenses - net for 2013 increased $7062016 decreased $446 million primarily due to:
an impairment chargegains of $300approximately $446 million primarily related to the Spain solar projects,sale of natural gas generation facilities in 2016 and the profit sharing liability amortization related to ownership interests sold to NEP, and
higher fuel expenses 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, $369 million)of approximately $284 million primarily reflecting lower fuel expense from the natural gas generation facilities sold in 2016,
partly offset by,
higher operating expenses associated with new investments of approximately $149$208 million, including $42 million
higher O&M expenses reflecting higher costs associated with growth in the Spain solar projects,NEER business, and
higher corporate operating expensesdepreciation of approximately $68$49 million
on existing assets primarily reflecting an increase of $111 million of depreciation from the gas infrastructure business primarily related to higher depletion rates and increased production, partly offset by lower depreciation on the natural gas generation facilities sold in 2016.
higher unrealized mark-to-market gains from non-qualifying hedges ($1 million in 2013 compared to $184 million of losses on such hedges in 2012).
Operating expenses - net for 2012 decreased $3272015 increased $138 million primarily due to:
higher operating expenses associated with new investments of approximately $123 million,
higher O&M expenses reflecting higher costs associated with growth in the NEER business, higher taxes other than income taxes and other reflecting the absence of operating expenses2014 gains on the sale of approximately $365 million associated with five natural gas-fired generating plants soldinvestments in certain wells in the fourth quarter of 2011,gas infrastructure business and
the absence of the $512014 reimbursement by a vendor of certain O&M-related costs, and
higher depreciation associated with the gas infrastructure business of $50 million impairment charge recorded in 2011,primarily related to higher depletion rates and increased production,
partly offset by,
higher unrealized mark-to-market losses from non-qualifying hedges ($184lower fuel expense of approximately $146 million primarily in 2012 compared to $95 millionthe ERCOT region and at the natural gas generation facility in 2011).Pennsylvania.
Interest Expense
NEER’s interest expense for 20132016 increased $54$107 million primarily duereflecting approximately $45 million of unfavorable changes in the fair value of interest rate derivative instruments compared to $11 million of favorable changes in 2015 and higher average debt balances reflecting growth in the business. Interest expense decreased $42 million in 2015 primarily reflecting the absence of approximately $64 million of losses in 2014 related to changes in the fair value of interest rate derivative instruments, partly offset by lowerhigher average interest rates. NEER's interest expense in 2013 also includes approximately $23 million of additional interest expense associated with the Spain solar projects, primarily due to the absence of capitalized interest during half of the year as the project was placed in service in June 2013. NEER’s interest expense for 2012 decreased $56 million primarily due to lower average interest rates and the absence of interest expense on debt associated with the natural gas-fired generating plants sold in the fourth quarter of 2011.balances.
Benefits Associated with Differential Membership Interests - net
Benefits associated with differential membership interests - net in NEE's 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,and solar projects, net of associated costs. The increase for 2016 primarily relates to lower interest costs associated with the ongoing paydown of the differential membership interest obligations, sales of differential membership interests and increased results of the underlying wind and solar projects. See Note 1 - Sale of Differential Membership Interests. For 2012
Equity in Earnings of Equity Method Investees
Equity in earnings of equity method investees increased in 2016 primarily due to increased earnings from AFUDC on NEER's investments in natural gas pipeline projects as construction continues and 2011, benefits associated with differential membership interests - net also includes $13 millionearnings from NEER's investment in a wind project that was placed in service in the fourth quarter of 2015. In 2015, the increase was primarily due to NEER's 50% equity investment in a 550 MW solar project that commenced partial operations at the end of 2013 and $52 million, respectively,full operations by the end of benefits where the investors elected to receive the convertible ITCs related to the underlying wind project.2014.
Gains on Disposal of AssetsInvestments and Other Property - net
Gains on disposal of assetsinvestments and other property - net in NEE’s consolidated statements of income for 2013, 2012 and 2011all periods presented primarily reflect gains on sales of securities held in NEER’s nuclear decommissioning funds and, for these respective periods, include approximately $14 million, $69 million and $25 million of OTTI reversals.funds. Gains on disposal of assetsinvestments and other property - net also reflect in 2013,2015, a pretax gain of approximately $14$6 million on the sale of a portfolio of wind assets with generation capacity totaling 223 MW, and in 2012, a pretax gain of $13 million on the sale of the 3041 MW wind project and, in 2014, a pretax gain of $7approximately $23 million on the sale of a 75 MW wind project. related
Revaluation of Contingent Consideration
Revaluation of contingent consideration reflects fair value adjustments to reduce the controlling interest gain.contingent holdback associated with the acquisition of the Texas pipelines. Approximately $65 million of the fair value adjustments is attributable to noncontrolling interests. See Note 7 - Texas Pipeline Business.
Tax Credits, Benefits and Expenses
PTCs from NEER’swind projects and ITCs and deferred income tax benefits associated with convertible ITCs from solar and certain 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, and were approximately $209$120 million, $203$149 million and $271$186 million in 2013, 20122016, 2015 and 2011,2014, respectively. In addition, NEE’s effective income tax rate for 2013, 2012ITCs and 2011 was affected by deferred income tax benefits associated with convertible ITCs of $71totaled approximately $150 million, $44$89 million and $2$84 million in 2016, 2015 and 2014, respectively. A portion of the PTCs and ITCs have been allocated to investors in connection with sales of differential membership interests. Also in 2014, NEE's effective income tax rate for 2013 was unfavorably affected by the establishmenta noncash income tax charge of a full valuation allowance on the deferred tax assetsapproximately $45 million associated with the Spain solar projects. structuring Canadian assets, approximately $30 million of which was reversed in 2016. See Note 5.
Capital Initiatives
NEER expects to add new contracted wind generation of approximately 2,400 MW to 4,100 MW, approximately 1,600 MW of additional repowering generation within the existing U.S. wind portfolio and Overviewnew contracted solar generation of approximately 400 MW to 1,300 MW in 2017 to 2018 and will continue to pursue other additional investment opportunities that may develop. Projects developed by NEER might be offered for sale to NEP if NEER should seek to sell the projects. NEER will also continue to invest in the development of its natural gas pipeline infrastructure assets (see Item 1. Business - Adjusted Earnings forNEER - Generation and Other Operations - Contracted, Merchant and Other Operations - Other Operations).
Sale of Assets to NEP
In 2016 and 2015, indirect subsidiaries of NEER sold additional information.ownership interests in wind and solar projects to indirect subsidiaries of NEP. See Note 1 - NextEra Energy Partners, LP.
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-utilitya portion of NEECH's corporate 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-utilityNEECH's corporate interest expense, the liabilitydeferred credit associated with differential membership interests sold by NEER’s subsidiaries is included with debt. Each subsidiary’s income taxes are calculated based on the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the subsidiary that
generated the tax benefits. Any remaining consolidated income tax benefits or expenses are recorded at Corporate and Other. The major components of Corporate and Other’s results, on an after-tax basis, are as follows:
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| | | | (millions) | | | | | (millions) | | |
| Interest expense, net of allocations to NEER | $ | (109 | ) | | $ | (90 | ) | | $ | (72 | ) | $ | 58 |
| | $ | (87 | ) | | $ | (95 | ) |
| Interest income | 32 |
| | 36 |
| | 32 |
| 29 |
| | 32 |
| | 31 |
|
| Federal and state income tax benefits | 15 |
| | 20 |
| | 91 |
| |
| Other | 65 |
| | 18 |
| | 30 |
| |
| Federal and state income tax benefits (expenses) | | (23 | ) | | 20 |
| | (7 | ) |
| Merger-related expenses | | (92 | ) | | (20 | ) | | — |
|
| Other - net | | 88 |
| | 67 |
| | 30 |
|
| Net income (loss) | $ | 3 |
| | $ | (16 | ) | | $ | 81 |
| $ | 60 |
| | $ | 12 |
| | $ | (41 | ) |
The increasedecrease in interest expense, net of allocations to NEER for 2016 primarily reflects net after-tax gains on interest rate and foreign currency derivative instruments and foreign currency transactions as hedge accounting was discontinued effective January 2016. See Note 3. The decrease in 2013 and 20122015 reflects higherlower average debt balances and,due in 2012,part to a lowerhigher allocation of interest costs to NEER as NEER obtained additional project-specific financing, partly offset by lower average interest rates.reflecting growth in NEER's business. The federal and state income tax benefits (expenses) reflect consolidating income tax adjustments, and include the following items:
including, in 2013, a $132016, approximately $57 million of income tax benefit recorded as a net gain from discontinued operations, net of federal income taxes (see Overview - Adjusted Earnings),
in 2011, a state deferred income tax benefit of approximately $64 million, net of federal income taxes, related to state tax law changes,
in 2011, an income tax benefit of $41 millioncharges related to the dissolutionsales of a subsidiary,certain of NEER's natural gas generation facilities and
the adoption of an accounting standards update (see Note 10 - Stock-Based Compensation), and in 2011, a $6 million expense2015, favorable changes in state income tax laws. Merger-related expenses increased in 2016 primarily related to the termination of the proposed merger between NEE, Hawaiian Electric Industries, Inc. (HEI) and two wholly owned direct subsidiaries of NEE (see Note 1 - Merger Termination) as well as costs associated with the loss on sale of natural gas-fired generating assets.
EFH merger agreement and related transactions (see Note 7 - Pending Oncor-Related Transactions). Other - net includes all other corporate income and expenses, as well as other business activities. The increase in other in 2013- net for 2016 primarily reflects higher 2016 investment gains, debt reacquisition gains and higher results from NEET and higher after-taxNEET. The increase in other - net for 2015 primarily reflects 2015 investment gains compared to 2014 investment losses and the absence of approximately $20 million.debt reacquisition losses recorded in 2014. Substantially all of the change in such investment gains and losses, on a pretax basis, is reflected in other - net in NEE's consolidated statements of income. The decline
In January 2017, an indirect wholly owned subsidiary of NEE completed the sale of its membership interests in other in 2012 is primarily due to approximately $18 million of after-tax investment losses, including a $13 million after-tax impairment charge on an early stage technology investment, a $6 million after-tax loss onFPL FiberNet. In connection with the redemption in 2012 of NEECH junior subordinated debentures, as well as other corporate costs, partly offset by higher results from other business activities. The pretax amount of the impairment charge on the early stage technology investmentsale and the loss on the redemptionrelated consolidating state income tax effects, a gain of NEECH junior subordinated debentures collectively amounted to approximately $30$1.1 billion (approximately $700 million and is reflected in other - netafter tax) will be recorded in NEE's consolidated statements of income.
Table of Contentsincome during the three months ended March 31, 2017. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale.
LIQUIDITY AND CAPITAL RESOURCES
NEE and its subsidiaries including FPL, require funds to support and grow their businesses. These funds are used for, among other things, working capital, capital expenditures, investments in or acquisitions of assets and businesses, payment of maturing debt obligations and, from time to time, redemption or repurchase of outstanding debt or equity securities. It is anticipated that these requirements will be satisfied through a combination of cash flows from operations, short- and long-term borrowings, the issuance from time to time, of short- and long-term debt and, from time to time, equity securities, and proceeds from the sale of differential membership interests,investors, 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. In 2013, NEE entered into a confirmation of forward sale transaction to issue 6.6 million shares to a forward counterparty, on a settlement date or dates to be specified at NEE's direction, which settlement will occur no later than December 31, 2014. See Note 10 - Issuance of Common Stock and Forward Sale Agreement. NEE, NEE, FPL and NEECH rely on access to credit and capital markets as significant sources of liquidity for capital requirements and other operations that are not satisfied by operating cash flows. The inability of NEE, FPL and NEECH to maintain their current credit ratings could affect their ability to raise short- and long-term capital, their cost of capital and the execution of their respective financing strategies, and could require the posting of additional collateral under certain agreements.
Cash Flows
NEE's and FPL's increase in cash flows from operating activities for 2013 reflect an increase in retail base rates and charges associated with FPL's 2012 rate agreement and, for NEE, also reflects operating cash generated from approximately 1,500 MW of NEER wind projects placed in service in 2012, primarily in the fourth quarter.
SourcesIn October 2015, NEE authorized a program to purchase, from time to time, up to $150 million of common units representing limited partner interests of NEP. Under the program, any purchases may be made in amounts, at prices and usesat such times as NEE or its subsidiaries deem appropriate, all subject to market conditions and other considerations. The purchases may be made in the open market or in privately negotiated transactions. Any purchases will be made in such quantities, at such prices, in such manner and on such terms and conditions as determined by NEE or its subsidiaries in their discretion, based on factors such as market and business conditions, applicable legal requirements and other factors. The common unit purchase program does not require NEE to acquire any specific number of NEE'scommon units and FPL's cash for 2013, 2012may be modified or terminated by NEE at any time. NEE owns and controls the general partner of NEP and beneficially owns approximately 66.1% of NEP’s voting power at December 31, 2016. The purpose of the program is not to cause NEP’s common units to be delisted from the New York Stock Exchange or to cause the common units to be deregistered with the SEC. As of December 31, 2016, NEE had purchased approximately $36 million of NEP common units under this program. Also in October 2015, NEP put in place an at-the-market equity issuance program pursuant to which NEP may issue from time to time, up to $150 million of its common units. As of December 31, 2016, NEP had issued approximately2011 were as follows:$41 million of its common units under this program.
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | Years Ended December 31, | | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 |
| | (millions) |
| Sources of cash: | | | | | | | | | | | |
| Cash flows from operating activities | $ | 5,102 |
| | $ | 3,992 |
| | $ | 4,074 |
| | $ | 3,558 |
| | $ | 2,823 |
| | $ | 2,245 |
|
| Long-term borrowings and change in loan proceeds restricted for construction | 4,599 |
| | 6,944 |
| | 3,375 |
| | 497 |
| | 1,296 |
| | 840 |
|
| Proceeds from sale of differential membership interests, net of payments | 385 |
| | 669 |
| | 366 |
| | — |
| | — |
| | — |
|
| Sale of independent power investments | 165 |
| | — |
| | 1,204 |
| | — |
| | — |
| | — |
|
| Capital contribution from NEE | — |
| | — |
| | — |
| | 275 |
| | 440 |
| | 410 |
|
| Cash grants under the Recovery Act | 165 |
| | 196 |
| | 624 |
| | — |
| | — |
| | 218 |
|
| Issuances of common stock - net | 842 |
| | 405 |
| | 48 |
| | — |
| | — |
| | — |
|
| Net increase in short-term debt | — |
| | 61 |
| | 460 |
| | 99 |
| | — |
| | 229 |
|
| Other sources - net | 66 |
| | 141 |
| | 205 |
| | 30 |
| | 68 |
| | 89 |
|
| Total sources of cash | 11,324 |
| | 12,408 |
| | 10,356 |
| | 4,459 |
| | 4,627 |
| | 4,031 |
|
| Uses of cash: | | | | | | | | | | | |
| Capital expenditures and independent power and other investments and nuclear fuel purchases | (6,682 | ) | | (9,461 | ) | | (6,628 | ) | | (2,903 | ) | | (4,285 | ) | | (3,502 | ) |
| Retirements of long-term debt | (2,396 | ) | | (1,612 | ) | | (2,121 | ) | | (453 | ) | | (50 | ) | | (45 | ) |
| Net decrease in short-term debt | (720 | ) | | — |
| | — |
| | — |
| | (225 | ) | | — |
|
| Dividends | (1,122 | ) | | (1,004 | ) | | (920 | ) | | (1,070 | ) | | — |
| | (400 | ) |
| Repurchases of common stock | — |
| | (19 | ) | | (375 | ) | | — |
| | — |
| | — |
|
| Other uses - net | (295 | ) | | (360 | ) | | (237 | ) | | (54 | ) | | (63 | ) | | (68 | ) |
| Total uses of cash | (11,215 | ) | | (12,456 | ) | | (10,281 | ) | | (4,480 | ) | | (4,623 | ) | | (4,015 | ) |
| Net increase (decrease) in cash and cash equivalents | $ | 109 |
| | $ | (48 | ) | | $ | 75 |
| | $ | (21 | ) | | $ | 4 |
| | $ | 16 |
|
Cash Flows
NEE's increase in cash flows from operating activities for 2016 and 2015 primarily reflects operating cash generated from additional wind and solar facilities that were placed in service during or after 2015 and 2014, respectively.
NEE's sources and uses of cash for 2016, 2015 and 2014 were as follows:
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 |
| | (millions) |
| Sources of cash: | | | | | |
| Cash flows from operating activities | $ | 6,336 |
| | $ | 6,116 |
| | $ | 5,500 |
|
| Long-term borrowings | 5,657 |
| | 5,772 |
| | 5,054 |
|
| Proceeds from differential membership investors, net of payments | 1,737 |
| | 669 |
| | 907 |
|
| Sale of independent power and other investments of NEER | 658 |
| | 52 |
| | 307 |
|
| Cash grants under the Recovery Act | 335 |
| | 8 |
| | 343 |
|
| Issuances of common stock - net | 537 |
| | 1,298 |
| | 633 |
|
| Net increase in commercial paper and other short-term debt | — |
| | — |
| | 451 |
|
| Proceeds from sale of noncontrolling interest in subsidiaries | 645 |
| | 345 |
| | 438 |
|
| Other sources - net | — |
| | 107 |
| | — |
|
| Total sources of cash | 15,905 |
| | 14,367 |
| | 13,633 |
|
| Uses of cash: | | | | | |
| Capital expenditures, independent power and other investments and nuclear fuel purchases | (9,636 | ) | | (8,377 | ) | | (7,017 | ) |
| Retirements of long-term debt | (3,310 | ) | | (3,972 | ) | | (4,750 | ) |
| Net decrease in commercial paper and other short-term debt | (268 | ) | | (356 | ) | | — |
|
| Dividends | (1,612 | ) | | (1,385 | ) | | (1,261 | ) |
| Other uses - net | (358 | ) | | (283 | ) | | (466 | ) |
| Total uses of cash | (15,184 | ) | | (14,373 | ) | | (13,494 | ) |
| Net increase (decrease) in cash and cash equivalents | $ | 721 |
| | $ | (6 | ) | | $ | 139 |
|
NEE's primary capital requirements are for expanding and enhancing FPL's electric system and generatinggeneration 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 20132016, 20122015 and 20112014.
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 |
| | (millions) |
| FPL: | | | | | |
| Generation: | | | | | |
| New | $ | 1,128 |
| | $ | 686 |
| | $ | 744 |
|
| Existing | 723 |
| | 811 |
| | 905 |
|
| Transmission and distribution | 1,848 |
| | 1,681 |
| | 1,307 |
|
| Nuclear fuel | 158 |
| | 205 |
| | 174 |
|
| General and other | 331 |
| | 384 |
| | 148 |
|
| Other, primarily change in accrued property additions and exclusion of AFUDC - equity | (254 | ) | | (134 | ) | | (37 | ) |
| Total | 3,934 |
| | 3,633 |
| | 3,241 |
|
| NEER: | | |
|
| |
|
|
| Wind | 2,474 |
| | 1,029 |
| | 2,136 |
|
| Solar | 1,554 |
| | 1,494 |
| | 546 |
|
| Nuclear, including nuclear fuel | 255 |
| | 315 |
| | 262 |
|
| Natural gas pipelines | 853 |
| | 1,198 |
| | 74 |
|
| Other | 385 |
| | 625 |
| | 683 |
|
| Total | 5,521 |
| | 4,661 |
| | 3,701 |
|
| Corporate and Other | 181 |
| | 83 |
| | 75 |
|
| Total capital expenditures, independent power and other investments and nuclear fuel purchases | $ | 9,636 |
| | $ | 8,377 |
| | $ | 7,017 |
|
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 |
| | (millions) |
| FPL: | | | | | |
| Generation: | | | | | |
| New | $ | 931 |
| | $ | 2,488 |
| | $ | 1,424 |
|
| Existing | 655 |
| | 520 |
| | 907 |
|
| Transmission and distribution | 873 |
| | 966 |
| | 880 |
|
| Nuclear fuel | 212 |
| | 215 |
| | 365 |
|
| General and other | 162 |
| | 95 |
| | 213 |
|
| Other, primarily the exclusion of AFUDC - equity and change in accrued property additions | 70 |
| | 1 |
| | (287 | ) |
| Total | 2,903 |
| | 4,285 |
| | 3,502 |
|
| NEER: | | | | | |
| Wind | 1,725 |
| | 2,365 |
| | 1,037 |
|
| Solar | 914 |
| | 1,235 |
| | 519 |
|
| Nuclear, including nuclear fuel | 269 |
| | 286 |
| | 686 |
|
| Other | 705 |
| | 795 |
| | 532 |
|
| Total | 3,613 |
| | 4,681 |
| | 2,774 |
|
| Corporate and Other | 166 |
| | 495 |
| | 352 |
|
| Total capital expenditures, independent power and other investments and nuclear fuel purchases | $ | 6,682 |
| | $ | 9,461 |
| | $ | 6,628 |
|
Liquidity
In January 2014,early February 2017, FPL and NEECH announced that it will redeem, on March 1, 2014, allextended the maturity date for a portion of their bank revolving line of credit facilities and NEECH increased a portion of its $375 million aggregate principal amount Series F Junior Subordinated Debentures due 2069 bearing interest at an annual rate of 8.75%.
Liquidity
At December 31, 2013, NEE's total net available liquidity was approximately $6.7 billion, of which FPL's portion was approximately $3.0 billion.revolving credit facilities. The table below provides the components of FPL's and NEECH's estimated net available liquidity at December 31, 2013:
as of February 10, 2017 reflecting these changes.
| | | | | | | | | Maturity Date | | | | | | Maturity Date |
| | FPL | | NEECH | | Total | | FPL | | NEECH | FPL | | NEECH | | Total | | FPL | | NEECH |
| | | | (millions) | | | | | | (millions) | | | |
Bank revolving line of credit facilities(a) | $ | 3,000 |
| | $ | 4,850 |
| | $ | 7,850 |
| | (b) | | (b) | $ | 2,916 |
| | $ | 4,964 |
| | $ | 7,880 |
| | 2018 - 2022 | | 2018 - 2022 |
| Less letters of credit | (3 | ) | | (1,128 | ) | | (1,131 | ) | | |
Issued letters of credit(b) | | (3 | ) | | (382 | ) | | (385 | ) | |
| | 2,997 |
| | 3,722 |
| | 6,719 |
| | 2,913 |
| | 4,582 |
| | 7,495 |
| |
| | | | | | | | | | | | | |
| Revolving credit facility | 235 |
| | — |
| | 235 |
| | May 2014 | | |
| Less borrowings | — |
| | — |
| | — |
| | |
| Revolving credit facilities | | 1,200 |
| | 1,360 |
| | 2,560 |
| | 2017 - 2019 | | 2017 - 2022 |
Borrowings(b) | | (1,000 | ) | | — |
| | (1,000 | ) | |
| | 235 |
| | — |
| | 235 |
| | 200 |
| | 1,360 |
| | 1,560 |
| |
| | | | | | | | | | | | | |
Letter of credit facilities(c) | — |
| | 250 |
| | 250 |
| | 2015 | — |
| | 650 |
| | 650 |
| | 2017 - 2019 |
| Less letters of credit | — |
| | (221 | ) | | (221 | ) | | |
Issued letters of credit(b) | | — |
| | (312 | ) | | (312 | ) | |
| | — |
| | 29 |
| | 29 |
| | — |
| | 338 |
| | 338 |
| |
| | | | | | | | | | | | | |
| Subtotal | 3,232 |
| | 3,751 |
| | 6,983 |
| | 3,113 |
| | 6,280 |
| | 9,393 |
| |
| | | | | | | | | | | | | |
Cash and cash equivalents | 19 |
| | 418 |
| | 437 |
| | 35 |
| | 684 |
| | 719 |
| |
| Less commercial paper | (204 | ) | | (487 | ) | | (691 | ) | | |
Outstanding commercial paper and other short-term debt(b) | | (1,433 | ) | | (40 | ) | | (1,473 | ) | |
| Net available liquidity | $ | 3,047 |
| | $ | 3,682 |
| | $ | 6,729 |
| | $ | 1,715 |
| | $ | 6,924 |
| (d) | $ | 8,639 |
| (d) | |
______________________
| |
| (a) | Provide for the funding of loans up to $7,850$7,880 million ($3,0002,916 million for FPL) and the issuance of letters of credit up to $6,600$3,050 million ($2,500670 million for FPL). The entire amount of the credit facilities is available for general corporate purposes and to provide additional liquidity in the event of a loss to the companies’ or their subsidiaries’ operating facilities (including, in the case of FPL, a transmission and distribution property loss). FPL’s bank revolving line of credit facilities are also available to support the purchase of $633$778 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 Approximately $2,315 million of FPL's and $750$3,730 million of NEECH's bank revolving line of credit facilities expire in 2016, essentially all2022. |
| |
| (b) | As of the remaining facilities at each of FPL and NEECH expire in 2019.January 31, 2017. |
| |
| (c) | Only available for the issuance of letters of credit. |
| |
| (d) | Excludes two variable rate bi-lateral term loan agreements totaling $7.5 billion discussed below. |
As of February 21, 2014, 6823, 2017, 67 banks participate in FPL’s and NEECH’s revolving credit facilities, with no one bank providing more than 6%7% of the combined revolving credit facilities. European banks provide approximately 3223% of the combined revolving credit facilities. Pursuant to a 1998 guarantee agreement, NEE guarantees the payment of NEECH’s debt obligations under theits revolving credit facilities.In order for FPL or NEECH to borrow or to have letters of credit issued under the terms of their respective revolving credit facilities and, also for NEECH, its letter of credit facilities, FPL, in the case of FPL, and NEE, in the case of NEECH, are required, among other things, to maintain a ratio of funded debt to total capitalization that does not exceed a stated ratio.The FPL and NEECH revolving credit facilities also contain default and related acceleration provisions relating to, among other things, failure of FPL and NEE, as the case may be, to maintain the respective ratio of funded debt to total capitalization at or below the specified ratio. At December 31, 2013,2016, each of NEE and FPL was in compliance with its required ratio.
Additionally, a NEER subsidiary has fiveat December 31, 2016, certain subsidiaries of NEP had credit or loan facilities with available liquidity as set forth in the table below.
|
| | | | | | | | | |
| | Amount | | Amount Remaining Available at December 31, 2016 | | Rate | | Maturity Date | | Purpose |
| | (millions) | | | | | | |
Senior secured revolving credit facility(a) | $250 | | $250 | | Variable | | 2019 | | Working capital, expansion projects, acquisitions and general business purposes |
Senior secured limited-recourse revolving loan facility(b) | $150 | | $— | | Variable | | 2020 | | General business purposes |
————————————
| |
| (a) | NEP OpCo and one of its direct subsidiaries are required to comply with certain financial covenants on a quarterly basis and NEP OpCo's ability to pay cash distributions to its unit holders is subject to certain other restrictions. The revolving credit facility includes borrowing capacity for letters of credit and incremental commitments to increase the revolving credit facility up to $1 billion in the aggregate. Borrowings under the revolving credit facility are guaranteed by NEP OpCo and NEP. |
| |
| (b) | A certain NEP subsidiary (borrower) is required to satisfy certain conditions, including among other things, meeting a leverage ratio at the time of any borrowing that does not exceed a specified ratio. Borrowings under this revolving loan facility are secured by liens on certain of the borrower's assets and certain of the borrower's subsidiaries' assets, as well as the ownership interest in the borrower. The revolving loan facility contains default and related acceleration provisions relating to, among other things, failure of the borrower to maintain a leverage ratio at or below the specified ratio and a minimum interest coverage ratio. |
In February 2017, NEECH entered into two variable rate Canadian revolving creditbi-lateral term loan agreements with original capacity totaling C$750 million and expiration dates ranging from October 2014 to 2016. These facilitieseach providing for a $3.75 billion short-term, non-revolving term loan facility, for a total of $7.5 billion, the loan proceeds of which are available for general corporate purposes; however,purposes, including to finance a portion of the current intent is to use these facilitiespurchase price payable by NEE for the purchase, development, construction and/or operationacquisition of Canadian renewable generating assets. In orderOncor (see Item 1. Business - Overview). The obligation to borrow or issue letters of credit under the termsmake loans pursuant to these bi-lateral term loan agreements terminates in August 2017 and each loan agreement expires in February 2018. Each of these bi-lateral term loan agreements among other things, NEE is required to maintain a ratio of funded debt to total capitalization that does not exceed a stated ratio. These agreements also contain certain covenants and default and related acceleration provisions relating to, among other things, the failure of NEE to maintain amake required payments or to observe other covenants in the loan agreement, including financial covenants relating to the ratio of NEE’s funded debt to total capitalization, at or belowand certain bankruptcy-related events. NEE guarantees the specified ratio. The payment of debt obligations under the loan agreements pursuant to a 1998 guarantee agreement. There are currently no amounts outstanding under these agreements are ultimately guaranteed by NEE. As of December 31, 2013, approximately $230 million of capacity remained available.facilities.
Storm Restoration Costs
As of December 31, 2013, FPL had the capacity to absorb up to approximately $121 million in future prudently incurred storm restoration costs without seeking recovery through a rate adjustment from the FPSC or filing a petition with the FPSC. See Note 1 – Revenue and Rates.
Dodd-Frank Act
The Dodd-Frank Act, enacted into law in July 2010, among other things, provides for substantially increased regulation of the OTC derivatives market. The Dodd-Frank Act includes provisions that will require certain OTC derivatives, or swaps, to be centrally cleared and executed through an exchange or other approved trading platform. While the legislation is broad and detailed, there are still portions of the legislation that either require implementing rules to be adopted by federal governmental agencies including, but not limited to, the SEC and the CFTC or otherwise require further interpretive guidance from federal government agencies. NEE and FPL continue to monitor the development of rules related to the Dodd-Frank Act and are taking steps to comply with those rules that affect their businesses. A number of rules have been finalized and are effective, including the swap reporting and recordkeeping obligations applicable to derivative end users such as NEE and FPL. The implementation of these rules has not had a material effect on NEE and FPL; however, the rules have added, and are expected to add more, cost and compliance risk related to hedging activities. The rules related to collateral requirements have not been finalized. If those rules, when finalized, require NEE and FPL to post significant amounts of cash collateral with respect to swap transactions, NEE's and FPL's liquidity could be materially adversely affected.
NEE and FPL cannot predict the impact these new rules will have on their ability to hedge their commodity and interest rate risks or on OTC derivatives markets as a whole, but management believes that they could potentially have a material adverse effect on NEE's and FPL's risk exposure, as well as reduce market liquidity and further increase the cost of hedging activities.
Capital Support
Guarantees, Letters of Credit, Surety Bonds and GuaranteesIndemnifications (Guarantee Arrangements)
Certain subsidiaries of NEE including FPL,issue guarantees and obtain letters of credit and surety bonds, and issue guaranteesas well as provide indemnities, to facilitate commercial transactions with third parties and financings. LettersSubstantially all of credit, surety bondsthe guarantee arrangements are on behalf of NEE’s consolidated subsidiaries, as discussed in more detail below. NEE is not required to recognize liabilities associated with guarantee arrangements issued on behalf of its consolidated subsidiaries unless it becomes probable that they will be required to perform. At December 31, 2016, NEE believes that there is no material exposure related to these guarantee arrangements.
NEE subsidiaries issue guarantees related to equity contribution agreements associated with the development, construction and financing of certain power generation facilities, engineering, procurement and construction agreements and natural gas pipeline development projects. Commitments associated with these activities are included in the contracts table in Note 13.
In addition, as of December 31, 2016, NEE subsidiaries had approximately $2.4 billion in guarantees related to obligations under purchased power agreements, nuclear-related activities, payment obligations related to PTCs and the non-receipt of proceeds from cash grants under the Recovery Act, as well as other types of contractual obligations.
In some instances, subsidiaries of NEE elect to issue guarantees instead of posting other forms of collateral required under certain financing arrangements, as well as for other project-level cash management activities. As of December 31, 2016, these guarantees totaled approximately $607 million and support, among other things, cash management activities, including those related to debt service and O&M service agreements, as well as other specific project financing requirements.
Subsidiaries of NEE also issue guarantees to support customer supply and proprietary power and gas trading activities, including the buying and selling of wholesale and retail energy commodities, debtcommodities. As of December 31, 2016, the estimated mark-to-market exposure (the total amount that these subsidiaries of NEE could be required to fund based on energy commodity market prices at December 31, 2016) plus contract settlement net payables, net of collateral posted for obligations under these guarantees totaled approximately $650 million.
As of December 31, 2016, subsidiaries of NEE also had approximately $1.0 billion of standby letters of credit and related reserves, capital expenditures for NEER's windapproximately $333 million of surety bonds to support certain of the commercial activities discussed above. FPL's and solar development, nuclear activities and other contractual agreements. Substantially allNEECH's credit facilities are available to support the amount of NEE's and FPL's guarantee arrangements are on behalfthe standby letters of their consolidated subsidiaries for their related payment obligations.credit.
In addition, as part of contract negotiations in the normal course of business, certain subsidiaries of NEE have agreed and and certain of its subsidiaries, including FPL,in the future may agree to make payments to compensate or indemnify other parties, including those associated with asset divestitures, 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 or the imposition of additional taxes due to a change in tax law or interpretations of the tax law or the non-receipttriggering of renewable tax credits or proceeds from cash grantsgrant recapture provisions under the Recovery Act. NEE and FPL areis unable to develop an estimate of the maximum potential amount of future payments under some of these contracts because events that would obligate them to make payments have not yet occurred or, if any such event has occurred, they have not been notified of its occurrence.
In addition,Certain guarantee arrangements described above contain requirements for NEECH and FPL to maintain a specified credit rating. For a discussion of credit rating downgrade triggers see Credit Ratings below. 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 December 31, 2013, NEE had approximately $1.4 billion of standby letters of credit ($3 million for FPL), approximately $151 million of surety bonds ($22 million for FPL) and approximately $11.2 billion notional amount of guarantees and indemnifications ($18 million for FPL), of which approximately $7.3 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 December 31, 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,July 2015, NEE, NEECH and FPL filed a shelf registration statement with the SEC for an unspecified amount of securities which became effective upon filing. The amount of securities issuable by the companies is established from time to time by their respective boards of directors. As of February 21, 2014, securitiesSecurities 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
Contractual Obligations and Estimated Capital Expenditures
NEE’s and FPL’s commitments at December 31, 20132016 were as follows:
| | | | 2014 | | 2015 | | 2016 | | 2017 | | 2018 | | Thereafter | | Total | 2017 | | 2018 | | 2019 | | 2020 | | 2021 | | Thereafter | | Total |
| | (millions) | (millions) |
Long-term debt, including interest:(a) | | | | | | | | | | | | | | | | | | | | | | | | | | |
FPL | $ | 763 |
| | $ | 463 |
| | $ | 464 |
| | $ | 764 |
| | $ | 448 |
| | $ | 14,865 |
| (b) | $ | 17,767 |
| $ | 806 |
| | $ | 765 |
| | $ | 662 |
| | $ | 417 |
| | $ | 453 |
| | $ | 15,241 |
| | $ | 18,344 |
|
| NEER | 2,266 |
| | 740 |
| | 1,059 |
| | 664 |
| | 894 |
| | 4,257 |
| | 9,880 |
| 940 |
| | 1,573 |
| | 962 |
| | 1,174 |
| | 796 |
| | 7,640 |
| | 13,085 |
|
| Corporate and Other | 1,962 |
| | 2,382 |
| | 1,319 |
| | 1,617 |
| | 928 |
| | 15,316 |
| | 23,524 |
| 2,187 |
| | 1,039 |
| | 2,150 |
| | 1,353 |
| | 2,457 |
| | 11,971 |
| | 21,157 |
|
| Purchase obligations: | | | | | | | | | | | | | | | | | | | | | | | | | | |
FPL(c) | 5,359 |
| | 3,628 |
| | 3,043 |
| | 2,972 |
| | 2,997 |
| | 16,424 |
| | 34,423 |
| 7,335 |
| | 4,735 |
| | 5,435 |
| | 4,515 |
| | 4,925 |
| | 12,315 |
| | 39,260 |
|
NEER(d) | 1,220 |
| | 145 |
| | 170 |
| | 100 |
| | 91 |
| | 452 |
| | 2,178 |
| 1,385 |
| | 1,370 |
| | 140 |
| | 90 |
| | 75 |
| | 285 |
| | 3,345 |
|
Corporate and Other(e)(d) | 90 |
| | 220 |
| | 460 |
| | 180 |
| | 20 |
| | 55 |
| | 1,025 |
| 45 |
| | 10 |
| | — |
| | 5 |
| | — |
| | — |
| | 60 |
|
Elimination of FPL's purchase obligations to NEECH(f) | — |
| | — |
| | — |
| | (59 | ) | | (87 | ) | | (1,410 | ) | | (1,556 | ) | |
Elimination of FPL's purchase obligations to NEER(d) | | (59 | ) | | (87 | ) | | (84 | ) | | (81 | ) | | (79 | ) | | (1,167 | ) | | (1,557 | ) |
Asset retirement activities:(g)(e) | | | | | | | | | | | | | | | | | | | | | | | | | | |
FPL(h)(f) | 7 |
| | — |
| | — |
| | — |
| | — |
| | 6,989 |
| | 6,996 |
| 16 |
| | 10 |
| | 3 |
| | 2 |
| | 2 |
| | 8,709 |
| | 8,742 |
|
NEER(i)(g) | — |
| | — |
| | — |
| | — |
| | — |
| | 12,937 |
| | 12,937 |
| — |
| | — |
| | 6 |
| | — |
| | 1 |
| | 13,634 |
| | 13,641 |
|
| Other commitments: | | | | | | | | | | | | | | | | | | | | | | | | | | |
NEER(j)(h) | 73 |
| | 95 |
| | 105 |
| | 124 |
| | 172 |
| | 483 |
| | 1,052 |
| 163 |
| | 215 |
| | 222 |
| | 119 |
| | 112 |
| | 447 |
| | 1,278 |
|
| Total | $ | 11,740 |
| | $ | 7,673 |
| | $ | 6,620 |
| | $ | 6,362 |
| | $ | 5,463 |
| | $ | 70,368 |
| | $ | 108,226 |
| $ | 12,818 |
| | $ | 9,630 |
| | $ | 9,496 |
| | $ | 7,594 |
| | $ | 8,742 |
| | $ | 69,075 |
| | $ | 117,355 |
|
_______________________________________________
| |
| (a) | Includes principal, interest, and interest rate swaps.contracts and payments by NEE under stock purchase contracts. Variable rate interest was computed using December 31, 20132016 rates. See Note 11. |
| |
| (b) | Includes $633 million of tax exempt bonds of approximately $9 million in 2020, $46 million in 2021 and $723 million thereafter that permit individual bond holders to tender the bonds for purchase at any time prior to maturity. In the event bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture. If the remarketing is unsuccessful, FPL would be required to purchase the tax exempt bonds. As of December 31, 2013,2016, all tax exempt bonds tendered for purchase have been successfully remarketed. FPL’s bank revolving line of credit facilities are available to support the purchase of tax exempt bonds. |
| |
| (c) | Represents required capacity and minimum charges under long-term purchased power and fuel contracts, projected capital expenditures through 2021 and the purchase price of the Indiantown generation facility (see Note 13 - Contracts),Commitments and projected capital expenditures through 2018 (see Note 13 - Commitments)Contracts). |
| |
| (d) | Represents firm commitments primarily in connection with construction and development activities and fuel-related contracts. See Note 13 - Commitments and Contracts. |
| |
(e) | Represents firm commitments primarily related to equity contributions by a NEECH subsidiary to Sabal Trail. See Note 13 - Contracts. |
| |
(f) | See Note 13 - Contracts. |
| |
(g)(e) | Represents expected cash payments adjusted for inflation for estimated costs to perform asset retirement activities. |
| |
(h)(f) | At December 31, 2013,2016, FPL had approximately $3,199$3,665 million in restricted funds for the payment of its portion of future expenditures to decommission FPL’sthe Turkey Point and St. Lucie nuclear units, which are included in NEE’s and FPL’s special use funds. See Note 12. |
| |
(i)(g) | At December 31, 2013, NEER’s 88.23% portion of Seabrook’s and 70% portion of Duane Arnold’s and its Point Beach’s2016, NEER had approximately $1,769 million in restricted funds for the payment of its portion of future expenditures to decommission itsSeabrook, Duane Arnold and Point Beach nuclear units totaled approximately $1,507 million andwhich are included in NEE’s special use funds. See Note 12. |
| |
(j)(h) | Represents estimated cash distributions related to differential membership interests and payments related to the acquisition of certain development rights. For further discussion of differential membership interests, see Note 1 - Sale of Differential Membership Interests. |
Credit Ratings
NEE’s and FPL’s liquidity, ability to access credit and capital markets, cost of borrowings and collateral posting requirements under certain agreements areis dependent on theirits and its subsidiaries credit ratings. At February 21, 2014,23, 2017, Moody’s Investors Service, Inc. (Moody’s), Standard & Poor’s Ratings Services (S&P) and Fitch Ratings (Fitch) had assigned the following credit ratings to NEE, FPL and NEECH:
|
| | | | | |
| | Moody's(a) | | S&P(a) | | Fitch(a) |
NEE:(b) | | | | | |
| Corporate credit rating | Baa1 | | A- | | A- |
| | | | | | |
FPL:(b) | | | | | |
| Corporate credit rating | A1 | | A- | | A |
| First mortgage bonds | Aa2 | | A | | AA- |
Pollution control, solid waste disposal and industrial development revenue bonds(c) | VMIG-1VMIG-1/P-1 | | AA-2 | | A+F1 |
| Commercial paper | P-1 | | A-2 | | F1 |
| | | | | | |
NEECH:(b) | | | | | |
| Corporate credit rating | Baa1 | | A- | | A- |
| Debentures | Baa1 | | BBB+ | | A- |
| Junior subordinated debentures | Baa2 | | BBB | | BBB |
| Commercial paper | P-2 | | A-2 | | F1F2 |
_______________________________________________
| |
| (a) | A security rating is not a recommendation to buy, sell or hold securities and should be evaluated independently of any other rating. The rating is subject to revision or withdrawal at any time by the assigning rating organization. |
| |
| (b) | The outlook indicated by each of Moody's, S&P and Fitch is stable. |
| |
| (c) | Short-term ratings are presented as all bonds outstanding are currently paying a short-term interest rate. At FPL's election, a portion or all of the bonds may be adjusted to a long-term interest rate. |
NEE and its subsidiaries including FPL, have no credit rating downgrade triggers that would accelerate the maturity dates of outstanding debt. A change in ratings is not an event of default under applicable debt instruments, and while there are conditions to drawing on the credit facilities noted above, the maintenance of a specific minimum credit rating is not a condition to drawing on these credit facilities.
Commitment fees and interest rates on loans under these credit facilities’ agreements are tied to credit ratings. A ratings downgrade also could reduce the accessibility and increase the cost of commercial paper and other short-term debt issuances and borrowings and additional or replacement credit facilities. In addition, a ratings downgrade could result in, among other things, the requirement that NEE subsidiaries including FPL, post collateral under certain agreements and guarantee arrangements, including, but not limited to, those related to fuel procurement, power sales and purchases, nuclear decommissioning funding, debt-related reserves and trading activities. FPL’s and NEECH’s credit facilities are available to support these potential requirements.
Covenants
NEE's charter does not limit the dividends that may be paid on its common stock. As a practical matter, the ability of NEE to pay dividends on its common stock is dependent upon, among other things, dividends paid to it by its subsidiaries. For example, FPL pays dividends to NEE in a manner consistent with FPL's long-term targeted capital structure. However, the mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends to NEE and the issuance of additional first mortgage bonds. Additionally, in some circumstances, the mortgage restricts the amount of retained earnings that FPL can use to pay cash dividends on its common stock. The restricted amount may change based on factors set out in the mortgage. Other than this restriction on the payment of common stock dividends, the mortgage does not restrict FPL's use of retained earnings. As of December 31, 2013,2016, no retained earnings were restricted by these provisions of the mortgage and, in light of FPL's current financial condition and level of earnings, management does not expect that planned financing activities or dividends would be affected by these limitations.
FPL may issue first mortgage bonds under its mortgage subject to its meeting an adjusted net earnings test set forth in the mortgage, which generally requires adjusted net earnings to be at least twice the annual interest requirements on, or at least 10% of the aggregate principal amount of, FPL’s first mortgage bonds including those to be issued and any other non-junior FPL indebtedness. As of December 31, 2013,2016, coverage for the 12 months ended December 31, 20132016 would have been approximately 6.88.5 times the annual interest requirements and approximately 3.64.2 times the aggregate principal requirements. New first mortgage bonds are also limited to an amount equal to the sum of 60% of unfunded property additions after adjustments to offset property retirements, the amount of retired first mortgage bonds or qualified lien bonds and the amount of cash on deposit with the mortgage trustee. As of December 31, 2013,2016, FPL could have issued in excess of $10.5$13.5 billion of additional first mortgage bonds based on the unfunded property additions and in excess of $5.8$6.3 billion based on retired first mortgage bonds. As of December 31, 2013,2016, no cash was deposited with the mortgage trustee for these purposes.
In September 2006, NEE and NEECH executed a Replacement Capital Covenant (September(as amended, September 2006 RCC) in connection with NEECH's offering of $350 million principal amount of Series B Enhanced Junior Subordinated Debentures due 2066 (Series B junior
subordinated debentures). The September 2006 RCC is for the benefit of persons that buy, hold or sell a specified series of long‑termlong-term indebtedness (covered debt) of NEECH (other than the Series B junior subordinated debentures) or, in certain cases, of NEE. FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the September 2006 RCC. The September 2006 RCC provides that NEECH may redeem, and NEE or NEECH may purchase, any Series B junior subordinated debentures on or before October 1, 2036, only to the extent that the redemption or purchase price does not exceed a specified amount of proceeds from the sale of qualifying securities, subject to certain limitations described in the September 2006 RCC. Qualifying securities are securities that have equity-like characteristics that are the same as, or more equity-like than, the Series B junior subordinated debentures at the time of redemption or purchase, which are sold within 180365 days prior to the date of the redemption or repurchase of the Series B junior subordinated debentures.
In June 2007, NEE and NEECH executed a Replacement Capital Covenant (June(as amended, June 2007 RCC) in connection with NEECH's offering of $400 million principal amount of its Series C Junior Subordinated Debentures due 2067 (Series C junior subordinated debentures). The June 2007 RCC is for the benefit of persons that buy, hold or sell a specified series of covered debt of NEECH (other than the Series C junior subordinated debentures) or, in certain cases, of NEE. FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the June 2007 RCC. The June 2007 RCC provides that NEECH may redeem or purchase, or satisfy, discharge or defease (collectively, defease), and NEE and any majority-owned subsidiary of NEE or NEECH may purchase, any Series C junior subordinated debentures on or before June 15, 2037, only to the extent that the principal amount defeased or the applicable redemption or purchase price does not exceed a specified amount raised from the issuance, during the 180365 days prior to the date of that redemption, purchase or defeasance, of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than, the applicable characteristics of the Series C junior subordinated debentures at the time of redemption, purchase or defeasance, subject to certain limitations described in the June 2007 RCC.
In September 2007, NEE and NEECH executed a Replacement Capital Covenant (September(as amended, September 2007 RCC) in connection with NEECH's offering of $250 million principal amount of its Series D Junior Subordinated Debentures due 2067 (Series D junior subordinated debentures). The September 2007 RCC is for the benefit of persons that buy, hold or sell a specified series of covered debt of NEECH (other than the Series D junior subordinated debentures) or, in certain cases, of NEE. FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the September 2007 RCC. The September
2007 RCC provides that NEECH may redeem, purchase, or defease, and NEE and any majority-owned subsidiary of NEE or NEECH may purchase, any Series D junior subordinated debentures on or before September 1, 2037, only to the extent that the principal amount defeased or the applicable redemption or purchase price does not exceed a specified amount raised from the issuance, during the 180365 days prior to the date of that redemption, purchase or defeasance, of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than, the applicable characteristics of the Series D junior subordinated debentures at the time of redemption, purchase or defeasance, subject to certain limitations described in the September 2007 RCC.
New Accounting Rules and NEECH executed a Replacement Capital Covenant (March 2009 RCC) in connection with NEECH's offering of $375 million principal amount of its Series F Junior Subordinated Debentures due 2069 (Series F junior subordinated debentures). The March 2009 RCC is for the benefit of persons that buy, hold or sell a specified series of covered debt of NEECH (other than the Series F junior subordinated debentures) or, in certain cases, of NEE. FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the March 2009 RCC. The March 2009 RCC provides that NEECH may redeem, purchase, or defease, and NEE and any majority-owned subsidiary of NEE or NEECH may purchase, any Series F junior subordinated debentures on or before March 1, 2039, onlyInterpretations
Amendments to the extentConsolidation Analysis - In February 2015, the Financial Accounting Standards Board (FASB) issued an accounting standards update that modified consolidation guidance. See Note 8.
Revenue Recognition - In May 2014, the principal amount defeased or the applicable redemption or purchase price does not exceed a specified amount raised from the issuance, during the 180 days priorFASB issued an accounting standards update related to the daterecognition of that redemption, purchase or defeasance, of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than, the applicable characteristics of the Series F junior subordinated debentures at the time of redemption, purchase or defeasance, subject to certain limitations described in the March 2009 RCC.revenue from contracts with customers and required disclosures. See Note 1 - Revenues and Rates.
Financial Instruments - In January 2016, the FASB issued an accounting standards update which modifies guidance regarding certain aspects of recognition, measurement, presentation and disclosure of financial instruments. See Note 4 - Financial Instruments Accounting Standards Update.
Leases - In February 2016, the FASB issued an accounting standards update which requires, among other things, that lessees recognize a lease liability and a right-of-use asset for all leases. See Note 1 - Leases.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
NEE’s and FPL’s significant accounting policies are described in Note 1 to the consolidated financial statements, which were prepared under GAAP. Critical accounting policies are those that NEE and FPL believebelieves are both most important to the portrayal of theirits financial condition and results of operations, and require complex, subjective judgments, often as a result of the need to make estimates and assumptions about the effect of matters that are inherently uncertain. Judgments and uncertainties affecting the application of those policies may result in materially different amounts being reported under different conditions or using different assumptions.
NEE and FPL considerconsiders the following policies to be the most critical in understanding the judgments that are involved in preparing theirits consolidated financial statements:
Accounting for Derivatives and Hedging Activities
NEE and FPL useuses 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
primarily with outstanding and forecastedexpected future debt issuances.issuances and borrowings. 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.
Nature of Accounting Estimates
Accounting pronouncements require the use of fair value accounting if certain conditions are met, which requires significant judgment to measure the fair value of assets and liabilities. This applies not only to traditional financial derivative instruments, but to any contract having the accounting characteristics of a derivative. Much of the existing accounting guidance related to derivatives focuses on when certain contracts for the purchase and sale of power and certain fuel supply contracts can be excluded from derivative accounting rules, however the guidance does not address all contract issues. As a result, significant judgment must be used in applying derivatives accounting guidance to contracts. In the event changes in interpretation occur, it is possible that contracts that currently are excluded from derivatives accounting rules would have to be recorded on the balance sheet at fair value, with changes in the fair value recorded in the statement of income.
Assumptions and Accounting Approach
NEE's and FPL’s derivativeDerivative instruments, when required to be marked to market, are recorded on the balance sheet at fair value. Fair values for some of the longer-term contracts where liquid markets are not available are derived through internally developed models which estimate the fair value of a contract by calculating the present value of the difference between the contract price and the forward prices. Forward prices represent the price at which a buyer or seller could contract today to purchase or sell a commodity at a future date.The near-term forward market for electricity is generally liquid and therefore the prices in the early years of the forward curves reflect observable market quotes. However, in the later years, the market is much less liquid and forward price curves must be developed using factors including the forward prices for the commodities used as fuel to generate electricity, the expected system heat rate (which measures the efficiency of power plants in converting fuel to electricity) in the region where the purchase or sale takes place, and a fundamental forecast of expected spot prices based on modeled supply and demand in the region. NEE estimates the fair value of interest rate and foreign currency derivatives using a discounted cash flows valuation technique based on the net amount of estimated future cash inflows and outflows related to the derivative agreements. The assumptions in these models are critical since any changes therein could have a significant impact on the fair value of the derivative.
At FPL, substantially all changes in the fair value of energy derivative transactions are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel clause. See Note 3.
In 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 equity in earnings of equity method investees in NEE’s consolidated statements of income.
For those transactions accountedIn January 2016, NEE discontinued hedge accounting for asits cash flow and fair value hedges much of the effects ofrelated to interest rate and foreign currency derivative instruments and, therefore, all changes in the derivatives' fair value are reflected in OCI, a component of common shareholders’ equity, rather than being recognized in current earnings. For those transactions accounted for as fair value hedges, the effectsinterest expense in NEE's consolidated statements of changes in fair value are reflected in current earnings offset by changes inincome. NEE estimates the fair value of the item being hedged.these derivatives based on a discounted cash flows valuation technique utilizing observable inputs.
Certain hedgingderivative transactions at NEER are 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. These changes in fair value are capturedreflected in the non-qualifying hedge category in computing adjusted earnings. Thisearnings and could be significant to NEER’s results 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. For additional information regarding derivative instruments, see Note 3, Overview and Energy Marketing and Trading and Market Risk Sensitivity.
Accounting for Pensions and Other PostretirementPension Benefits
NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. NEE also has a supplemental executive retirement plan (SERP) which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees. The impact of the SERP component is included within the pension plan as discussed below. Management believes that, based on actuarial assumptions and the well-funded status of the pension plan, NEE will not be required to make any cash contributions to the qualified pension plan in the near future.
In addition to pension benefits, NEE sponsors a contributory postretirement plan for health care and life insurance benefits (other benefits plan) for retirees of NEE and its subsidiaries meeting certain eligibility requirements. The qualified pension plan has a fully funded trust dedicated to providing the benefits under the plan. The other benefits plan has a partially funded trust dedicated to providing benefits related to life insurance. NEE allocates net periodic benefit income or cost associated with the pension and other benefits plansplan to its subsidiaries annually using specific criteria.
Nature of Accounting Estimates
For the pension plan, the benefit obligation is the actuarial present value, as of the December 31 measurement date, of all benefits attributed by the pension benefit formula to employee service rendered to that date. The amount of benefit to be paid depends on a number of future events incorporated into the pension benefit formula, including estimatesan estimate of the average remaining life of employees/survivors andas well as the average years of service rendered. The projected benefit obligation is measured based on assumptions concerning future interest rates and future employee compensation levels. For the other benefits plan, the benefit obligation is the actuarial present value as of the December 31 measurement date of all future benefits attributed under the terms of the other benefits plan to employee service rendered to that date. NEE derives pension income and the cost of the other benefits plan from actuarial calculations based on eachthe plan’s provisions and management’svarious management assumptions regardingincluding discount rate, rate of increase in compensation levels and expected long-term rate of return on plan assets and, in the case of the other benefits plan, health care cost trend rates.assets.
Assumptions and Accounting Approach
Accounting guidance requires recognition of the funded status of benefit plansthe pension plan in the balance sheet, with changes in the funded status recognized in other comprehensive income within shareholders’ equity in the year in which the changes occur. Since NEE is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, this accounting guidance is reflected at NEE and not allocated to the subsidiaries. The portion of previously unrecognized actuarial gains and losses and prior service costs or credits and transition obligations that are estimated to be allocable to FPL as net periodic benefit (income) cost in future periods and that otherwise would be recorded in AOCI are classified as regulatory assets and liabilities at NEE in accordance with regulatory treatment.
PensionNet periodic pension income and the cost of the other benefits plan areis included in O&M expenses, and areis calculated using a number of actuarial assumptions. Those assumptions for the years ended December 31, 2013, 20122016, 2015 and 20112014 include:
|
| | | | | | | | |
| | 2016 | | 2015 | | 2014 |
| Discount rate | 4.35 | % | | 3.95 | % | | 4.80 | % |
| Salary increase | 4.10 | % | | 4.10 | % | | 4.00 | % |
Expected long-term rate of return(a) | 7.35 | % | | 7.35 | % | | 7.75 | % |
___________________
| |
| (a) | In 2016 and 2015, an expected long-term rate of return of 7.75% is presented net of investment management fees. |
an expected long-term rate54
assumed increases in salary of 4.00%, and
weighted-average discount rates of 4.00%, 4.65% and 5.00% for the pension plan and 3.75%, 4.53% and 5.25% for the other benefits plan, respectively.
In developing these assumptions, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. In addition, for the expected long-term rate of return on fundpension plan assets, NEE considered different models, capital market return assumptions and historical returns for a portfolio with an equity/bond asset mix similar to its funds,pension fund, as well as its funds'pension fund's historical compounded returns. NEE believes that 7.75%7.35% is a reasonable long-term rate of return, net of investment management fees, on its pension plan and other benefits plan assets. NEE will continue to evaluate all of its actuarial assumptions, including its expected rate of return, at least annually, and will adjust them as necessary.appropriate.
NEE utilizes in its determination of pension and other benefits plan expense or income a market-related valuation of plan assets. This market-related valuation reduces year-to-year volatility and recognizes investment gains or losses over a five-year period following the year in which they occur. Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of plan assets and the actual return realized on those plan assets. Since the market-related value of plan assets recognizes gains or losses over a five-year period, the future value of plan assets will be affected as previously deferred gains or losses are recognized. Such gains and losses together with other differences between actual results and the estimates used in the actuarial valuations are deferred and recognized in determining pension income and other benefits plan expense only to the extent they exceed 10% of the greater of projected benefit obligations or the market-related value of plan assets.
The following table illustrates the effect on net periodic benefit income of changing the critical actuarial assumptions discussed above, while holding all other assumptions constant:
| | | | | Decrease in 2013 Net Periodic Benefit Income | | Decrease in 2016 Net Periodic Income |
| | Change in Assumption | | NEE | | FPL | Change in Assumption | | NEE | | FPL |
| | | (millions) | | (millions) |
| Expected long-term rate of return | (0.5)% | | $ | (16 | ) | | $ | (11 | ) | (0.5)% | | $ | (18 | ) | | $ | (12 | ) |
| Discount rate | (0.5)% | | $ | (10 | ) | | $ | (6 | ) | 0.5% | | $ | (4 | ) | | $ | (2 | ) |
| Salary increase | 0.5% | | $ | (3 | ) | | $ | (2 | ) | 0.5% | | $ | (2 | ) | | $ | (1 | ) |
NEE also utilizes actuarial assumptions about mortality to help estimate obligations of the pension plan. NEE has adopted the latest revised mortality tables and mortality improvement scales released by the Society of Actuaries, which adoption did not have a material impact on the pension plan's obligation.
See Note 2.
Carrying Value of Long-Lived Assets
NEE evaluates long-lived assets for impairment when events or changes in circumstances indicate that the carrying amount may not be recoverable.
Nature of Accounting Estimates
The amount of future net cash flows, the timing of the cash flows and the determination of an appropriate interest rate all involve estimates and judgments about future events. In particular, the aggregate amount of cash flows determines whether an impairment exists, and the timing of the cash flows is critical in determining fair value. Because each assessment is based on the facts and circumstances associated with each long-lived asset, the effects of changes in assumptions cannot be generalized.
Assumptions and Accounting Approach
An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset. The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset’s fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate. See Note 4Management's Discussion - Nonrecurring Fair Value Measurements and Note 6.NEER: Results of Operations - Gas Infrastructure.
Decommissioning and Dismantlement
The componentsNEE accounts for AROs under accounting guidance that requires a liability for the fair value of NEE’s and FPL’s decommissioningan ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of nuclear plants, dismantlementthe carrying amount of plants and other accrued asset removal costs are as follows:the long-lived assets.
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | FPL | | | | |
| | Nuclear Decommissioning | | Fossil/Solar Dismantlement | | Interim Removal Costs and Other | | NEER | | NEE |
| | December 31, | | December 31, | | December 31, | | December 31, | | December 31, |
| | 2013 |
| | 2012 |
| | 2013 |
| | 2012 |
| | 2013 |
| | 2012 |
| | 2013 |
| | 2012 |
| | 2013 |
| | 2012 |
|
| | (millions) |
| AROs | $ | 1,237 |
| | $ | 1,173 |
| | $ | 44 |
| | $ | 29 |
| | $ | 4 |
| | $ | 4 |
| | $ | 565 |
| | $ | 509 |
| | $ | 1,850 |
| | $ | 1,715 |
|
| Less capitalized ARO asset net of accumulated depreciation | — |
| | — |
| | (19 | ) | | (11 | ) | | — |
| | — |
| | — |
| | — |
| | (19 | ) | | (11 | ) |
Accrued asset removal costs(a) | 260 |
| | 234 |
| | 323 |
| | 338 |
| | 1,256 |
| | 1,378 |
| | — |
| | — |
| | 1,839 |
| | 1,950 |
|
Asset retirement obligation regulatory expense difference(a) | 2,062 |
| | 1,787 |
| | 22 |
| | 27 |
| | (2 | ) | | (1 | ) | | — |
| | — |
| | 2,082 |
| | 1,813 |
|
| Accrued decommissioning, dismantlement and other accrued asset removal costs | $ | 3,559 |
| (b) | $ | 3,194 |
| (b) | $ | 370 |
| (b) | $ | 383 |
| (b) | $ | 1,258 |
| (b) | $ | 1,381 |
| (b) | $ | 565 |
| | $ | 509 |
| | $ | 5,752 |
| | $ | 5,467 |
|
______________________
| |
(a) | Regulatory liability on NEE’s and FPL’s consolidated balance sheets. |
| |
(b) | Represents total amount accrued for ratemaking purposes. |
Nature of Accounting Estimates
The calculation of the future cost of retiring long-lived assets, including nuclear decommissioning and plant dismantlement costs, involves estimating the amount and timing of future expenditures and making judgments concerning whether or not such costs are considered a legal obligation. Estimating the amount and timing of future expenditures includes, among other things, making projections of when assets will be retired and ultimately decommissioned and how costs will escalate with inflation. In addition, NEE and FPL also makemakes interest rate and rate of return projections on theirits investments in determining recommended funding requirements for nuclear decommissioning costs. Periodically, NEE and FPL areis required to update these estimates and projections which can affect the annual expense amounts recognized, the liabilities recorded and the annual funding requirements for nuclear decommissioning costs. For example, an increase of 0.25% in the assumed escalation rates for nuclear decommissioning costs would increase NEE’s and FPL’s asset retirement obligations and conditional asset retirement obligations (collectively, AROs) as of December 31, 20132016 by $130 million and $97 million, respectively.$185 million.
Assumptions and Accounting Approach
NEE and FPL each account for AROs under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets.
FPL -For ratemaking purposes,purposes, FPL accrues and funds for nuclear plant decommissioning costs over the expected service life of each unit based on studies that are filed withapproved by the FPSC. The studies reflect, among other things, the expiration dates of the operating licenses for FPL’s nuclear units. The most recent studies, filed in 2010,2015, indicate that FPL’s portion of the future cost of decommissioning its four nuclear units, including spent fuel storage above what is expected to be refunded by the DOE under the spent fuel settlement agreement, is approximately $6.2$7.5 billion, or $2.5$3.0 billion expressed in 20132016 dollars.
FPL accrues the cost of dismantling its fossil and solar plants over the expected service life of each unit based on studies filed with the FPSC. Unlike nuclear decommissioning, dismantlement costs are not funded. The most recent studies became effective January 1, 2010.2017. At December 31, 2013,2016, FPL’s portion of the ultimate cost to dismantle its fossil and solar units is approximately $751 million,$1.3 billion, or $394$480 million expressed in 20132016 dollars. The majority of the dismantlement costs are not considered AROs. FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. Any differences between the ARO amountamount recorded and the amount recorded for ratemaking purposes are reported as a regulatory liability in accordance with regulatory accounting.
The components of FPL’s decommissioning of nuclear plants, dismantlement of plants and other accrued asset removal costs are as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Nuclear Decommissioning | | Fossil/Solar Dismantlement | | Interim Removal Costs and Other | | Total |
| | December 31, | | December 31, | | December 31, | | December 31, |
| | 2016 | | 2015 | | 2016 | | 2015 | | 2016 | | 2015 | | 2016 | | 2015 |
| | (millions) |
| AROs | $ | 1,852 |
| | $ | 1,764 |
| | $ | 62 |
| | $ | 53 |
| | $ | 5 |
| | $ | 5 |
| | $ | 1,919 |
| | $ | 1,822 |
|
| Less capitalized ARO asset net of accumulated depreciation | 355 |
| | 375 |
| | 32 |
| | 38 |
| | — |
| | — |
| | 387 |
| | 413 |
|
Accrued asset removal costs(a) | 297 |
| | 279 |
| | 322 |
| | 315 |
| | 1,325 |
| | 1,327 |
| | 1,944 |
| | 1,921 |
|
Asset retirement obligation regulatory expense difference(a) | 2,272 |
| | 2,147 |
| | 24 |
| | 37 |
| | (2 | ) | | (2 | ) | | 2,294 |
| | 2,182 |
|
Accrued decommissioning, dismantlement and other accrued asset removal costs(b) | $ | 4,066 |
| | $ | 3,815 |
| | $ | 376 |
| | $ | 367 |
| | $ | 1,328 |
| | $ | 1,330 |
| | $ | 5,770 |
| | $ | 5,512 |
|
______________________
| |
| (a) | Included in noncurrent regulatory liabilities on NEE’s and FPL’s consolidated balance sheets. |
| |
| (b) | Represents total amount accrued for ratemaking purposes. |
NEER -NEER records a liabilityliabilities for the present value of its expected nuclear plant decommissioning costs which isare determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning. The liability isliabilities are being accreted using the interest method through the date decommissioning activities are expected to be complete. At December 31, 2013,2016, the AROAROs for nuclear decommissioning of NEER’s nuclear plants totaled approximately $434 million. $451 million. NEER’s portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under the spent fuel settlement agreement, is estimated to be approximately $11.9$11.8 billion, or $2.0$2.0 billion expressed in 20132016 dollars.
See Note 1 - Asset Retirement Obligations Note 1and - Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs and Note 12.
Regulatory Accounting
NEE’s and FPL’sCertain of NEE's businesses are subject to rate regulation which results in the recording of regulatory assets and liabilities are as follows:liabilities. See Note 1 - Rate Regulation for a detail of NEE’s regulatory assets and liabilities.
|
| | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | December 31, | | December 31, |
| | 2013 | | 2012 | | 2013 | | 2012 |
| | (millions) |
| Regulatory assets: | | | | | | | |
| Current: | | | | | | | |
| Deferred clause and franchise expenses | $ | 192 |
| | $ | 75 |
| | $ | 192 |
| | $ | 75 |
|
| Other | $ | 116 |
| | $ | 113 |
| | $ | 105 |
| | $ | 106 |
|
| Noncurrent: | |
| | |
| | |
| | |
|
| Securitized storm-recovery costs | $ | 372 |
| | $ | 461 |
| | $ | 372 |
| | $ | 461 |
|
| Other | $ | 426 |
| | $ | 582 |
| | $ | 396 |
| | $ | 351 |
|
| Regulatory liabilities: | |
| | |
| | |
| | |
|
| Current, included in other current liabilities | $ | 65 |
| | $ | 65 |
| | $ | 63 |
| | $ | 65 |
|
| Noncurrent: | |
| | |
| | |
| | |
|
| Accrued asset removal costs | $ | 1,839 |
| | $ | 1,950 |
| | $ | 1,839 |
| | $ | 1,950 |
|
| Asset retirement obligation regulatory expense difference | $ | 2,082 |
| | $ | 1,813 |
| | $ | 2,082 |
| | $ | 1,813 |
|
| Other | $ | 462 |
| | $ | 309 |
| | $ | 386 |
| | $ | 309 |
|
Nature of Accounting Estimates
Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process. Regulatory assets and liabilities are included in rate base or otherwise earn (pay) a return on investment during the recovery period.
Assumptions and Accounting Approach
Accounting guidance allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities. If NEE's rate-regulated entities, primarily FPL, were no longer subject to cost-based rate regulation, the existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund. In addition, the regulators, including the FPSC for FPL, have the authority to disallow recovery of costs that it considersthey consider excessive or imprudently incurred. Such costs may include, among others, fuel and O&M expenses, the cost of replacing power lost when fossil and nuclear units are unavailable, storm restoration costs and costs associated with the construction or acquisition of new facilities. The continued applicability of regulatory accounting is assessed at each reporting period.
Energy Marketing and Trading and Market Risk SensitivityENERGY MARKETING AND TRADING AND MARKET RISK SENSITIVITY
NEE and FPL are exposed to risks associated with adverse changes in commodity prices, interest rates and equity prices.Financial instruments and positions affecting the financial statements of NEE and FPL described below are held primarily for purposes other than trading. Market risk is measured as the potential loss in fair value resulting from hypothetical reasonably possible changes in commodity prices, interest rates or equity prices over the next year. Management has established risk management policies to monitor and manage such market risks, as well as credit risks.
Commodity Price Risk
NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the commodity price risk inherent in the purchase and sale of fuel and electricity. In addition, NEE, through NEER, uses derivatives to optimize the value of its power generation and gas infrastructure assets and engages in power and gas marketing and trading activities to take advantage of expected future favorable price movements. See Critical Accounting Policies and Estimates - Accounting for Derivatives and Hedging Activities and Note 3.
During 20122015 and 2013,2016, the changes in the fair value of NEE’s consolidated subsidiaries’ energy contract derivative instruments were as follows:
|
| | | | | | | | | | | | | | | |
| | | Hedges on Owned Assets | | |
| | Trading | | Non- Qualifying | | FPL Cost Recovery Clauses | | NEE Total |
| | (millions) |
| Fair value of contracts outstanding at December 31, 2014 | $ | 320 |
| | $ | 898 |
| | $ | (363 | ) | | $ | 855 |
|
| Reclassification to realized at settlement of contracts | (227 | ) | | (359 | ) | | 471 |
| | (115 | ) |
| Inception value of new contracts | 18 |
| | 3 |
| | — |
| | 21 |
|
| Net option premium purchases (issuances) | (45 | ) | | 3 |
| | — |
| | (42 | ) |
| Changes in fair value excluding reclassification to realized | 293 |
| | 640 |
| | (326 | ) | | 607 |
|
| Fair value of contracts outstanding at December 31, 2015 | 359 |
| | 1,185 |
| | (218 | ) | | 1,326 |
|
| Reclassification to realized at settlement of contracts | (189 | ) | | (455 | ) | | 223 |
| | (421 | ) |
| Inception value of new contracts | 37 |
| | 15 |
| | — |
| | 52 |
|
| Net option premium purchases (issuances) | — |
| | 3 |
| | — |
| | 3 |
|
| Changes in fair value excluding reclassification to realized | 223 |
| | 236 |
| | 203 |
| | 662 |
|
| Fair value of contracts outstanding at December 31, 2016 | 430 |
|
| 984 |
|
| 208 |
|
| 1,622 |
|
| Net margin cash collateral paid (received) | | | | | | | (167 | ) |
| Total mark-to-market energy contract net assets (liabilities) at December 31, 2016 | $ | 430 |
| | $ | 984 |
| | $ | 208 |
| | $ | 1,455 |
|
|
| | | | | | | | | | | | | | | | | | | |
| | | Hedges on Owned Assets | | |
| | Trading | | Non- Qualifying | | OCI | | FPL Cost Recovery Clauses | | NEE Total |
| | (millions) |
| Fair value of contracts outstanding at December 31, 2011 | $ | 15 |
| | $ | 720 |
| | $ | 8 |
| | $ | (501 | ) | | $ | 242 |
|
| Reclassification to realized at settlement of contracts | 83 |
| | (122 | ) | | (8 | ) | | 663 |
| | 616 |
|
| Inception value of new contracts and contracts sold | 6 |
| | 22 |
| | — |
| | — |
| | 28 |
|
| Net option premium purchases (issuances) | (2 | ) | | 3 |
| | — |
| | — |
| | 1 |
|
| Changes in fair value excluding reclassification to realized | 159 |
| | 51 |
| | — |
| | (177 | ) | | 33 |
|
| Fair value of contracts outstanding at December 31, 2012 | 261 |
| | 674 |
| | — |
| | (15 | ) | | 920 |
|
| Reclassification to realized at settlement of contracts | (35 | ) | | (42 | ) | | — |
| | (20 | ) | | (97 | ) |
| Inception value of new contracts and contracts sold | 3 |
| | — |
| | — |
| | — |
| | 3 |
|
| Net option premium purchases (issuances) | (61 | ) | | (12 | ) | | — |
| | — |
| | (73 | ) |
| Changes in fair value excluding reclassification to realized | 133 |
| | (57 | ) | | — |
| | 81 |
| | 157 |
|
| Fair value of contracts outstanding at December 31, 2013 | 301 |
| | 563 |
| | — |
| | 46 |
| | 910 |
|
| Net margin cash collateral paid (received) | | | | | | | | | (279 | ) |
| Total mark-to-market energy contract net assets at December 31, 2013 | $ | 301 |
| | $ | 563 |
| | $ | — |
| | $ | 46 |
| | $ | 631 |
|
NEE’s total mark-to-market energy contract net assets (liabilities) at December 31, 20132016 shown above are included on the consolidated balance sheets as follows:
| | | | December 31, 2013 | December 31, 2016 |
| | (millions) | (millions) |
| Current derivative assets | $ | 471 |
| $ | 710 |
|
| Noncurrent derivative assets | 1,100 |
| 1,228 |
|
| Current derivative liabilities | (556 | ) | (248 | ) |
| Noncurrent derivative liabilities | (384 | ) | (235 | ) |
| NEE's total mark-to-market energy contract net assets | $ | 631 |
| $ | 1,455 |
|
The sources of fair value estimates and maturity of energy contract derivative instruments at December 31, 20132016 were as follows:
| | | | Maturity | Maturity |
| | 2014 | | 2015 | | 2016 | | 2017 | | 2018 | | Thereafter | | Total | 2017 | | 2018 | | 2019 | | 2020 | | 2021 | | Thereafter | | Total |
| | (millions) | (millions) |
| Trading: | | |
| Quoted prices in active markets for identical assets | $ | 76 |
| | $ | 22 |
| | $ | (6 | ) | | $ | — |
| | $ | — |
| | $ | — |
| | $ | 92 |
| $ | 61 |
| | $ | 11 |
| | $ | 4 |
| | $ | (4 | ) | | $ | (3 | ) | | $ | — |
| | $ | 69 |
|
| Significant other observable inputs | 67 |
| | (5 | ) | | 21 |
| | 17 |
| | (3 | ) | | (1 | ) | | 96 |
| 29 |
| | 43 |
| | 7 |
| | (5 | ) | | (10 | ) | | (18 | ) | | 46 |
|
| Significant unobservable inputs | (57 | ) | | 65 |
| | 38 |
| | 36 |
| | 3 |
| | 28 |
| | 113 |
| 106 |
| | 32 |
| | 33 |
| | 38 |
| | 30 |
| | 76 |
| | 315 |
|
| Total | 86 |
| | 82 |
| | 53 |
| | 53 |
| | — |
| | 27 |
| | 301 |
| 196 |
| | 86 |
| | 44 |
| | 29 |
| | 17 |
| | 58 |
| | 430 |
|
| Owned Assets - Non-Qualifying: | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Quoted prices in active markets for identical assets | (11 | ) | | 2 |
| | — |
| | — |
| | — |
| | — |
| | (9 | ) | (6 | ) | | 12 |
| | 7 |
| | 5 |
| | — |
| | — |
| | 18 |
|
| Significant other observable inputs | (66 | ) | | (18 | ) | | 30 |
| | 17 |
| | 3 |
| | 4 |
| | (30 | ) | 115 |
| | 100 |
| | 124 |
| | 99 |
| | 83 |
| | 74 |
| | 595 |
|
| Significant unobservable inputs | 43 |
| | 40 |
| | 59 |
| | 66 |
| | 69 |
| | 325 |
| | 602 |
| 45 |
| | 32 |
| | 27 |
| | 28 |
| | 16 |
| | 223 |
| | 371 |
|
| Total | (34 | ) | | 24 |
| | 89 |
| | 83 |
| | 72 |
| | 329 |
| | 563 |
| 154 |
| | 144 |
| | 158 |
| | 132 |
| | 99 |
| | 297 |
| | 984 |
|
| Owned Assets - FPL Cost Recovery Clauses: | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Quoted prices in active markets for identical assets | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
|
| Significant other observable inputs | 46 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 46 |
| 206 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 206 |
|
| Significant unobservable inputs | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| 2 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 2 |
|
| Total | 46 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 46 |
| 208 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 208 |
|
| Total sources of fair value | $ | 98 |
| | $ | 106 |
| | $ | 142 |
| | $ | 136 |
| | $ | 72 |
| | $ | 356 |
| | $ | 910 |
| $ | 558 |
| | $ | 230 |
| | $ | 202 |
| | $ | 161 |
| | $ | 116 |
| | $ | 355 |
| | $ | 1,622 |
|
With respect to commodities, NEE’s Exposure Management Committee (EMC), which is comprised of certain members of senior management, and NEE's chief executive officer are responsible for the overall approval of market risk management policies and the delegation of approval and authorization levels. The EMC and NEE's chief executive officer receive periodic updates on market positions and related exposures, credit exposures and overall risk management activities.
NEE uses a value-at-risk (VaR) model to measure commodity price market risk in its trading and mark-to-market portfolios. The VaR is the estimated nominal loss of market value based on a one-day holding period at a 95% confidence level using historical simulation methodology. As of December 31, 20132016 and 2012,2015, the VaR figures are as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Trading | | Non-Qualifying Hedges and FPL Cost Recovery Clauses(a) | | Total |
| | FPL | | NEER | | NEE | | FPL | | NEER | | NEE | | FPL | | NEER | | NEE |
| | | | | | | | | | (millions) | | | | | | | | |
| December 31, 2012 | $ | — |
| | $ | 2 |
| | $ | 2 |
| | $ | 34 |
| | $ | 88 |
| | $ | 76 |
| | $ | 34 |
| | $ | 87 |
| | $ | 76 |
|
| December 31, 2013 | $ | — |
| | $ | 2 |
| | $ | 2 |
| | $ | 36 |
| | $ | 54 |
| | $ | 43 |
| | $ | 36 |
| | $ | 55 |
| | $ | 42 |
|
| Average for the period ended December 31, 2013 | $ | — |
| | $ | 1 |
| | $ | 1 |
| | $ | 34 |
| | $ | 42 |
| | $ | 34 |
| | $ | 34 |
| | $ | 42 |
| | $ | 34 |
|
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 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, 2015 | $ | — |
| | $ | 3 |
| | $ | 3 |
| | $ | 51 |
| | $ | 44 |
| | $ | 23 |
| | $ | 51 |
| | $ | 46 |
| | $ | 25 |
|
| December 31, 2016 | $ | — |
| | $ | 4 |
| | $ | 4 |
| | $ | 46 |
| | $ | 62 |
| | $ | 23 |
| | $ | 46 |
| | $ | 57 |
| | $ | 23 |
|
| Average for the year ended December 31, 2016 | $ | — |
| | $ | 2 |
| | $ | 2 |
| | $ | 26 |
| | $ | 31 |
| | $ | 25 |
| | $ | 26 |
| | $ | 31 |
| | $ | 25 |
|
______________________
| |
| (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
NEENEE's and FPLFPL's financial results are exposed to risk resulting from changes in interest rates as a result of their respective outstanding and expected future issuances of debt, investments in special use funds and other investments. NEE and FPL manage their respective interest rate exposure by monitoring current interest rates, entering into interest rate contracts and using a combination of fixed rate and variable rate debt. Interest rate contracts are used to mitigate and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.
The following are estimates of the fair value of NEE's and FPL's financial instruments that are exposed to interest rate risk:
| | | | December 31, 2013 | | December 31, 2012 | | December 31, 2016 | | December 31, 2015 | |
| | Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value | |
| | (millions) | | (millions) | |
| NEE: | | | | | | | | | | | | | | | | |
| Fixed income securities: | | | | | | | | | | | | | | | | |
| Special use funds | $ | 2,195 |
| | $ | 2,195 |
| (a) | $ | 1,979 |
| | $ | 1,979 |
| (a) | $ | 1,809 |
| | $ | 1,809 |
| (a) | $ | 1,789 |
| | $ | 1,789 |
| (a) |
| Other investments: | |
| | | | |
| | |
| | |
| | | | |
| | |
| |
| Debt securities | $ | 113 |
| | $ | 113 |
| (a) | $ | 111 |
| | $ | 111 |
| (a) | $ | 123 |
| | $ | 123 |
| (a) | $ | 124 |
| | $ | 124 |
| (a) |
| Primarily notes receivable | $ | 531 |
| | $ | 627 |
| (b) | $ | 590 |
| | $ | 774 |
| (b) | $ | 526 |
| | $ | 668 |
| (b) | $ | 512 |
| | $ | 722 |
| (b) |
| Long-term debt, including current maturities | $ | 27,728 |
| | $ | 28,612 |
| (c) | $ | 26,647 |
| (d) | $ | 28,874 |
| (c) | $ | 30,418 |
| | $ | 31,623 |
| (c) | $ | 28,897 |
| | $ | 30,412 |
| (c) |
| Interest rate contracts - net unrealized losses | $ | (130 | ) | | $ | (130 | ) | (e) | $ | (311 | ) | | $ | (311 | ) | (e) | |
| Interest rate contracts - net unrealized gains (losses) | | $ | 4 |
| | $ | 4 |
| (d) | $ | (285 | ) | | $ | (285 | ) | (d) |
| FPL: | | | | | | | | | | | | | | | | |
| Fixed income securities - special use funds | $ | 1,735 |
| | $ | 1,735 |
| (a) | $ | 1,526 |
| | $ | 1,526 |
| (a) | $ | 1,363 |
| | $ | 1,363 |
| (a) | $ | 1,378 |
| | $ | 1,378 |
| (a) |
| Long-term debt, including current maturities | $ | 8,829 |
| | $ | 9,451 |
| (c) | $ | 8,782 |
| | $ | 10,421 |
| (c) | $ | 10,072 |
| | $ | 11,211 |
| (c) | $ | 10,020 |
| | $ | 11,028 |
| (c) |
| |
| (a) | Primarily estimated using a market approach based on quoted market prices for these or similar issues. |
| |
| (b) | Primarily estimated using an income approach utilizing 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 a market approach based on quoted market prices for the same or similar issues or an income approach utilizing a discounted cash flow valuation technique, considering the current credit spreadprofile of the debtor. |
| |
| (d) | Also includes long-term debt reflected in liabilities associated with assets held for sale on the consolidated balance sheets, for which carrying amount approximates fair value. |
| |
(e) | Modeled internally using an income approach utilizing a 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. See Note 1 - Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve. 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 December 31, 2013,2016, NEE had interest rate contracts with a notional amount of approximately $6.5$15.1 billion related to long-termoutstanding and expected future debt issuances and borrowings, of which $1.8$13.5 billion are fair value hedges at NEECH that effectively convert fixed-rate debt to a variable-rate instrument. The remaining $4.7 billion of notional amount of interest rate contracts relate to cash flow hedges to managemanages exposure to the variability of cash flows associated with outstanding and expected future debt issuances at NEECH and NEER. The remaining $1.6 billion of notional amount of interest rate contracts effectively convert fixed-rate debt to variable-rate debt instruments all of which relate to NEER debt issuances. At December 31, 2013, the estimated fair value of NEE's fair value hedges and cash flow hedges was approximately $10 million and $(140) million, respectively.at NEECH. See Note 3.
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 $985$1,515 million ($488459 million for FPL) at December 31, 2013.2016.
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 $2,585$2,913 million and $2,211$2,674 million ($1,5381,745 million and $1,392$1,598 million for FPL) at December 31, 20132016 and 2012,2015, respectively. At December 31, 2013,2016, a hypothetical 10% decrease in the prices quoted by stock exchanges, which is a reasonable near-term market change, would result in a $241$272 million ($141162 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.
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’sinclude 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 December 31, 2013,2016, approximately 97%94% of NEE’s and 100% of FPL’sFPL's energy marketing and trading counterparty credit risk exposure is associated with companies that have investment grade credit ratings.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
See Management’s Discussion – Energy Marketing and Trading and Market Risk Sensitivity.
Item 8. Financial Statements and Supplementary Data
MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
NextEra Energy, Inc.'s (NEE) and Florida Power & Light Company's (FPL) management are responsible for establishing and maintaining adequate internal control over financial reporting as defined in the Securities Exchange Act of 1934 Rules 13a-15(f) and 15d-15(f). The consolidated financial statements, which in part are based on informed judgments and estimates made by management, have been prepared in conformity with generally accepted accounting principles applied on a consistent basis.
To aid in carrying out this responsibility, we, along with all other members of management, maintain a system of internal accounting control which is established after weighing the cost of such controls against the benefits derived. In the opinion of management, the overall system of internal accounting control provides reasonable assurance that the assets of NEE and FPL and their subsidiaries are safeguarded and that transactions are executed in accordance with management's authorization and are properly recorded for the preparation of financial statements. In addition, management believes the overall system of internal accounting control provides reasonable assurance that material errors or irregularities would be prevented or detected on a timely basis by employees in the normal course of their duties. Any system of internal accounting control, no matter how well designed, has inherent limitations, including the possibility that controls can be circumvented or overridden and misstatements due to error or fraud may occur and not be detected. Also, because of changes in conditions, internal control effectiveness may vary over time. Accordingly, even an effective system of internal control will provide only reasonable assurance with respect to financial statement preparation and reporting.
The system of internal accounting control is supported by written policies and guidelines, the selection and training of qualified employees, an organizational structure that provides an appropriate division of responsibility and a program of internal auditing. NEE's written policies include a Code of Business Conduct & Ethics that states management's policy on conflicts of interest and ethical conduct. Compliance with the Code of Business Conduct & Ethics is confirmed annually by key personnel.
The Board of Directors pursues its oversight responsibility for financial reporting and accounting through its Audit Committee. This Committee, which is comprised entirely of independent directors, meets regularly with management, the internal auditors and the independent auditors to make inquiries as to the manner in which the responsibilities of each are being discharged. The independent auditors and the internal audit staff have free access to the Committee without management's presence to discuss auditing, internal accounting control and financial reporting matters.
Management assessed the effectiveness of NEE's and FPL's internal control over financial reporting as of December 31, 2013,2016, using the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in the Internal Control - Integrated Framework (1992)(2013). Based on this assessment, management believes that NEE's and FPL's internal control over financial reporting was effective as of December 31, 2013.2016.
NEE's and FPL's independent registered public accounting firm, Deloitte & Touche LLP, is engaged to express an opinion on NEE's and FPL's consolidated financial statements and an opinion on NEE's and FPL's internal control over financial reporting. Their reports are based on procedures believed by them to provide a reasonable basis to support such opinions. These reports appear on the following pages.
|
| | |
| JAMES L. ROBO | | MORAY P. DEWHURSTJOHN W. KETCHUM |
James L. Robo Chairman, President and Chief Executive Officer of NEE and Chairman and Chief Executive Officer of FPL | | Moray P. Dewhurst
Vice Chairman and Chief Financial Officer,
and Executive Vice President - Finance of NEE andJohn W. Ketchum
Executive Vice President, Finance and Chief Financial Officer of NEE and FPL |
|
| | |
CHRIS N. FROGGATTTERRELL KIRK CREWS, II | | KIMBERLY OUSDAHL |
Chris N. FroggattTerrell Kirk Crews, II
Vice President, Controller and Chief Accounting Officer
of NEE | | |
|
| | |
| ERIC E. SILAGY | | KIMBERLY OUSDAHL |
Eric E. Silagy President and Chief Executive Officer of FPL | | Kimberly Ousdahl
Vice President Controller and Chief Accounting Officer of FPL |
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders
NextEra Energy, Inc. and Florida Power & Light Company:Company
We have audited the internal control over financial reporting of NextEra Energy, Inc. and subsidiaries (NextEra Energy) and Florida Power & Light Company and subsidiaries (FPL) as of December 31, 20132016, based on criteria established in Internal Control — Integrated Framework (1992)(2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. NextEra Energy's and FPL’s management are responsible for maintaining effective internal control over financial reporting and for their assessments of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on NextEra Energy’s and FPL’s internal control over financial reporting based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audits included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinion.
A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
In our opinion, NextEra Energy and FPL maintained, in all material respects, effective internal control over financial reporting as of December 31, 20132016, based on the criteria established in Internal Control — Integrated Framework (1992)(2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 20132016 of NextEra Energy and FPL and our report dated February 21, 201423, 2017 expressed an unqualified opinion on those financial statements.
DELOITTE & TOUCHE LLP
Certified Public Accountants
Miami,Boca Raton, Florida
February 21, 201423, 2017
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders
NextEra Energy, Inc. and Florida Power & Light Company:Company
We have audited the accompanying consolidated balance sheets of NextEra Energy, Inc. and subsidiaries (NextEra Energy) and the separate consolidated balance sheets of Florida Power & Light Company and subsidiaries (FPL) as of December 31, 20132016 and 20122015, and NextEra Energy's and FPL's related consolidated statements of income, NextEra Energy's consolidated statements of comprehensive income, NextEra Energy's and FPL's consolidated statements of cash flows, NextEra Energy’s consolidated statements of common shareholders' equity, and FPL’s consolidated statements of common shareholder’s equity for each of the three years in the period ended December 31, 20132016. These financial statements are the responsibility of NextEra Energy's and FPL's management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all material respects, the consolidated financial position of NextEra Energy, Inc. and subsidiaries and the consolidated financial position of Florida Power & Light Company and subsidiaries at December 31, 20132016 and 20122015, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 20132016, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), NextEra Energy’s and FPL’s internal control over financial reporting as of December 31, 2013,2016, based on the criteria established in Internal Control —– Integrated Framework (1992)(2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 21, 201423, 2017 expressed an unqualified opinion on NextEra Energy’s and FPL’s internal control over financial reporting.
DELOITTE & TOUCHE LLP
Certified Public Accountants
Miami,Boca Raton, Florida
February 21, 201423, 2017
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF INCOME
(millions, except per share amounts)
| | | | Years Ended December 31, | | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | | 2016 | | 2015 | | 2014 |
| OPERATING REVENUES | $ | 15,136 |
| | $ | 14,256 |
| | $ | 15,341 |
| | $ | 16,155 |
| | $ | 17,486 |
| | $ | 17,021 |
|
| OPERATING EXPENSES | |
| | |
| | |
| |
| OPERATING EXPENSES (INCOME) | | | |
| | |
| | |
|
| Fuel, purchased power and interchange | 4,958 |
| | 5,121 |
| | 6,256 |
| | 4,042 |
| | 5,327 |
| | 5,602 |
|
| Other operations and maintenance | 3,194 |
| | 3,155 |
| | 3,002 |
| | 3,389 |
| | 3,269 |
| | 3,149 |
|
| Impairment charges | 300 |
| | — |
| | 51 |
| |
| Merger-related | | | 135 |
| | 26 |
| | — |
|
| Depreciation and amortization | 2,163 |
| | 1,518 |
| | 1,567 |
| | 3,077 |
| | 2,831 |
| | 2,551 |
|
| Taxes other than income taxes and other | 1,280 |
| | 1,186 |
| | 1,204 |
| |
| Total operating expenses | 11,895 |
| | 10,980 |
| | 12,080 |
| |
| Losses (gains) on disposal of assets - net | | | (446 | ) | | 4 |
| | (27 | ) |
| Taxes other than income taxes and other - net | | | 1,350 |
| | 1,397 |
| | 1,362 |
|
| Total operating expenses - net | | | 11,547 |
| | 12,854 |
| | 12,637 |
|
| OPERATING INCOME | 3,241 |
| | 3,276 |
| | 3,261 |
| | 4,608 |
| | 4,632 |
| | 4,384 |
|
| OTHER INCOME (DEDUCTIONS) | |
| | |
| | |
| | |
| | |
| | |
|
| Interest expense | (1,121 | ) | | (1,038 | ) | | (1,035 | ) | | (1,093 | ) | | (1,211 | ) | | (1,261 | ) |
| Benefits associated with differential membership interests - net | 165 |
| | 81 |
| | 118 |
| | 309 |
| | 216 |
| | 199 |
|
| Loss on sale of natural gas-fired generating assets | — |
| | — |
| | (151 | ) | |
| Equity in earnings of equity method investees | 25 |
| | 13 |
| | 55 |
| | 148 |
| | 107 |
| | 93 |
|
| Allowance for equity funds used during construction | 63 |
| | 67 |
| | 39 |
| | 86 |
| | 70 |
| | 37 |
|
| Interest income | 78 |
| | 86 |
| | 79 |
| | 82 |
| | 86 |
| | 80 |
|
| Gains on disposal of assets - net | 54 |
| | 157 |
| | 85 |
| |
| Gains on disposal of investments and other property - net | | | 40 |
| | 90 |
| | 105 |
|
| Gain associated with Maine fossil | | | — |
| | — |
| | 21 |
|
| Other than temporary impairment losses on securities held in nuclear decommissioning funds | (11 | ) | | (16 | ) | | (36 | ) | | (23 | ) | | (40 | ) | | (13 | ) |
| Revaluation of contingent consideration | | | 189 |
| | — |
| | — |
|
| Other - net | 27 |
| | (23 | ) | | 37 |
| | 42 |
| | 40 |
| | — |
|
| Total other deductions - net | (720 | ) | | (673 | ) | | (809 | ) | | (220 | ) | | (642 | ) | | (739 | ) |
| INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES | 2,521 |
| | 2,603 |
| | 2,452 |
| |
| INCOME BEFORE INCOME TAXES | | | 4,388 |
| | 3,990 |
| | 3,645 |
|
| INCOME TAXES | 801 |
| | 692 |
| | 529 |
| | 1,383 |
| | 1,228 |
| | 1,176 |
|
| INCOME FROM CONTINUING OPERATIONS | 1,720 |
| | 1,911 |
| | 1,923 |
| |
| NET GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES | 188 |
| | — |
| | — |
| |
| NET INCOME | $ | 1,908 |
| | $ | 1,911 |
| | $ | 1,923 |
| | 3,005 |
| | 2,762 |
| | 2,469 |
|
| | | | | | | |
| Basic earnings per share of common stock: | |
| | |
| | |
| |
| Continuing operations | $ | 4.06 |
| | $ | 4.59 |
| | $ | 4.62 |
| |
| Discontinued operations | 0.44 |
| | — |
| | — |
| |
| Net income | $ | 4.50 |
| | $ | 4.59 |
| | $ | 4.62 |
| |
| Earnings per share of common stock - assuming dilution: | | | | | | |
| Continuing operations | $ | 4.03 |
| | $ | 4.56 |
| | $ | 4.59 |
| |
| Discontinued operations | 0.44 |
| | — |
| | — |
| |
| Net income | $ | 4.47 |
| | $ | 4.56 |
| | $ | 4.59 |
| |
| LESS NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS | | | 93 |
|
| 10 |
|
| 4 |
|
| NET INCOME ATTRIBUTABLE TO NEE | | | $ | 2,912 |
| | $ | 2,752 |
| | $ | 2,465 |
|
| Earnings per share attributable to NEE: | | | |
| | |
| | |
|
| Basic | | | $ | 6.29 |
| | $ | 6.11 |
| | $ | 5.67 |
|
| Assuming dilution | | | $ | 6.25 |
| | $ | 6.06 |
| | $ | 5.60 |
|
| Weighted-average number of common shares outstanding: | |
| | |
| | |
| | |
| | |
| | |
|
| Basic | 424.2 |
| | 416.7 |
| | 416.6 |
| | 463.1 |
| | 450.5 |
| | 434.4 |
|
| Assuming dilution | 427.0 |
| | 419.2 |
| | 419.0 |
| | 465.8 |
| | 454.0 |
| | 440.1 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(millions)
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 |
| NET INCOME | $ | 1,908 |
| | $ | 1,911 |
| | $ | 1,923 |
|
| | | | | | |
| OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX | | | | | |
| Net unrealized gains (losses) on cash flow hedges: | |
| | | | |
| Effective portion of net unrealized gains (losses) (net of $45 tax expense, $55 tax benefit and $135 tax benefit, respectively) | 84 |
| | (106 | ) | | (265 | ) |
| Reclassification from accumulated other comprehensive income to net income (net of $38, $25 and $18 tax expense, respectively) | 67 |
| | 44 |
| | 37 |
|
| Net unrealized gains (losses) on available for sale securities: | | | | | |
| Net unrealized gains on securities still held (net of $84, $48 and $13 tax expense, respectively) | 118 |
| | 70 |
| | 19 |
|
| Reclassification from accumulated other comprehensive income to net income (net of $10, $52 and $34 tax benefit, respectively) | (17 | ) | | (77 | ) | | (49 | ) |
| Defined benefit pension and other benefits plans (net of $61 tax expense, $19 tax benefit and $32 tax benefit, respectively) | 97 |
| | (28 | ) | | (45 | ) |
| Net unrealized gains (losses) on foreign currency translation (net of $22 tax benefit, $3 tax expense and $3 tax benefit, respectively) | (45 | ) | | 7 |
| | (5 | ) |
| Other comprehensive income (loss) related to equity method investee (net of $5 tax expense, $7 tax benefit and $8 tax benefit, respectively) | 7 |
| | (11 | ) | | (12 | ) |
| Total other comprehensive income (loss), net of tax | 311 |
| | (101 | ) | | (320 | ) |
| | | | | | |
| COMPREHENSIVE INCOME | $ | 2,219 |
| | $ | 1,810 |
| | $ | 1,603 |
|
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 |
| NET INCOME | $ | 3,005 |
| | $ | 2,762 |
| | $ | 2,469 |
|
| OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX | | | | | |
| Net unrealized gains (losses) on cash flow hedges: | |
| | | | |
| Effective portion of net unrealized losses (net of $37 and $80 tax benefit, respectively) | — |
| | (88 | ) | | (141 | ) |
| Reclassification from accumulated other comprehensive income to net income (net of $32, $25 and $57 tax expense, respectively) | 70 |
| | 63 |
| | 98 |
|
| Net unrealized gains (losses) on available for sale securities: | | | | | |
| Net unrealized gains (losses) on securities still held (net of $50 tax expense, $8 tax benefit and $45 tax expense, respectively) | 69 |
| | (7 | ) | | 62 |
|
| Reclassification from accumulated other comprehensive income to net income (net of $13, $33 and $26 tax benefit, respectively) | (18 | ) | | (37 | ) | | (41 | ) |
| Defined benefit pension and other benefits plans (net of $13, $26 and $27 tax benefit, respectively) | (21 | ) | | (42 | ) | | (43 | ) |
| Net unrealized losses on foreign currency translation (net of $2, $2 and $12 tax benefit, respectively) | (5 | ) | | (27 | ) | | (25 | ) |
| Other comprehensive income (loss) related to equity method investee (net of $2 tax expense and $5 tax benefit, respectively) | 2 |
| | — |
| | (8 | ) |
| Total other comprehensive income (loss), net of tax | 97 |
| | (138 | ) | | (98 | ) |
| COMPREHENSIVE INCOME | 3,102 |
| | 2,624 |
| | 2,371 |
|
| LESS COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO NONCONTROLLING INTERESTS | 93 |
| | (1 | ) | | 2 |
|
| COMPREHENSIVE INCOME ATTRIBUTABLE TO NEE | $ | 3,009 |
| | $ | 2,625 |
| | $ | 2,369 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
NEXTERA ENERGY, INC.
CONSOLIDATED BALANCE SHEETS
(millions, except par value)
|
| | | | | | | |
| | December 31, |
| | 2013 | | 2012 |
| PROPERTY, PLANT AND EQUIPMENT | | | |
| Electric plant in service and other property | $ | 62,699 |
| | $ | 57,054 |
|
| Nuclear fuel | 2,059 |
| | 1,895 |
|
| Construction work in progress | 4,690 |
| | 5,968 |
|
| Less accumulated depreciation and amortization | (16,728 | ) | | (15,504 | ) |
| Total property, plant and equipment - net ($5,127 and $4,487 related to VIEs, respectively) | 52,720 |
| | 49,413 |
|
| CURRENT ASSETS | |
| | |
|
| Cash and cash equivalents | 438 |
| | 329 |
|
| Customer receivables, net of allowances of $14 and $10, respectively | 1,777 |
| | 1,487 |
|
| Other receivables | 512 |
| | 569 |
|
| Materials, supplies and fossil fuel inventory | 1,153 |
| | 1,073 |
|
| Regulatory assets: | |
| | |
|
| Deferred clause and franchise expenses | 192 |
| | 75 |
|
| Other | 116 |
| | 113 |
|
| Derivatives | 498 |
| | 517 |
|
| Deferred income taxes | 753 |
| | 397 |
|
| Assets held for sale | — |
| | 335 |
|
| Other | 403 |
| | 342 |
|
| Total current assets | 5,842 |
| | 5,237 |
|
| OTHER ASSETS | |
| | |
|
| Special use funds | 4,780 |
| | 4,190 |
|
| Other investments | 1,121 |
| | 976 |
|
| Prepaid benefit costs | 1,456 |
| | 1,031 |
|
| Regulatory assets: | |
| | |
|
| Securitized storm-recovery costs ($228 and $274 related to a VIE, respectively) | 372 |
| | 461 |
|
| Other | 426 |
| | 582 |
|
| Derivatives | 1,163 |
| | 920 |
|
| Other | 1,426 |
| | 1,629 |
|
| Total other assets | 10,744 |
| | 9,789 |
|
| TOTAL ASSETS | $ | 69,306 |
| | $ | 64,439 |
|
| CAPITALIZATION | |
| | |
|
| Common stock ($0.01 par value, authorized shares - 800; outstanding shares - 435 and 424, respectively) | $ | 4 |
| | $ | 4 |
|
| Additional paid-in capital | 6,411 |
| | 5,536 |
|
| Retained earnings | 11,569 |
| | 10,783 |
|
| Accumulated other comprehensive income (loss) | 56 |
| | (255 | ) |
| Total common shareholders' equity | 18,040 |
| | 16,068 |
|
| Long-term debt ($1,207 and $1,369 related to VIEs, respectively) | 23,969 |
| | 23,177 |
|
| Total capitalization | 42,009 |
| | 39,245 |
|
| CURRENT LIABILITIES | |
| | |
|
| Commercial paper | 691 |
| | 1,211 |
|
| Short-term debt | — |
| | 200 |
|
| Current maturities of long-term debt | 3,766 |
| | 2,771 |
|
| Accounts payable | 1,200 |
| | 1,281 |
|
| Customer deposits | 452 |
| | 508 |
|
| Accrued interest and taxes | 473 |
| | 414 |
|
| Derivatives | 838 |
| | 430 |
|
| Accrued construction-related expenditures | 839 |
| | 427 |
|
| Liabilities associated with assets held for sale | — |
| | 733 |
|
| Other | 930 |
| | 904 |
|
| Total current liabilities | 9,189 |
| | 8,879 |
|
| OTHER LIABILITIES AND DEFERRED CREDITS | |
| | |
|
| Asset retirement obligations | 1,850 |
| | 1,715 |
|
| Deferred income taxes | 8,144 |
| | 6,703 |
|
| Regulatory liabilities: | |
| | |
|
| Accrued asset removal costs | 1,839 |
| | 1,950 |
|
| Asset retirement obligation regulatory expense difference | 2,082 |
| | 1,813 |
|
| Other | 462 |
| | 309 |
|
| Derivatives | 473 |
| | 587 |
|
| Deferral related to differential membership interests - VIEs | 2,001 |
| | 1,784 |
|
| Other | 1,257 |
| | 1,454 |
|
| Total other liabilities and deferred credits | 18,108 |
| | 16,315 |
|
| COMMITMENTS AND CONTINGENCIES |
|
| |
|
|
| TOTAL CAPITALIZATION AND LIABILITIES | $ | 69,306 |
| | $ | 64,439 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(millions)
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 |
| CASH FLOWS FROM OPERATING ACTIVITIES | | | | | |
| Net income | $ | 1,908 |
| | $ | 1,911 |
| | $ | 1,923 |
|
| Adjustments to reconcile net income to net cash provided by (used in) operating activities: | | | | | |
| Depreciation and amortization | 2,163 |
| | 1,518 |
| | 1,567 |
|
| Nuclear fuel and other amortization | 358 |
| | 259 |
| | 282 |
|
| Loss on sale of natural gas-fired generating assets | — |
| | — |
| | 151 |
|
| Impairment charges | 300 |
| | — |
| | 51 |
|
| Unrealized gains on marked to market energy contracts | (10 | ) | | (85 | ) | | (271 | ) |
| Deferred income taxes | 877 |
| | 682 |
| | 553 |
|
| Cost recovery clauses and franchise fees | (166 | ) | | 129 |
| | 181 |
|
| Benefits associated with differential membership interests - net | (165 | ) | | (81 | ) | | (118 | ) |
| Equity in earnings of equity method investees | (25 | ) | | (13 | ) | | (55 | ) |
| Distributions of earnings from equity method investees | 33 |
| | 32 |
| | 95 |
|
| Allowance for equity funds used during construction | (63 | ) | | (67 | ) | | (39 | ) |
| Gains on disposal of assets - net | (54 | ) | | (157 | ) | | (85 | ) |
| Other than temporary impairment losses on securities held in nuclear decommissioning funds | 11 |
| | 16 |
| | 36 |
|
| Net gain from discontinued operations, net of income taxes | (188 | ) | | — |
| | — |
|
| Other - net | 175 |
| | 38 |
| | 305 |
|
| Changes in operating assets and liabilities: | |
| | |
| | |
| Customer and other receivables | (268 | ) | | (286 | ) | | 149 |
|
| Materials, supplies and fossil fuel inventory | (81 | ) | | 1 |
| | (308 | ) |
| Other current assets | 8 |
| | (46 | ) | | (22 | ) |
| Other assets | 8 |
| | 3 |
| | (103 | ) |
| Accounts payable and customer deposits | 122 |
| | (56 | ) | | (184 | ) |
| Margin cash collateral | 156 |
| | 104 |
| | 81 |
|
| Income taxes | (56 | ) | | (20 | ) | | 62 |
|
| Interest and other taxes | 3 |
| | 15 |
| | 12 |
|
| Other current liabilities | 140 |
| | 139 |
| | 3 |
|
| Other liabilities | (84 | ) | | (44 | ) | | (192 | ) |
| Net cash provided by operating activities | 5,102 |
| | 3,992 |
| | 4,074 |
|
| CASH FLOWS FROM INVESTING ACTIVITIES | |
| | |
| | |
|
| Capital expenditures of FPL | (2,691 | ) | | (4,070 | ) | | (3,137 | ) |
| Independent power and other investments of NEER | (3,454 | ) | | (4,591 | ) | | (2,601 | ) |
| Cash grants under the American Recovery and Reinvestment Act of 2009 | 165 |
| | 196 |
| | 624 |
|
| Nuclear fuel purchases | (371 | ) | | (305 | ) | | (538 | ) |
| Other capital expenditures and other investments | (166 | ) | | (495 | ) | | (352 | ) |
| Sale of independent power investments | 165 |
| | — |
| | 1,204 |
|
| Change in loan proceeds restricted for construction | 228 |
| | 314 |
| | (565 | ) |
| Proceeds from sale or maturity of securities in special use funds and other investments | 4,405 |
| | 5,301 |
| | 4,836 |
|
| Purchases of securities in special use funds and other investments | (4,470 | ) | | (5,419 | ) | | (4,955 | ) |
| Other - net | 66 |
| | 141 |
| | 205 |
|
| Net cash used in investing activities | (6,123 | ) | | (8,928 | ) | | (5,279 | ) |
| CASH FLOWS FROM FINANCING ACTIVITIES | |
| | |
| | |
|
| Issuances of long-term debt | 4,371 |
| | 6,630 |
| | 3,940 |
|
| Retirements of long-term debt | (2,396 | ) | | (1,612 | ) | | (2,121 | ) |
| Proceeds from sale of differential membership interests | 448 |
| | 808 |
| | 466 |
|
| Payments to differential membership investors | (63 | ) | | (139 | ) | | (100 | ) |
| Net change in short-term debt | (720 | ) | | 61 |
| | 460 |
|
| Issuances of common stock - net | 842 |
| | 405 |
| | 48 |
|
| Repurchases of common stock | — |
| | (19 | ) | | (375 | ) |
| Dividends on common stock | (1,122 | ) | | (1,004 | ) | | (920 | ) |
| Other - net | (230 | ) | | (242 | ) | | (118 | ) |
| Net cash provided by financing activities | 1,130 |
| | 4,888 |
| | 1,280 |
|
| Net increase (decrease) in cash and cash equivalents | 109 |
| | (48 | ) | | 75 |
|
| Cash and cash equivalents at beginning of year | 329 |
| | 377 |
| | 302 |
|
| Cash and cash equivalents at end of year | $ | 438 |
| | $ | 329 |
| | $ | 377 |
|
| SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION | |
| | |
| | |
|
| Cash paid for interest (net of amount capitalized) | $ | 1,070 |
| | $ | 1,001 |
| | $ | 978 |
|
| Cash paid (received) for income taxes - net | $ | (20 | ) | | $ | 25 |
| | $ | (95 | ) |
| SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES | |
| | |
| | |
|
| Accrued property additions | $ | 1,098 |
| | $ | 970 |
| | $ | 909 |
|
| Sale of generating assets through assumption of debt by buyer | $ | 700 |
| | $ | — |
| | $ | 158 |
|
|
| | | | | | | | |
| | | December 31, |
| | | 2016 | | 2015 |
| PROPERTY, PLANT AND EQUIPMENT | | | | |
| Electric plant in service and other property | | $ | 80,150 |
| | $ | 72,606 |
|
| Nuclear fuel | | 2,131 |
| | 2,067 |
|
| Construction work in progress | | 4,732 |
| | 5,657 |
|
| Accumulated depreciation and amortization | | (20,101 | ) | | (18,944 | ) |
| Total property, plant and equipment - net ($14,632 and $7,966 related to VIEs, respectively) | | 66,912 |
| | 61,386 |
|
| CURRENT ASSETS | | |
| | |
|
| Cash and cash equivalents | | 1,292 |
| | 571 |
|
| Customer receivables, net of allowances of $5 and $13, respectively | | 1,784 |
| | 1,784 |
|
| Other receivables | | 655 |
| | 481 |
|
| Materials, supplies and fossil fuel inventory | | 1,289 |
| | 1,259 |
|
| Regulatory assets | | 524 |
| | 503 |
|
| Derivatives | | 885 |
| | 712 |
|
| Assets held for sale | | 452 |
| | 1,009 |
|
| Other | | 528 |
| | 476 |
|
| Total current assets | | 7,409 |
| | 6,795 |
|
| OTHER ASSETS | | |
| | |
|
| Special use funds | | 5,434 |
| | 5,138 |
|
| Other investments ($479 related to a VIE at December 31, 2016) | | 2,482 |
| | 1,786 |
|
| Prepaid benefit costs | | 1,177 |
| | 1,155 |
|
| Regulatory assets ($107 and $128 related to a VIE, respectively) | | 1,894 |
| | 1,778 |
|
| Derivatives | | 1,350 |
| | 1,202 |
|
| Other | | 3,335 |
| | 3,239 |
|
| Total other assets | | 15,672 |
| | 14,298 |
|
| TOTAL ASSETS | | $ | 89,993 |
| | $ | 82,479 |
|
| CAPITALIZATION | | |
| | |
|
| Common stock ($0.01 par value, authorized shares - 800; outstanding shares - 468 and 461, respectively) | | $ | 5 |
| | $ | 5 |
|
| Additional paid-in capital | | 8,948 |
| | 8,596 |
|
| Retained earnings | | 15,458 |
| | 14,140 |
|
| Accumulated other comprehensive loss | | (70 | ) | | (167 | ) |
| Total common shareholders' equity | | 24,341 |
| | 22,574 |
|
| Noncontrolling interests | | 990 |
| | 538 |
|
| Total equity | | 25,331 |
| | 23,112 |
|
| Long-term debt ($5,080 and $684 related to VIEs, respectively) | | 27,818 |
| | 26,681 |
|
| Total capitalization | | 53,149 |
| | 49,793 |
|
| CURRENT LIABILITIES | | |
| | |
|
| Commercial paper | | 268 |
| | 374 |
|
| Other short-term debt | | 150 |
| | 412 |
|
| Current maturities of long-term debt | | 2,604 |
| | 2,220 |
|
| Accounts payable | | 3,447 |
| | 2,529 |
|
| Customer deposits | | 470 |
| | 473 |
|
| Accrued interest and taxes | | 480 |
| | 449 |
|
| Derivatives | | 404 |
| | 882 |
|
| Accrued construction-related expenditures | | 1,120 |
| | 921 |
|
| Regulatory liabilities | | 299 |
| | 14 |
|
| Liabilities associated with assets held for sale | | 451 |
| | 992 |
|
| Other | | 1,226 |
| | 841 |
|
| Total current liabilities | | 10,919 |
| | 10,107 |
|
| OTHER LIABILITIES AND DEFERRED CREDITS | | | | |
| Asset retirement obligations | | 2,736 |
| | 2,469 |
|
| Deferred income taxes | | 11,101 |
| | 9,827 |
|
| Regulatory liabilities | | 4,906 |
| | 4,606 |
|
| Derivatives | | 477 |
| | 530 |
|
| Deferral related to differential membership interests - VIEs | | 4,656 |
| | 3,142 |
|
| Other | | 2,049 |
| | 2,005 |
|
| Total other liabilities and deferred credits | | 25,925 |
| | 22,579 |
|
| COMMITMENTS AND CONTINGENCIES | |
|
| |
|
|
| TOTAL CAPITALIZATION AND LIABILITIES | | $ | 89,993 |
| | $ | 82,479 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITYCASH FLOWS
(millions)
|
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Common Stock | | Additional Paid-In Capital | | Unearned ESOP Compensation | | Accumulated Other Comprehensive Income (Loss) | | Retained Earnings | | Common Shareholders' Equity |
| | Shares | | Aggregate Par Value | |
| Balances, December 31, 2010 | 421 |
| | $ | 4 |
| | $ | 5,487 |
| | $ | (69 | ) | | $ | 166 |
| | $ | 8,873 |
| | $ | 14,461 |
|
| Net income | — |
| | — |
| | — |
| | — |
| | — |
| | 1,923 |
| | |
| Issuances of common stock, net of issuance cost of less than $1 | 1 |
| | — |
| | 59 |
| | 5 |
| | — |
| | — |
| | |
| Repurchases of common stock | (7 | ) | | — |
| | (375 | ) | | — |
| | — |
| | — |
| | |
| Exercise of stock options and other incentive plan activity | 1 |
| | — |
| | 68 |
| | — |
| | — |
| | — |
| | |
Dividends on common stock(b) | — |
| | — |
| | — |
| | — |
| | — |
| | (920 | ) | | |
| Earned compensation under ESOP | — |
| | — |
| | 31 |
| | 11 |
| | — |
| | — |
| | |
| Other comprehensive loss | — |
| | — |
| | — |
| | — |
| | (320 | ) | | — |
| | |
| Balances, December 31, 2011 | 416 |
| (a) | 4 |
| | 5,270 |
| | (53 | ) | | (154 | ) | | 9,876 |
| | $ | 14,943 |
|
| Net income | — |
| | — |
| | — |
| | — |
| | — |
| | 1,911 |
| | |
| Issuances of common stock, net of issuance cost of less than $1 | 6 |
| | — |
| | 367 |
| | 4 |
| | — |
| | — |
| | |
| Repurchases of common stock | — |
| | — |
| | (19 | ) | | — |
| | — |
| | — |
| | |
| Exercise of stock options and other incentive plan activity | 2 |
| | — |
| | 98 |
| | — |
| | — |
| | — |
| | |
Dividends on common stock(b) | — |
| | — |
| | — |
| | — |
| | — |
| | (1,004 | ) | | |
| Earned compensation under ESOP | — |
| | — |
| | 34 |
| | 10 |
| | — |
| | — |
| | |
| Other comprehensive loss | — |
| | — |
| | — |
| | — |
| | (101 | ) | | — |
| | |
| Premium on equity units | — |
| | — |
| | (151 | ) | | — |
| | — |
| | — |
| | |
| Issuance costs on equity units | — |
| | — |
| | (24 | ) | | — |
| | — |
| | — |
| | |
| Balances, December 31, 2012 | 424 |
| (a) | 4 |
| | 5,575 |
| | (39 | ) | | (255 | ) | | 10,783 |
| | $ | 16,068 |
|
| Net income | — |
| | — |
| | — |
| | — |
| | — |
| | 1,908 |
| | |
| Issuances of common stock, net of issuance cost of less than $1 | 10 |
| | — |
| | 823 |
| | 4 |
| | — |
| | — |
| | |
| Exercise of stock options and other incentive plan activity | 1 |
| | — |
| | 74 |
| | — |
| | — |
| | — |
| | |
Dividends on common stock(b) | — |
| | — |
| | — |
| | — |
| | — |
| | (1,122 | ) | | |
| Earned compensation under ESOP | — |
| | — |
| | 37 |
| | 9 |
| | — |
| | — |
| | |
| Other comprehensive income | — |
| | — |
| | — |
| | — |
| | 311 |
| | — |
| | |
| Premium on equity units | — |
| | — |
| | (62 | ) | | — |
| | — |
| | — |
| | |
| Issuance costs on equity units | — |
| | — |
| | (10 | ) | | — |
| | — |
| | — |
| | |
| Balances, December 31, 2013 | 435 |
| (a) | $ | 4 |
| | $ | 6,437 |
| | $ | (26 | ) | | $ | 56 |
| | $ | 11,569 |
| | $ | 18,040 |
|
|
| | | | | | | | | | | |
| | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 |
| CASH FLOWS FROM OPERATING ACTIVITIES | | | | | |
| Net income | $ | 3,005 |
| | $ | 2,762 |
| | $ | 2,469 |
|
| Adjustments to reconcile net income to net cash provided by (used in) operating activities: | | | | | |
| Depreciation and amortization | 3,077 |
| | 2,831 |
| | 2,551 |
|
| Nuclear fuel and other amortization | 300 |
| | 372 |
| | 345 |
|
| Unrealized gains on marked to market derivative contracts - net | (44 | ) | | (337 | ) | | (411 | ) |
| Foreign currency transaction losses | 13 |
| | — |
| | — |
|
| Deferred income taxes | 1,230 |
| | 1,162 |
| | 1,205 |
|
| Cost recovery clauses and franchise fees | 94 |
| | 176 |
| | (67 | ) |
| Purchased power agreement termination | — |
| | (521 | ) | | — |
|
| Benefits associated with differential membership interests - net | (309 | ) | | (216 | ) | | (199 | ) |
| Gains on disposal of assets - net | (490 | ) | | (89 | ) | | (133 | ) |
| Recoverable storm-related costs | (223 | ) | | — |
| | — |
|
| Other - net | (94 | ) | | 68 |
| | 278 |
|
| Changes in operating assets and liabilities: | |
| | |
| | |
| Current assets | (120 | ) | | 73 |
| | (172 | ) |
| Noncurrent assets | (67 | ) | | (106 | ) | | (220 | ) |
| Current liabilities | (24 | ) | | 64 |
| | (134 | ) |
| Noncurrent liabilities | (12 | ) | | (123 | ) | | (12 | ) |
| Net cash provided by operating activities | 6,336 |
| | 6,116 |
| | 5,500 |
|
| CASH FLOWS FROM INVESTING ACTIVITIES | |
| | |
| | |
|
| Capital expenditures of FPL | (3,776 | ) | | (3,428 | ) | | (3,067 | ) |
| Independent power and other investments of NEER | (5,396 | ) | | (4,505 | ) | | (3,588 | ) |
| Cash grants under the American Recovery and Reinvestment Act of 2009 | 335 |
| | 8 |
| | 343 |
|
| Nuclear fuel purchases | (283 | ) | | (361 | ) | | (287 | ) |
| Other capital expenditures and other investments | (181 | ) | | (83 | ) | | (75 | ) |
| Sale of independent power and other investments of NEER | 658 |
| | 52 |
| | 307 |
|
| Proceeds from sale or maturity of securities in special use funds and other investments | 3,776 |
| | 4,851 |
| | 4,621 |
|
| Purchases of securities in special use funds and other investments | (3,829 | ) | | (4,982 | ) | | (4,767 | ) |
| Proceeds from the sale of a noncontrolling interest in subsidiaries | 645 |
| | 345 |
| | 438 |
|
| Other - net | (59 | ) | | 98 |
| | (286 | ) |
| Net cash used in investing activities | (8,110 | ) | | (8,005 | ) | | (6,361 | ) |
| CASH FLOWS FROM FINANCING ACTIVITIES | |
| | |
| | |
|
| Issuances of long-term debt | 5,657 |
| | 5,772 |
| | 5,054 |
|
| Retirements of long-term debt | (3,310 | ) | | (3,972 | ) | | (4,750 | ) |
| Proceeds from differential membership investors | 1,859 |
| | 761 |
| | 978 |
|
| Payments to differential membership investors | (122 | ) | | (92 | ) | | (71 | ) |
| Proceeds from other short-term debt | 500 |
| | 1,225 |
| | 500 |
|
| Repayments of other short-term debt | (662 | ) | | (813 | ) | | (500 | ) |
| Net change in commercial paper | (106 | ) | | (768 | ) | | 451 |
|
| Issuances of common stock - net | 537 |
| | 1,298 |
| | 633 |
|
| Dividends on common stock | (1,612 | ) | | (1,385 | ) | | (1,261 | ) |
| Other - net | (246 | ) | | (143 | ) | | (34 | ) |
| Net cash provided by financing activities | 2,495 |
| | 1,883 |
| | 1,000 |
|
| Net increase (decrease) in cash and cash equivalents | 721 |
| | (6 | ) | | 139 |
|
| Cash and cash equivalents at beginning of year | 571 |
| | 577 |
| | 438 |
|
| Cash and cash equivalents at end of year | $ | 1,292 |
| | $ | 571 |
| | $ | 577 |
|
| SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION | |
| | |
| | |
|
| Cash paid for interest (net of amount capitalized) | $ | 1,193 |
| | $ | 1,143 |
| | $ | 1,181 |
|
| Cash paid for income taxes - net | $ | 91 |
| | $ | 33 |
| | $ | 46 |
|
| SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES | |
| | |
| | |
|
| Accrued property additions | $ | 3,626 |
| | $ | 2,616 |
| | $ | 956 |
|
| Assumption of debt/acquisition holdbacks in connection with Texas pipeline acquisition | $ | — |
| | $ | 1,078 |
| | $ | — |
|
| Decrease in property, plant and equipment - net as a result of cash grants primarily under the American Recovery and Reinvestment Act of 2009 | $ | 419 |
| | $ | 224 |
| | $ | 161 |
|
| Decrease (increase) in property, plant and equipment - net as a result of a settlement | $ | (72 | ) | | $ | (45 | ) | | $ | 181 |
|
| Proceeds from differential membership investors used to reduce debt | $ | 100 |
| | $ | — |
| | $ | — |
|
______________________
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF EQUITY
(millions)
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Common Stock | | Additional Paid-In Capital | | Unearned ESOP Compensation | | Accumulated Other Comprehensive Income (Loss) | | Retained Earnings | | Total Common Shareholders' Equity | | Non- controlling Interests | | Total Equity |
| | Shares | | Aggregate Par Value | |
| Balances, December 31, 2013 | 435 |
| | $ | 4 |
| | $ | 6,437 |
| | $ | (26 | ) | | $ | 56 |
| | $ | 11,569 |
| | $ | 18,040 |
| | $ | — |
| | $ | 18,040 |
|
| Net income | — |
|
| — |
| | — |
| | — |
| | — |
| | 2,465 |
| | 2,465 |
| | 4 |
| | |
| Issuances of common stock, net of issuance cost of less than $1 | 7 |
| | — |
| | 604 |
| | 3 |
| | — |
| | — |
| | 607 |
| | — |
| | |
| Exercise of stock options and other incentive plan activity | 1 |
| | — |
| | 102 |
| | — |
| | — |
| | — |
| | 102 |
| | — |
| | |
Dividends on common stock(a) | — |
| | — |
| | — |
| | — |
| | — |
| | (1,261 | ) | | (1,261 | ) | | — |
| | |
| Other comprehensive loss | — |
| | — |
| | — |
| | — |
| | (96 | ) | | — |
| | (96 | ) | | (2 | ) | | |
| NEP acquisition of limited partner interest in NEP OpCo | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 232 |
| | |
| Other | — |
| | — |
| | 50 |
| | 9 |
| | — |
| | — |
| | 59 |
| | 18 |
| | |
| Balances, December 31, 2014 | 443 |
| | 4 |
| | 7,193 |
| | (14 | ) | | (40 | ) | | 12,773 |
| | 19,916 |
| | 252 |
| | $ | 20,168 |
|
| Net income | — |
|
| — |
| | — |
| | — |
| | — |
| | 2,752 |
| | 2,752 |
| | 10 |
| | |
| Issuances of common stock, net of issuance cost of less than $1 | 17 |
| | 1 |
| | 1,302 |
| | 4 |
| | — |
| | — |
| | 1,307 |
| | — |
| | |
Dividends on common stock(a) | — |
| | — |
| | — |
| | — |
| | — |
| | (1,385 | ) | | (1,385 | ) | | — |
| | |
| Other comprehensive loss | — |
| | — |
| | — |
| | — |
| | (127 | ) | | — |
| | (127 | ) | | (11 | ) | | |
| Premium on equity units | — |
| | — |
| | (80 | ) | | — |
| | — |
| | — |
| | (80 | ) | | — |
| | |
| Sale of NEER assets to NEP | — |
| | — |
| | 88 |
| | — |
| | — |
| | — |
| | 88 |
| | 252 |
| | |
| Other | 1 |
| | — |
| | 94 |
| | 9 |
| | — |
| | — |
| | 103 |
| | 35 |
| | |
| Balances, December 31, 2015 | 461 |
| | 5 |
| | 8,597 |
| | (1 | ) | | (167 | ) | | 14,140 |
| | 22,574 |
| | 538 |
| | $ | 23,112 |
|
| Net income | — |
|
| — |
| | — |
| | — |
| | — |
| | 2,912 |
| | 2,912 |
| | 93 |
| | |
| Issuances of common stock, net of issuance cost of less than $1 | 6 |
| | — |
| | 527 |
| | — |
| | — |
| | — |
| | 527 |
| | — |
| | |
Dividends on common stock(a) | — |
| | — |
| | — |
| | — |
| | — |
| | (1,612 | ) | | (1,612 | ) | | — |
| | |
| Other comprehensive income | — |
| | — |
| | — |
| | — |
| | 97 |
| | — |
| | 97 |
| | — |
| | |
| Premium on equity units | — |
| | — |
| | (200 | ) | | — |
| | — |
| | — |
| | (200 | ) | | — |
| | |
| Sale of NEER assets to NEP | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 433 |
| | |
| Other | 1 |
| | — |
| | 24 |
| | 1 |
| | — |
| | 18 |
| | 43 |
| | (74 | ) | | |
| Balances, December 31, 2016 | 468 |
| | $ | 5 |
| | $ | 8,948 |
| | $ | — |
| | $ | (70 | ) | | $ | 15,458 |
| | $ | 24,341 |
| | $ | 990 |
| | $ | 25,331 |
|
___________________________
| |
| (a) | Outstanding and unallocated shares held by the Employee Stock Ownership Plan (ESOP) Trust totaled approximately 2 million, 3 million and 4 million at December 31, 2013, 2012 and 2011, respectively; the original number of shares purchased and held by the ESOP Trust was approximately 25 million shares.
|
| |
(b) | Dividends per share were $2.64, $2.40$3.48, $3.08 and $2.20$2.90 for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively. |
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(millions)
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| OPERATING REVENUES | $ | 10,445 |
| | $ | 10,114 |
| | $ | 10,613 |
| $ | 10,895 |
| | $ | 11,651 |
| | $ | 11,421 |
|
| OPERATING EXPENSES | |
| | |
| | |
| |
| OPERATING EXPENSES (INCOME) | | |
| | |
| | |
|
| Fuel, purchased power and interchange | 3,925 |
| | 4,265 |
| | 4,977 |
| 3,297 |
| | 4,276 |
| | 4,375 |
|
| Other operations and maintenance | 1,699 |
| | 1,773 |
| | 1,699 |
| 1,600 |
| | 1,617 |
| | 1,620 |
|
| Depreciation and amortization | 1,159 |
| | 659 |
| | 798 |
| 1,651 |
| | 1,576 |
| | 1,432 |
|
| Taxes other than income taxes and other | 1,123 |
| | 1,060 |
| | 1,063 |
| |
| Total operating expenses | 7,906 |
| | 7,757 |
| | 8,537 |
| |
| Taxes other than income taxes and other - net | | 1,189 |
| | 1,205 |
| | 1,166 |
|
| Total operating expenses - net | | 7,737 |
| | 8,674 |
| | 8,593 |
|
| OPERATING INCOME | 2,539 |
| | 2,357 |
| | 2,076 |
| 3,158 |
| | 2,977 |
| | 2,828 |
|
| OTHER INCOME (DEDUCTIONS) | |
| | |
| | |
| |
| | |
| | |
|
| Interest expense | (415 | ) | | (417 | ) | | (387 | ) | (456 | ) | | (445 | ) | | (439 | ) |
| Allowance for equity funds used during construction | 55 |
| | 52 |
| | 35 |
| 74 |
| | 68 |
| | 36 |
|
| Other - net | 5 |
| | — |
| | (2 | ) | 2 |
| | 5 |
| | 2 |
|
| Total other deductions - net | (355 | ) | | (365 | ) | | (354 | ) | (380 | ) | | (372 | ) | | (401 | ) |
| INCOME BEFORE INCOME TAXES | 2,184 |
| | 1,992 |
| | 1,722 |
| 2,778 |
| | 2,605 |
| | 2,427 |
|
| INCOME TAXES | 835 |
| | 752 |
| | 654 |
| 1,051 |
| | 957 |
| | 910 |
|
NET INCOME(a) | $ | 1,349 |
| | $ | 1,240 |
| | $ | 1,068 |
| $ | 1,727 |
| | $ | 1,648 |
| | $ | 1,517 |
|
______________________
| |
| (a) | FPL's comprehensive income is the same as reported net income. |
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED BALANCE SHEETS
(millions, except share amount)
| | | | December 31, | December 31, |
| | 2013 | | 2012 | 2016 | | 2015 |
| ELECTRIC UTILITY PLANT | | | | |
| ELECTRIC UTILITY PLANT AND OTHER PROPERTY | | | | |
| Plant in service and other property | $ | 36,838 |
| | $ | 34,474 |
| $ | 44,966 |
| | $ | 41,227 |
|
| Nuclear fuel | 1,240 |
| | 1,190 |
| 1,308 |
| | 1,306 |
|
| Construction work in progress | 1,818 |
| | 2,585 |
| 2,039 |
| | 2,850 |
|
| Less accumulated depreciation and amortization | (10,944 | ) | | (10,698 | ) | |
| Total electric utility plant - net | 28,952 |
| | 27,551 |
| |
| Accumulated depreciation and amortization | | (12,304 | ) | | (11,862 | ) |
| Total electric utility plant and other property - net | | 36,009 |
| | 33,521 |
|
| CURRENT ASSETS | |
| | |
| |
| | |
|
| Cash and cash equivalents | 19 |
| | 40 |
| 33 |
| | 23 |
|
| Customer receivables, net of allowances of $5 and $7, respectively | 757 |
| | 760 |
| |
| Customer receivables, net of allowances of $2 and $3, respectively | | 768 |
| | 849 |
|
| Other receivables | 137 |
| | 447 |
| 148 |
| | 123 |
|
| Materials, supplies and fossil fuel inventory | 742 |
| | 727 |
| 851 |
| | 826 |
|
| Regulatory assets: | |
| | |
| |
| Deferred clause and franchise expenses | 192 |
| | 75 |
| |
| Other | 105 |
| | 106 |
| |
| Regulatory assets | | 524 |
| | 502 |
|
| Derivatives | | 209 |
| | 3 |
|
| Other | 261 |
| | 131 |
| 213 |
| | 181 |
|
| Total current assets | 2,213 |
| | 2,286 |
| 2,746 |
| | 2,507 |
|
| OTHER ASSETS | |
| | |
| |
| | |
|
| Special use funds | 3,273 |
| | 2,918 |
| 3,665 |
| | 3,504 |
|
| Prepaid benefit costs | 1,142 |
| | 1,135 |
| 1,301 |
| | 1,243 |
|
| Regulatory assets: | |
| | |
| |
| Securitized storm-recovery costs ($228 and $274 related to a VIE, respectively) | 372 |
| | 461 |
| |
| Other | 396 |
| | 351 |
| |
| Regulatory assets ($107 and $128 related to a VIE, respectively) | | 1,573 |
| | 1,513 |
|
| Other | 140 |
| | 151 |
| 207 |
| | 235 |
|
| Total other assets | 5,323 |
| | 5,016 |
| 6,746 |
| | 6,495 |
|
| TOTAL ASSETS | $ | 36,488 |
| | $ | 34,853 |
| $ | 45,501 |
| | $ | 42,523 |
|
| CAPITALIZATION | |
| | |
| |
| | |
|
| Common stock (no par value, 1,000 shares authorized, issued and outstanding) | $ | 1,373 |
| | $ | 1,373 |
| $ | 1,373 |
| | $ | 1,373 |
|
| Additional paid-in capital | 6,179 |
| | 5,903 |
| 8,332 |
| | 7,733 |
|
| Retained earnings | 5,532 |
| | 5,254 |
| 6,875 |
| | 6,447 |
|
| Total common shareholder's equity | 13,084 |
| | 12,530 |
| 16,580 |
| | 15,553 |
|
| Long-term debt ($331 and $386 related to a VIE, respectively) | 8,473 |
| | 8,329 |
| |
| Long-term debt ($144 and $210 related to a VIE, respectively) | | 9,705 |
| | 9,956 |
|
| Total capitalization | 21,557 |
| | 20,859 |
| 26,285 |
| | 25,509 |
|
| CURRENT LIABILITIES | |
| | |
| |
| | |
|
| Commercial paper | 204 |
| | 105 |
| 268 |
| | 56 |
|
| Other short-term debt | | 150 |
| | 100 |
|
| Current maturities of long-term debt | 356 |
| | 453 |
| 367 |
| | 64 |
|
| Accounts payable | 611 |
| | 612 |
| 837 |
| | 664 |
|
| Customer deposits | 447 |
| | 503 |
| 466 |
| | 469 |
|
| Accrued interest and taxes | 272 |
| | 223 |
| 240 |
| | 279 |
|
| Derivatives | | 1 |
| | 222 |
|
| Accrued construction-related expenditures | 202 |
| | 235 |
| 262 |
| | 240 |
|
| Regulatory liabilities | | 294 |
| | 12 |
|
| Other | 438 |
| | 495 |
| 496 |
| | 343 |
|
| Total current liabilities | 2,530 |
| | 2,626 |
| 3,381 |
| | 2,449 |
|
| OTHER LIABILITIES AND DEFERRED CREDITS | |
| | |
| |
| | |
|
| Asset retirement obligations | 1,285 |
| | 1,206 |
| 1,919 |
| | 1,822 |
|
| Deferred income taxes | 6,355 |
| | 5,584 |
| 8,541 |
| | 7,730 |
|
| Regulatory liabilities: | |
| | |
| |
| Accrued asset removal costs | 1,839 |
| | 1,950 |
| |
| Asset retirement obligation regulatory expense difference | 2,082 |
| | 1,813 |
| |
| Other | 386 |
| | 309 |
| |
| Regulatory liabilities | | 4,893 |
| | 4,595 |
|
| Other | 454 |
| | 506 |
| 482 |
| | 418 |
|
| Total other liabilities and deferred credits | 12,401 |
| | 11,368 |
| 15,835 |
| | 14,565 |
|
| COMMITMENTS AND CONTINGENCIES |
|
| |
|
|
|
| |
|
|
| TOTAL CAPITALIZATION AND LIABILITIES | $ | 36,488 |
| | $ | 34,853 |
| $ | 45,501 |
| | $ | 42,523 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(millions)
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| CASH FLOWS FROM OPERATING ACTIVITIES | | | | | | | | | | |
| Net income | $ | 1,349 |
| | $ | 1,240 |
| | $ | 1,068 |
| $ | 1,727 |
| | $ | 1,648 |
| | $ | 1,517 |
|
| Adjustments to reconcile net income to net cash provided by (used in) operating activities: | |
| | |
| | |
| |
| | |
| | |
|
| Depreciation and amortization | 1,159 |
| | 659 |
| | 798 |
| 1,651 |
| | 1,576 |
| | 1,432 |
|
| Nuclear fuel and other amortization | 184 |
| | 122 |
| | 160 |
| 218 |
| | 209 |
| | 201 |
|
| Deferred income taxes | 617 |
| | 988 |
| | 675 |
| 932 |
| | 504 |
| | 601 |
|
| Cost recovery clauses and franchise fees | (166 | ) | | 129 |
| | 181 |
| 94 |
| | 176 |
| | (67 | ) |
| Allowance for equity funds used during construction | (55 | ) | | (52 | ) | | (35 | ) | |
| Purchased power agreement termination | | — |
| | (521 | ) | | — |
|
| Recoverable storm-related costs | | (223 | ) | | — |
| | — |
|
| Other - net | 101 |
| | (42 | ) | | 60 |
| 42 |
| | (56 | ) | | 94 |
|
| Changes in operating assets and liabilities: | |
| | |
| | |
| |
| | |
| | |
|
| Customer and other receivables | (5 | ) | | (96 | ) | | 65 |
| |
| Materials, supplies and fossil fuel inventory | (16 | ) | | 33 |
| | (254 | ) | |
| Other current assets | 15 |
| | (20 | ) | | (20 | ) | |
| Other assets | (12 | ) | | (41 | ) | | (52 | ) | |
| Accounts payable and customer deposits | (1 | ) | | (33 | ) | | (137 | ) | |
| Income taxes | 384 |
| | (111 | ) | | (215 | ) | |
| Interest and other taxes | 8 |
| | 1 |
| | (21 | ) | |
| Other current liabilities | 3 |
| | 67 |
| | 32 |
| |
| Other liabilities | (7 | ) | | (21 | ) | | (60 | ) | |
| Current assets | | 26 |
| | (89 | ) | | (125 | ) |
| Noncurrent assets | | (31 | ) | | (53 | ) | | (103 | ) |
| Current liabilities | | 16 |
| | 40 |
| | (70 | ) |
| Noncurrent liabilities | | (86 | ) | | (41 | ) | | (26 | ) |
| Net cash provided by operating activities | 3,558 |
| | 2,823 |
| | 2,245 |
| 4,366 |
| | 3,393 |
| | 3,454 |
|
| CASH FLOWS FROM INVESTING ACTIVITIES | |
| | |
| | |
| |
| | |
| | |
|
| Capital expenditures | (2,691 | ) | | (4,070 | ) | | (3,137 | ) | (3,776 | ) | | (3,428 | ) | | (3,067 | ) |
| Cash grants under the American Recovery and Reinvestment Act of 2009 | — |
| | — |
| | 218 |
| |
| Nuclear fuel purchases | (212 | ) | | (215 | ) | | (365 | ) | (158 | ) | | (205 | ) | | (174 | ) |
| Proceeds from sale or maturity of securities in special use funds | 3,342 |
| | 3,790 |
| | 2,988 |
| 2,495 |
| | 3,731 |
| | 3,349 |
|
| Purchases of securities in special use funds | (3,389 | ) | | (3,838 | ) | | (3,052 | ) | (2,506 | ) | | (3,792 | ) | | (3,414 | ) |
| Other - net | 30 |
| | 68 |
| | 89 |
| (15 | ) | | 19 |
| | (268 | ) |
| Net cash used in investing activities | (2,920 | ) | | (4,265 | ) | | (3,259 | ) | (3,960 | ) | | (3,675 | ) | | (3,574 | ) |
| CASH FLOWS FROM FINANCING ACTIVITIES | |
| | |
| | |
| |
| | |
| | |
|
| Issuances of long-term debt | 497 |
| | 1,296 |
| | 840 |
| 309 |
| | 1,084 |
| | 997 |
|
| Retirements of long-term debt | (453 | ) | | (50 | ) | | (45 | ) | (262 | ) | | (551 | ) | | (355 | ) |
| Net change in short-term debt | 99 |
| | (225 | ) | | 229 |
| |
| Proceeds from other short-term debt | | 500 |
| | 100 |
| | — |
|
| Repayments of other short-term debt | | (450 | ) | | — |
| | — |
|
| Net change in commercial paper | | 212 |
| | (1,086 | ) | | 938 |
|
| Capital contributions from NEE | 275 |
| | 440 |
| | 410 |
| 600 |
| | 1,454 |
| | 100 |
|
| Dividends to NEE | (1,070 | ) | | — |
| | (400 | ) | (1,300 | ) | | (700 | ) | | (1,550 | ) |
| Other - net | (7 | ) | | (15 | ) | | (4 | ) | (5 | ) | | (10 | ) | | (15 | ) |
| Net cash provided by (used in) financing activities | (659 | ) | | 1,446 |
| | 1,030 |
| (396 | ) | | 291 |
| | 115 |
|
| Net increase (decrease) in cash and cash equivalents | (21 | ) | | 4 |
| | 16 |
| 10 |
| | 9 |
| | (5 | ) |
| Cash and cash equivalents at beginning of year | 40 |
| | 36 |
| | 20 |
| 23 |
| | 14 |
| | 19 |
|
| Cash and cash equivalents at end of year | $ | 19 |
| | $ | 40 |
| | $ | 36 |
| $ | 33 |
| | $ | 23 |
| | $ | 14 |
|
| SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION | |
| | |
| | |
| |
| | |
| | |
|
| Cash paid for interest (net of amount capitalized) | $ | 410 |
| | $ | 400 |
| | $ | 389 |
| $ | 434 |
| | $ | 435 |
| | $ | 417 |
|
| Cash paid (received) for income taxes - net | $ | (166 | ) | | $ | (124 | ) | | $ | 194 |
| |
| Cash paid for income taxes - net | | $ | 147 |
| | $ | 439 |
| | $ | 342 |
|
| SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES | |
| | |
| | |
| |
| | |
| | |
|
| Accrued property additions | $ | 386 |
| | $ | 472 |
| | $ | 526 |
| $ | 664 |
| | $ | 474 |
| | $ | 404 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY
(millions)
| | | | Common Stock | | Additional Paid-In Capital | | Retained Earnings | | Common Shareholder's Equity | Common Stock | | Additional Paid-In Capital | | Retained Earnings | | Common Shareholder's Equity |
| Balances, December 31, 2010 | $ | 1,373 |
| | $ | 5,054 |
| | $ | 3,364 |
| | $ | 9,791 |
| |
| Balances, December 31, 2013 | | $ | 1,373 |
| | $ | 6,179 |
| | $ | 5,532 |
| | $ | 13,084 |
|
| Net income | — |
| | — |
| | 1,068 |
| | | — |
| | — |
| | 1,517 |
| | |
| Capital contributions from NEE | — |
| | 410 |
| | — |
| | | — |
| | 100 |
| | — |
| | |
| Dividends to NEE | — |
| | — |
| | (419 | ) | | | — |
| | — |
| | (1,550 | ) | | |
| Balances, December 31, 2011 | 1,373 |
| | 5,464 |
| | 4,013 |
| | $ | 10,850 |
| |
| Balances, December 31, 2014 | | 1,373 |
| | 6,279 |
| | 5,499 |
| | $ | 13,151 |
|
| Net income | — |
| | — |
| | 1,240 |
| | | — |
| | — |
| | 1,648 |
| | |
| Capital contributions from NEE | — |
| | 440 |
| | — |
| | | — |
| | 1,454 |
| | — |
| | |
| Other | — |
| | (1 | ) | | 1 |
| | | |
| Balances, December 31, 2012 | 1,373 |
| | 5,903 |
| | 5,254 |
| | $ | 12,530 |
| |
| Dividends to NEE | | — |
| | — |
| | (700 | ) | | |
| Balances, December 31, 2015 | | 1,373 |
| | 7,733 |
| | 6,447 |
| | $ | 15,553 |
|
| Net income | — |
| | — |
| | 1,349 |
| | | — |
| | — |
| | 1,727 |
| | |
| Capital contributions from NEE | — |
| | 275 |
| | — |
| | | — |
| | 600 |
| | — |
| | |
| Dividends to NEE | — |
| | — |
| | (1,070 | ) | | | — |
| | — |
| | (1,300 | ) | | |
| Other | — |
| | 1 |
| | (1 | ) | | | — |
| | (1 | ) | | 1 |
| | |
| Balances, December 31, 2013 | $ | 1,373 |
| | $ | 6,179 |
| | $ | 5,532 |
| | $ | 13,084 |
| |
| Balances, December 31, 2016 | | $ | 1,373 |
| | $ | 8,332 |
| | $ | 6,875 |
| | $ | 16,580 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Years Ended December 31, 2013, 20122016, 2015 and 20112014
1. Summary of Significant Accounting and Reporting Policies
Basis of Presentation - The operations of NextEra Energy, Inc. (NEE) are conducted primarily through its wholly-owned subsidiary Florida Power & Light Company (FPL), a wholly owned subsidiary, and its wholly-owned indirect subsidiary NextEra Energy Resources, LLC (NEER)., a wholly owned indirect subsidiary. FPL, a rate-regulated electric utility, supplies electric service to approximately 4.74.9 million customer accounts throughout most of the east and lower west coasts of Florida. NEER invests in independent power projects through both controlled and consolidated entities and non-controllingnoncontrolling ownership interests in joint ventures essentially all of which are accounted for under the equity method. NEER also participates in natural gas, natural gas liquids and oil production primarily through non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests.
The consolidated financial statements of NEE and FPL include the accounts of their respective majority-owned and controlled subsidiaries. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates.
NextEra Energy Partners, LP - NEE, through NEER, formed NextEra Energy Partners, LP (NEP) to acquire, manage and own contracted clean energy projects with stable, long-term cash flows through a limited partner interest in NextEra Energy Operating Partners, LP (NEP OpCo). On July 1, 2014, NEP closed its initial public offering (IPO) by issuing 18,687,500 common units representing limited partner interests. The proceeds from the sale of the common units, net of underwriting discounts, commissions and structuring fees, were approximately $438 million. NEP used such proceeds to purchase 18,687,500 common units of NEP OpCo, of which approximately $288 million was used to purchase common units from an indirect wholly owned subsidiary of NEE and $150 million was used to purchase common units from NEP OpCo. Through an indirect wholly owned subsidiary, NEE retained 74,440,000 units of NEP OpCo representing a 79.9% interest in NEP's operating projects. Additionally, NEE owns a controlling general partner interest in NEP and consolidates NEP for financial reporting purposes and presents NEP's limited partner interest as a noncontrolling interest in NEE's consolidated financial statements. Certain equity and asset transactions between NEP, NEER and NEP OpCo involve the exchange of cash, energy projects and ownership interests in NEP OpCo. These exchanges are accounted for under the profit sharing method and resulted in a profit sharing liability, net of amortization, of approximately $757 million and $447 million at December 31, 2016 and 2015, respectively, which is reflected in noncurrent other liabilities on NEE's consolidated balance sheets. The profit sharing liability will be amortized into income on a straight-line basis over the estimated useful lives of the underlying energy projects held by NEP OpCo. Accordingly, the profit sharing liability amortization totaled approximately $37 million during 2016 and is included in taxes other than income taxes and other - net in NEE’s consolidated statements of income. During the purchase price adjustment period associated with the IPO, which ended in November 2016, approximately $288 million of the profit sharing liability was not amortized.
During 2015 and 2016, NEP sold an additional 35,527,435 common units and purchased an additional 35,527,435 NEP OpCo common units. Also, in 2015, a subsidiary of NEE purchased 27,000,000 of NEP OpCo's common units. After giving effect to these transactions, NEE’s partnership interest in NEP OpCo's operating projects is approximately 65.2% as of December 31, 2016. As of December 31, 2016, NEP, through NEER's contribution of energy projects to NEP OpCo, owns or has an interest in a portfolio of 22 wind and solar projects with generating capacity totaling approximately 2,787 megawatts (MW), as well as a portfolio of seven long-term contracted natural gas pipeline assets located in Texas.
In October 2015, NEE authorized a program to purchase, from time to time, up to $150 million of common units representing limited partner interests of NEP. Under the program, any purchases may be made in amounts, at prices and at such times as NEE or its subsidiaries deem appropriate, all subject to market conditions and other considerations. The common unit purchase program does not require NEE to acquire any specific number of common units and may be modified or terminated by NEE at any time. The purchases may be made in the open market or in privately negotiated transactions. As of December 31, 2016, NEE had purchased approximately $36 million of NEP common units under this program.
Rate Regulation - FPL is subject to rate regulation by the Florida Public Service Commission (FPSC) and the Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing electric service to its customers including a reasonable rate of return on invested capital. As a result of this cost-based regulation, FPL follows the accounting guidance that allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities. Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
NEE's and FPL's regulatory assets and liabilities are as follows:
|
| | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | December 31, | | December 31, |
| | 2016 | | 2015 | | 2016 | | 2015 |
| | (millions) |
| Regulatory assets: | | | | | | | |
| Current: | | | | | | | |
| Derivatives | $ | — |
| | $ | 218 |
| | $ | — |
| | $ | 218 |
|
| Storm reserve deficiency | 203 |
| | — |
| | 203 |
| | — |
|
| Other | 321 |
| | 285 |
| | 321 |
| | 284 |
|
| Total | $ | 524 |
| | $ | 503 |
| | $ | 524 |
| | $ | 502 |
|
| Noncurrent: | |
| | |
| | |
| | |
|
| Purchased power agreement termination | $ | 636 |
| | $ | 726 |
| | $ | 636 |
| | $ | 726 |
|
| Other | 1,258 |
| | 1,052 |
| | 937 |
| | 787 |
|
| Total | $ | 1,894 |
| | $ | 1,778 |
| | $ | 1,573 |
| | $ | 1,513 |
|
| Regulatory liabilities: | |
| | |
| | |
| | |
|
| Current: | | | | | | | |
| Derivatives | $ | 208 |
| | $ | — |
| | $ | 208 |
| | $ | — |
|
| Other | 91 |
| | 14 |
| | 86 |
| | 12 |
|
| Total | $ | 299 |
| | $ | 14 |
| | $ | 294 |
| | $ | 12 |
|
| Noncurrent: | |
| | |
| | |
| | |
|
| Accrued asset removal costs | $ | 1,956 |
| | $ | 1,930 |
| | $ | 1,944 |
| | $ | 1,921 |
|
| Asset retirement obligation regulatory expense difference | 2,294 |
| | 2,182 |
| | 2,294 |
| | 2,182 |
|
| Other | 656 |
| | 494 |
| | 655 |
| | 492 |
|
| Total | $ | 4,906 |
| | $ | 4,606 |
| | $ | 4,893 |
| | $ | 4,595 |
|
Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through the various clauses, include substantially all fuel, purchased power and interchange expense, certain costs associated with the acquisition of certain generation facilities, certain construction-related costs for FPL's planned additional nuclear units at Turkey Point andcertain of FPL's solar generatinggeneration facilities, and conservation and certain environmental-related costs. Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods.
In 2015, FPL assumed ownership of a 250 MW coal-fired generation facility located in Jacksonville, Florida (Cedar Bay generation facility) and terminated its long-term purchased power agreement for substantially all of the facility’s capacity and energy for a purchase price of approximately $521 million. The FPSC approved a stipulation and settlement between the State of Florida Office of Public Counsel and FPL regarding issues relating to the ratemaking treatment for the Cedar Bay generation facility which provides for recovery of the purchase price and associated income tax gross-up as a regulatory asset of approximately $847 million which will be amortized over approximately nine years. At December 31, 2016 and 2015, the regulatory assets, net of amortization, totaled approximately $726 million and $817 million, respectively, and are included in current and noncurrent regulatory assets on NEE’s and FPL’s consolidated balance sheets. This settlement also reduced the reserve amount that was available for amortization under the 2012 rate agreement by $30 million to $370 million. See Revenues and Rates - FPL Rates Effective January 2013 through December 2016 below. In December 2016, FPL retired the Cedar Bay generation facility.
If FPL were no longer subject to cost-based rate regulation, the existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund. In addition, the FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. The continued applicability of regulatory accounting is assessed at each reporting period.
Revenues and Rates - FPL's retail and wholesale utility rate schedules are approved by the FPSC and the FERC, respectively. FPL records unbilled base revenues for the estimated amount of energy delivered to customers but not yet billed. FPL's unbilled base revenues are included in customer receivables on NEE's and FPL's consolidated balance sheets and amounted to approximately $200$261 million and $175$246 million at December 31, 20132016 and 2012,2015, respectively. FPL's operating revenues also include amounts resulting from cost recovery clauses (see Rate Regulation above), franchise fees, gross receipts taxes and surcharges related to storm-recovery bonds (see Note 8 - FPL). Franchise fees and gross receipts taxes are imposed on FPL; however, the FPSC allows FPL to include in the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise amountfee for those customers located in the jurisdiction that imposes the fee.amount. Accordingly, franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $680 million, $684 million and $716 million in 2013, 2012 and 2011, respectively. The revenues from the surcharges related to storm-recovery bonds included in operating revenues in NEE's and FPL's consolidated statements of income were approximately $108 million, $106 million and $100 million in 2013, 2012 and 2011, respectively. FPL also collects municipal utility taxes which are reported gross in customer receivables and accounts payable on NEE's and FPL's consolidated balance sheets.
FPL Rates Effective January 2013 - December 2016 - In January 2013, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement). Key elements of the 2012 rate agreement, which is effective from January 2013 through December 2016, include, among other things, the following:
New retail base rates and charges were established in January 2013 resulting in an increase in retail base revenues of $350 million on an annualized basis.
FPL's allowed regulatory return on common equity (ROE) is 10.50%, with a range of plus or minus 100 basis points. If FPL's earned regulatory ROE falls below 9.50%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.50%, any party to the 2012 rate agreement other than FPL may seek a review of FPL's retail base rates.
Retail base rates will be increased by the annualized base revenue requirements for FPL's three modernization projects (Cape Canaveral, Riviera Beach and Port Everglades) as each of the modernized power plants becomes operational. (Cape Canaveral became operational in April 2013 and Riviera Beach and Port Everglades are expected to be operational in the second quarter of 2014 and by mid-2016, respectively.)
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Cost recoverygross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $700 million, $722 million and $716 million in 2016, 2015 and 2014, respectively. The revenues from the surcharges related to storm-recovery bonds included in operating revenues in NEE's and FPL's consolidated statements of income were approximately $119 million, $115 million and $109 million in 2016, 2015 and 2014, respectively. FPL also collects municipal utility taxes which are reported gross in customer receivables and accounts payable on NEE's and FPL's consolidated balance sheets.
FPL Rates Effective January 2017 through December 2020 - In December 2016, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2016 rate agreement). Key elements of the 2016 rate agreement, which is effective from January 2017 through at least December 2020, include, among other things, the following:
New retail base rates and charges were established resulting in the following increases in annualized retail base revenues:
| |
| ◦ | $400 million beginning January 1, 2017; |
| |
| ◦ | $211 million beginning January 1, 2018; and |
| |
| ◦ | $200 million when a new approximately 1,750 MW natural gas-fired combined-cycle unit in Okeechobee County, Florida achieves commercial operation, which is expected to occur in mid-2019. |
In addition, FPL is eligible to receive, subject to conditions specified in the 2016 rate agreement, base rate increases associated with the addition of up to 300 MW annually of new solar generation in each of 2017 through 2020 and may carry forward any unused MW to subsequent years during the term of the 2016 rate agreement. FPL will be required to demonstrate that any proposed solar facilities are cost effective and scheduled to be in service before December 31, 2021. FPL has agreed to an installed cost cap of $1,750 per kilowatt (kW).
FPL's allowed regulatory return on common equity (ROE) is 10.55%, with a range of 9.60% to 11.60%. If FPL's earned regulatory ROE falls below 9.60%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.60%, any party other than FPL may seek a review of FPL's West County Energy Center (WCEC) Unit No. 3 will continue to occur through the capacity cost recovery clause (capacity clause) (reported as retail base rates); however, such recovery will not be limited to the projected annual fuel cost savings as was the case in the previous rate agreement discussed below.rates.
Subject to certain conditions, FPL may amortize, over the term of the 20122016 rate agreement, aup to $1.0 billion of depreciation reserve surplus plus the reserve amount remaining at the end ofunder FPL's 2012 under the 2010 rate agreement discussed below (approximately $224 million) and may amortize a portion of FPL's fossil dismantlement reserve up to a maximum of $176 million (collectively, the reserve)$250 million), provided that in any year of the 20122016 rate agreement, FPL must amortize at least enough reserve to maintain a 9.50%9.60% earned regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 11.50%11.60%.
Future storm restoration costs would be recoverable on an interim basis beginning 60 days from the filing of a cost recovery petition, but capped at an amount that could produce a surcharge of no more than $4$4 for every 1,000 kilowatt-hours kilowatt-hour (kWh) of usage on residential bills during the first 12 months of cost recovery. Any additional costs would be eligible for recovery in subsequent years. If storm restoration costs exceed $800$800 million in any given calendar year, FPL may request an increase to the $4$4 surcharge to recover amounts above $400 million.
In January 2017, the amount aboveSierra Club filed a notice of appeal challenging the FPSC’s final order approving the 2016 rate agreement, which notice of appeal is pending before the Florida Supreme Court.
FPL Rates Effective January 2013 through December 2016 - Effective January 2013, pursuant to an FPSC final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement), new retail base rates and charges for FPL were established resulting in an increase in retail base revenues of $350 million on an annualized basis. The 2012 rate agreement, provided for, among other things, the following:
a regulatory ROE of $800 million10.50%. with a range of plus or minus 100 basis points;
Anan increase in annualized base revenue requirements as each of three FPL modernized power plants became operational in April 2013, April 2014 and April 2016;
the continuation of cost recovery through the capacity clause (reported as retail base revenues) for a generating unit which was placed in service in May 2011 (beginning January 2017, under the 2016 rate agreement, cost recovery will be through base rates);
subject to certain conditions, the right to reduce depreciation expense up to $400 million (reserve), provided that in any year of the 2012 rate agreement, FPL was required to amortize enough reserve to maintain an earned regulatory ROE within the range of 9.50% to 11.50% (see Rate Regulation above regarding a subsequent reduction in the reserve amount);
an interim cost recovery mechanism for storm restoration costs (see Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve below); and
an incentive mechanism whereby customers will receive 100% of certain gains, including but not limited to, gains from the purchase and sale of electricity and natural gas (including transportation and storage), up to a specified threshold. Thethreshold; gains exceeding that specified threshold will bewere shared by FPL and its customers.
In September 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.
FPL Rates Effective March 2010 - December 2012 - Effective March 1, 2010, pursuant to an FPSC final order (2010 FPSC rate order), new retail base rates for FPL were established, resulting in an increase in retail base revenues of approximately $75 million on an annualized basis. The 2010 FPSC rate order, among other things, also established a regulatory ROE of 10.0% with a range of plus or minus 100 basis points. In February 2011, the FPSC issued a final order approving a stipulation and settlement agreement between FPL and principal parties in FPL's 2009 rate case (2010 rate agreement). The 2010 rate agreement, which was effective through December 31, 2012, provided for, among other things, a reduction in depreciation expense (surplus depreciation credit) in any calendar year up to a cap in 2010 of $267 million, a cap in subsequent years of $267 million plus the amount of any unused portion from prior years, and a total cap of $776 million over the course of the 2010 rate agreement, provided that in any year of the 2010 rate agreement FPL was required to use enough surplus depreciation credit to maintain an earned regulatory ROE within the range of 9.0% - 11.0%. The 2010 rate agreement also permitted incremental cost recovery through FPL's capacity clause for WCEC Unit No. 3 up to the amount of the projected annual fuel savings for customers.
NEER's revenue is recorded on the basis of commodities delivered, contracts settled or services rendered and includes estimated amounts yet to be billed to customers. Certain commodity contracts for the purchase and sale of power that meet the definition of a derivative are recorded at fair value with subsequent changes in fair value recognized as revenue. See Energy Trading below and Note 3.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
In May 2014, the Financial Accounting Standards Board (FASB) issued an accounting standards update which provides guidance on the recognition of revenue from contracts with customers and requires additional disclosures about the nature, amount, timing and uncertainty of revenue and cash flows from an entity's contracts with customers. The standards update will be effective for NEE and FPL beginning January 1, 2018 with early adoption on January 1, 2017 permitted. The standards update may be applied retrospectively to each prior period presented or retrospectively with the cumulative effect recognized as an adjustment to retained earnings as of the date of initial application (modified retrospective method).
NEE and FPL are currently reviewing individual contracts within various identified revenue streams in order to determine the impact, if any, this standards update will have on their consolidated financial statements. A number of industry-specific implementation issues are still unresolved and the final resolution of certain of these issues could impact NEE's and/or FPL's current accounting policies and/or revenue recognition patterns. NEE and FPL currently anticipate adopting the standards update on January 1, 2018 using the modified retrospective method.
Electric Plant, Depreciation and Amortization - The cost of additions to units of property of FPL and NEER is added to electric plant in service. In accordance with regulatory accounting, the cost of FPL's units of utility property retired, less estimated net salvage value, is charged to accumulated depreciation. Maintenance and repairs of property as well as replacements and renewals of items determined to be less than units of utility property are charged to other operations and maintenance (O&M) expenses. At December 31, 2013,2016, the electric generating,generation, transmission, distribution and general facilities of FPL represented approximately 51%50%, 11%, 33% and 5%6%, respectively, of FPL's gross investment in electric utility plant in service and other property. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. A number of NEER's generatinggeneration and pipeline facilities are encumbered by liens securing various financings. The net book value of NEER's assets serving as collateral was approximately $10.215.5 billion at December 31, 20132016. The American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 20132016 and 20122015, convertible ITCs, net of amortization, were approximately $1.5$2.1 billion ($165 ($147 million at FPL) and $1.4$1.8 billion ($171153 million at FPL). At December 31, 20132016 and 20122015, approximately $182$289 million and $170207 million, respectively, of such convertible ITCs are included primarily in other receivables on NEE's consolidated balance sheets.
Depreciation of FPL's electric property is primarily provided on a straight-line average remaining life basis. FPL includes in depreciation expense a provision for fossil and solar plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs)Costs below), storm recovery amortization and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery clause. For substantially all of FPL's property, depreciation studies are typically performed and filed with the FPSC at least every four years. As part of the 2010 FPSC rate order, the FPSC approved new depreciation rates which became effective January 1, 2010. In accordance with the 2012 rate agreement, FPL iswas not required to file depreciation studies during the effective period of the agreement and theagreement; therefore, previously approved depreciation rates remainwhich became effective January 1, 2010 remained in effect.effect through December 2016. As discussed in RevenueRevenues and Rates above, the use of reserve amortization (the reduction of the reservewas permitted under the 2012 rate agreement. In accordance with the 2012 rate agreement, FPL recorded reserve amortization (reversal) of approximately $13 million, $(15) million and $(33) million in 2016, 2015 and 2014, respectively. The reserve is amortized as a reduction of (or reversed as an increase to) accrued asset removal costs which is reflected in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. The weighted annual composite depreciation and amortization rate for FPL's electric utility plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the surplus depreciation credit underadjustments discussed above, was approximately 3.4%, 3.3% and 3.3% for 2016, 2015 and 2014, respectively. As part of the 20102016 rate agreement) is permitted underagreement, the 2012FPSC approved new depreciation rates which became effective January 1, 2017. These new rates are expected to increase depreciation expense. The 2016 rate agreement also permits reserve amortization during the term of the agreement. See Revenues and 2010 rate agreements.Rates above. FPL files a twelve-month forecast
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with the FPSC each year which contains a regulatory ROE intended to be earned based on the best information FPL has at that time assuming normal weather. This forecast establishes a fixed targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period under the 2012 and 2010effective rate agreements,agreement, reserve amortization is calculated using a trailing thirteen-month average of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues net of O&M, depreciation and amortization, interest and tax expenses. In general, the net impact of these income statement line items is adjusted, in part, by reserve amortization or its reversal to earn the targeted regulatory ROE.In accordance with the 2012 and 2010 rate agreements, FPL recorded approximately $155 million, $480 million and $187 million of reserve amortization in 2013, 2012 and 2011, respectively. Beginning in 2013, the reserve is amortized as a reduction of regulatory liabilities - accrued asset removal costs on NEE's and FPL's consolidated balance sheets. The weighted annual composite depreciation and amortization rate for FPL's electric utility plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed above, was approximately 3.4%, 3.3% and 3.2% for 2013, 2012 and 2011, respectively.
At December 31, 2012, approximately $309 million and $258 million was included in plant in service and other property and accumulated depreciation and amortization, respectively, on FPL's balance sheets (electric plant in service and other property and accumulated depreciation and amortization, respectively, for NEE) with respect to Port Everglades Units Nos. 3 and 4, which FPL retired and began dismantling in 2013. Upon retirement in 2013, FPL reclassified the net book value to a regulatory asset and began amortizing it over a four-year period.
NEER's electric plant in service less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. At December 31, 20132016 and 2012,2015, wind, nuclear, natural gas and solar plants represented approximately 62% and 67%62%, 13%10% and 11%, less than 1% and 3%, and 14%, and 9% and 10%, and 6% and 1%, respectively, of NEER's depreciable electric plant in service and other property. The estimated useful lives of NEER's plants range primarily from 25 to 30 years for wind, natural gas and solar plants and from 25 to 47 years for nuclear plants. NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. In 2011, this review indicated thatNEER's oil and gas production assets, representing approximately 8% and 7%, respectively, of NEER's depreciable electric plant in service and other property at December 31, 2016 and 2015, are accounted for under the actual lives of certain equipment at NEER's wind plants are expected to be longer than the previously estimated useful lives used for depreciation purposes. As a result, effective January 1, 2011, NEER changed the estimates of the useful lives of certain equipment to better reflect the estimated periods during which these assets are expected to remain in service. The useful lives of substantially all of the wind plants’ equipment that were previously estimated to be 25 years were increased to 30 years. The effect of this change in estimate was to reduce depreciation and amortization expense by approximately $75 million, increase net income by $44 million and increase basic and diluted earnings per share by approximately $0.11successful efforts method. Depletion expenses for the year ended December 31, 2011.acquisition of reserve rights and development costs are recognized using the unit of production method.
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Nuclear Fuel - FPL and NEER have several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel. See Note 13 - Contracts. FPL's and NEER's nuclear fuel costs are charged to fuel expense on a unit of production method.
Construction Activity - Allowance for funds used during construction (AFUDC) is a non-cash item which represents the allowed cost of capital, including an ROE, used to finance FPL construction projects. The portion of AFUDC attributable to borrowed funds is recorded as a reduction of interest expense and the remainder is recorded as other income. For FPL, FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the 0.5% threshold as a component of rate base. During 2013, 2012each of 2016, 2015 and 2011,2014, FPL capitalized AFUDC at a rate of 6.52%6.34%, 6.41% and 6.41%, respectively, which amounted to approximately $81$97 million, $7488 million and $50 million, respectively. See Note 13 - Commitments.
FPL's construction work in progress includes construction materials, progress payments on major equipment contracts, engineering costs, AFUDC and other costs directly associated with the construction of various projects. Upon completion of the projects, these costs are transferred to electric utility plant in service and other property. Capitalized costs associated with construction activities are charged to O&M expenses when recoverability is no longer probable. See Regulation above for information on recovery of costs associated with new nuclear capacity and solar generating facilities.
NEER capitalizes project development costs once it is probable that such costs will be realized through the ultimate construction of a power plant or sale of development rights. At December 31, 20132016 and 20122015, NEER's capitalized development costs totaled approximately $162193 million and $106133 million, respectively, which are included in noncurrent other assets on NEE's consolidated balance sheets. These costs include land rights and other third-party costs directly associated with the development of a new project. Upon commencement of construction, these costs either are transferred to construction work in progress or remain in other assets, depending upon the nature of the cost. Capitalized development costs are charged to O&M expenses when it is no longer probable that these costs are not realizable.will be realized.
NEER's construction work in progress includes construction materials, prepaymentsprogress payments on turbine generators and othermajor equipment contracts, third-party engineering costs, capitalized interest and other costs directly associated with the construction and development of various projects. Interest capitalized on construction projects amounted to approximately $109107 million, $139100 million and $104 million during 2013, 20122016, 2015 and 20112014, respectively. Interest expense allocated from NextEra Energy Capital Holdings, Inc. (NEECH) to NEER is based on a deemed capital structure of 70% debt. Upon commencement of plant operation, costs associated with construction work in progress are transferred to electric plant in service and other property.
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Asset Retirement Obligations - NEE and FPL each account for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets. The asset retirement cost is subsequently allocated to expense, for NEE's non-rate regulated operations, and regulatory liability, for FPL, using a systematic and rational method over the asset’s estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in the consolidated statements of income.income for NEE's non-rate regulated operations, and ARO and regulatory liability, in the case of FPL. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted, in the case of NEE's non-rate regulated operations, and ARO and regulatory liability, in the case of FPL. See Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 12.
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs - For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. For financial reporting purposes, FPL recognizes decommissioning and dismantlement liabilities in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory liability in accordance with regulatory accounting. See Revenues and Rates, Electric Plant, Depreciation and Amortization, Asset Retirement Obligations above and Note 12.
Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2010.2015. These studies reflect FPL's current plans, under the operating licenses, for prompt dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2032 and 2033, respectively, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the prompt dismantlement of St. Lucie Unit No. 2 in 2043. These studies also assume that FPL will be storing spent fuel on site pending removal to a U.S.United States (U.S.) government facility. The studies indicate FPL's portion of the ultimate costs of decommissioning its four nuclear units, including costs associated with
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
spent fuel storage above what is expected to be refunded by the U.S. Department of Energy (DOE) under a spent fuel settlement agreement, to be approximately $6.2$7.5 billion,, or $2.5$3.0 billion expressed in 20132016 dollars.
Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's and FPL's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily classified as available for sale and carried at fair value. See Note 4. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of dividends and interest. Fund earnings, consisting of dividends, interest and realized gains and losses, net of taxes, are reinvested in the funds. Fund earnings, as well as any changes in unrealized gains and losses, are not recognized in income and are reflected as a corresponding offset in the related regulatory liability accounts. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of fund earnings. During 2013, 20122016, 2015 and 20112014 fund earnings on decommissioning funds were approximately $167$102 million,, $98 $96 million and $66$91 million,, respectively. The tax effects of amounts not yet recognized for tax purposes are included in accumulated deferred income taxes.
Fossil and solar plant dismantlement studies are typically performed at least every four years and are submitted to the FPSC for approval. FPL's latestIn accordance with the 2012 rate agreement, FPL was not required to file fossil and solar plant dismantlement studies during the effective period of the agreement; therefore, previously approved studies which became effective January 1, 2010 remained in effect through December 2016 and resulted in an annual expense of $18$18 million which is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. As part of the 2016 rate agreement, the FPSC approved a new annual expense of $26 million based on FPL's 2016 fossil and solar dismantlement studies which became effective January 1, 2017. At December 31, 2013,2016, FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $751$1.3 billion, or $480 million, or $394 million expressed in 20132016 dollars. In accordance with the 2012 rate agreement, FPL is not required to file fossil and solar dismantlement studies during the effective period of the agreement.
NEER records nuclear decommissioning liabilities for Seabrook Station (Seabrook), Duane Arnold Energy Center (Duane Arnold) and Point Beach Nuclear Power Plant (Point Beach) and dismantlement liabilities for its wind and solar facilities, when required in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. The liability isliabilities are being accreted using the interest method through the date decommissioning or dismantlement activities are expected to be complete. See Note 12. At December 31, 20132016 and 2012,2015, NEER's ARO, which is primarily related to nuclear decommissioning totaledand wind and solar dismantlement, was approximately $434817 million and $408647 million, respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning.decommissioning or dismantlement. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $11.911.8 billion, or $2.0 billion expressed in 20132016 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately$1.8 billion.
Seabrook files a comprehensive nuclear decommissioning study with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) every four years; the most recent study was filed in 2011.2015. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC), and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily classified as available for sale and carried at fair value. Market adjustments result in a corresponding adjustment to other comprehensive income (OCI), except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NEE's consolidated statements of income. Fund earnings are recognized in income and are reinvested in the funds. See Note 4. The tax effects of amounts not yet recognized for tax purposes are included in accumulated deferred income taxes.
Major Maintenance Costs - FPL uses the accrue-in-advance method for recognizingrecognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment and records the related accrual as a regulatory liability. FPL expenses costs associated with planned fossil maintenance as incurred. FPL's estimated nuclear maintenance costs for each nuclear unit's next planned outage are accrued over the period from the end of the last outage to the end of the next planned outage. Any difference between the estimated and actual costs is included in O&M expenses when known. The accrued liability for nuclear maintenance costs at December 31, 20132016 and 20122015 totaled approximately $70$65 million and $35$48 million,, respectively, and is included in noncurrent regulatory liabilities - other on NEE's and FPL's consolidated balance sheets. For the years ended December 31, 2013, 20122016, 2015 and 2011,2014, FPL recognized approximately $9289 million, $10490 million and $9776 million, respectively, in nuclear maintenance costs which are primarily included in O&M expenses in NEE's and FPL's consolidated statements of income.
NEER uses the deferral method to account for certain planned major maintenance costs. NEER's major maintenance costs for its nuclear generatinggeneration units and combustion turbines are capitalized and amortized on a unit of production method over the period from the end of the last outage to the beginning of the next planned outage. NEER's capitalized major maintenance costs, net of accumulated amortization, totaled approximately $9269 million and $14897 million at December 31, 20132016 and 20122015, respectively, and are included in noncurrent other assets on NEE's consolidated balance sheets. For the years ended December 31, 2013, 20122016, 2015 and 2011
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
2014, NEER amortized approximately $9374 million, $10079 million and $7781 million in major maintenance costs which are included in O&M expenses in NEE's consolidated statements of income.
Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.
Restricted Cash - At December 31, 20132016 and 2012,2015, NEE had approximately $215311 million ($38120 million for FPL) and $149244 million ($3875 million for FPL), respectively, of restricted cash included in other current assets on NEE's and FPL's consolidated balance sheets, which was restricted primarily forrelated to margin cash collateral requirements, debt service payments and margin cash collateral.bond proceeds held for construction at FPL. Where offsetting positions exist, restricted cash related to margin cash collateral is netted against derivative instruments. See Note 3. In addition, NEE had approximately $2 million and $251 million of noncurrent restricted cash at December 31, 2013 and 2012, respectively, related to loan proceeds held for construction at NEER, which is included in noncurrent other assets on NEE's consolidated balance sheets.
Allowance for Doubtful Accounts - FPL maintains an accumulated provision for uncollectible customer accounts receivable that is estimated using a percentage, derived from historical revenue and write-off trends, of the previous five months of revenue. Additional amounts are included in the provision to address specific items that are not considered in the calculation described above. NEER regularly reviews collectibility of its receivables and establishes a provision for losses estimated as a percentage of accounts receivable based on the historical bad debt write-off trends for its retail electricity provider operations and, when necessary, using the specific identification method for all other receivables.
Inventory - FPL values materials, supplies and fossil fuel inventory using a weighted-average cost method. NEER's materials, supplies and fossil fuel inventories are carried at the lower of weighted-average cost or market, unless evidence indicates that the weighted-average cost (even if in excess of market) will be recovered with a normal profit upon sale in the ordinary course of business.
Energy Trading - NEE provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, in certain markets and engages in power and gas marketing and trading activities to optimize the value of electricity and fuel contracts, generatinggeneration facilities and gas infrastructure assets, as well as to take advantage of projected favorable commodity price movements. Trading contracts that meet the definition of a derivative are accounted for at fair value and realized gains and losses from all trading contracts, including those where physical delivery is required, are recorded net for all periods presented. See Note 3.
Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve - In connection with the 2007 storm-recovery bond financing (see Note 8 - FPL), the net proceeds to FPL from the sale of the storm-recovery property were used primarily to reimburse FPL for its estimated net of tax deficiency in its storm and property insurance reserve (storm reserve) and provide for a storm and property insurance reserve fund (storm fund). Upon the issuance of the storm-recovery bonds, the storm reserve deficiency was reclassified to securitized storm-recovery costs andwhich is recorded as a current and noncurrent regulatory asset on NEE's and FPL's consolidated balance sheets. As storm-recovery charges are billed to customers (which are included in operating revenues), the securitized storm-recovery costs are amortized and included in depreciation
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
and amortization expense in NEE's and FPL's consolidated statements of income. Marketable securities held in the storm fund are classified as available for sale and are carried at fair value with market adjustments, including any other than temporary impairment losses, resulting in a corresponding adjustment to the storm reserve.value. See Note 4. Fund earnings, consisting of dividends, interest and realized gains and losses, net of taxes, are reinvested in the fund. Fund earnings, as well as any changes in unrealized gains and losses, are not recognized in income and are reflected as a corresponding adjustment to the storm reserve. The tax effects of amounts not yet recognized for tax purposes are included in accumulated deferred income taxes. The storm fund is included in special use funds on NEE's and FPL's consolidated balance sheets and was approximately $74 million and $73 millionat December 31, 20132015. During the fourth quarter of 2016, all available funds were withdrawn from the storm fund to pay for the storm restoration costs associated with Hurricane Hermine and 2012, respectively. See Note 4.Hurricane Matthew (see below regarding Hurricane Hermine and Hurricane Matthew).
TheFPL was impacted by Hurricane Hermine in September 2016 and Hurricane Matthew in October 2016. Hurricane Matthew resulted in damage in much of FPL's service territory and caused approximately 1.2 million of FPL's customers to lose electrical service. Damage to FPL property was primarily limited to the transmission and distribution systems. Storm restoration costs eligible for recovery for both events totaled approximately $315 million, the majority of which relates to Hurricane Matthew. Prior to these storms, FPL's storm and property insurance reserve had the capacity to absorb approximately $112 million in additional storm restoration costs ($20 million of which was absorbed by Hurricane Hermine). At December 31, 2016, FPL's storm and property insurance reserve was fully depleted and storm restoration costs expected to be recoverable from customers exceeded the balance of the storm reserve that was reestablished in an FPSC financing order related to the issuance of the storm-recovery bonds was not initially reflectedby approximately $203 million. This deficiency has been deferred and recorded as a regulatory asset on NEE's and FPL's consolidated balance sheets. In February 2017, the FPSC approved FPL’s request to begin recovering eligible storm restoration costs over the reserve amount, plus approximately $117 million to replenish the reserve to the level authorized by the 2012 rate agreement. The recovery will take place through an interim surcharge that applies for a 12-month period starting March 1, 2017, with the amount collected subject to refund based on an FPSC prudence review.
The replenished reserve will not initially be reflected on NEE’s and FPL’s consolidated balance sheets because the associated regulatory asset diddoes not meet the specific recognition criteria under the accounting guidance for certain regulated entities. As a result, as the storm surcharge is billed to customers (which is recorded as operating revenues), the storm reserve will be recognized
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
as a regulatory liability as the storm-recovery charges are billed to customers and charged to depreciation and amortization expense in NEE'sNEE’s and FPL'sFPL’s consolidated statements of income. Furthermore, the storm reserve will be reduced as storm costs are reimbursed. As of December 31, 2013, FPL had the capacity to absorb up to approximately $121 million in future prudently incurred storm restoration costs without seeking recovery through a rate adjustment from the FPSC or filing a petition with the FPSC.
Impairment of Long-Lived Assets - NEE evaluates long-lived assets for impairment when events or changes in circumstances indicate that the carrying amount may not be recoverable. An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset. The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset's fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate. See Note 4 - Nonrecurring Fair Value Measurements and Note 6.
Goodwill and Other Intangible Assets - NEE's goodwill and other intangible assets are as follows:
|
| | | | | | | | | |
| | Weighted- Average Useful Lives | | December 31, |
| | | 2013 | | 2012 |
| | (years) | | (millions) |
| Goodwill: | | | | | |
| Merchant reporting unit | | | $ | 72 |
| | $ | 72 |
|
| Wind reporting unit | | | 49 |
| | 51 |
|
| Fiber-optic telecommunications reporting unit | | | 28 |
| | 28 |
|
| Total goodwill | | | $ | 149 |
| | $ | 151 |
|
| Other intangible assets not subject to amortization, primarily land easements | | | $ | 143 |
| | $ | 143 |
|
| Other intangible assets subject to amortization: | | | | | |
| Purchased power agreements | 20 | | $ | 70 |
| | $ | 72 |
|
| Customer lists | 5 | | 35 |
| | 39 |
|
| Other, primarily transmission and development rights, permits and licenses | 24 | | 98 |
| | 87 |
|
| Total | | | 203 |
| | 198 |
|
| Less accumulated amortization | | | (112 | ) | | (102 | ) |
| Total other intangible assets subject to amortization - net | | | $ | 91 |
| | $ | 96 |
|
|
| | | | | | | | | |
| | Weighted- Average Useful Lives | | December 31, |
| | | 2016 | | 2015 |
| | (years) | | (millions) |
| Goodwill (by reporting unit): | | | | | |
| NEER segment: | | | | | |
| Gas infrastructure, primarily Texas pipelines | | | $ | 641 |
| | $ | 635 |
|
| Customer supply | | | 72 |
| | 72 |
|
| Generation assets | | | 38 |
| | 43 |
|
| Other | | | 28 |
| | 28 |
|
| Total goodwill | | | $ | 779 |
| | $ | 778 |
|
| Other intangible assets not subject to amortization, primarily land easements | | | $ | 143 |
| | $ | 143 |
|
| Other intangible assets subject to amortization: | | | | | |
| Customer relationships associated with gas infrastructure | 41 | | $ | 700 |
| | $ | 720 |
|
| Purchased power agreements | 22 | | 444 |
| | 328 |
|
| Other, primarily transmission and development rights and customer lists | 19 | | 81 |
| | 136 |
|
| Total | | | 1,225 |
| | 1,184 |
|
| Accumulated amortization | | | (115 | ) | | (120 | ) |
| Total other intangible assets subject to amortization - net | | | $ | 1,110 |
| | $ | 1,064 |
|
NEE's goodwill relates to various acquisitions which were accounted for using the purchase method of accounting. Other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. ForAmortization expense was approximately $35 million, $17 million and $15 million for the years ended December 31, 2013, 20122016, 2015 and 2011, amortization expense was approximately $13 million, $14 million and $14 million,2014, respectively, and is expected to be approximately $12$31 million, $10$46 million, $6$39 million, $6$26 million and $5$19 million for 2014, 2015, 2016, 2017, 2018, 2019, 2020 and 2018,2021, respectively.
Goodwill and other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. Goodwill and other intangible assets not subject to amortization are assessed for impairment at least annually by applying a fair value-based analysis. Other intangible assets subject to amortization are periodically reviewed when impairment indicators are present to assess recoverability from future operations using undiscounted future cash flows.
Pension and Other Postretirement PlansPlan - NEE allocates net periodic pension benefit income to its subsidiaries based on the pensionable earnings of the subsidiaries' employees; net periodic supplemental executive retirement plan (SERP) benefit costs to its subsidiaries based upon actuarial calculations by participant; and postretirement health care and life insurance benefits (other benefits) net periodic benefit costs to its subsidiaries based upon the number of eligible employees at each subsidiary.
employees. Accounting guidance requires recognition of the funded status of benefit plansthe pension plan in the balance sheet, with changes in the funded status recognized in other comprehensive income within shareholders' equity in the year in which the changes occur. Since NEE is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, this
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
accounting guidance is reflected at NEE and not allocated to the subsidiaries. The portion of previously unrecognized actuarial gains and losses and prior service costs or credits and transition obligations that are estimated to be allocable to FPL as net periodic benefit (income) cost in future periods and that otherwise would be recorded in accumulated other comprehensive income (AOCI) are classified as regulatory assets and liabilities at NEE in accordance with regulatory treatment.
Stock-Based Compensation - NEE accounts for stock-based payment transactions based on grant-date fair value. Compensation costs for awards with graded vesting are recognized on a straight-line basis over the requisite service period for the entire award. See Note 10 - Stock-Based Compensation.
Income Taxes - Deferred income taxes are recognized on all significant temporary differences between the financial statement and tax bases of assets and liabilities.liabilities, and are presented as noncurrent on NEE's and FPL's consolidated balance sheets. In connection with the tax sharing agreement between NEE and certain of its subsidiaries, the income tax provision at each applicable subsidiary reflects the use of the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the subsidiary that generated the tax benefits. Any remaining consolidated
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
income tax benefits or expenses are recorded at the corporate level. Included in other regulatory assets and other regulatory liabilities on NEE's and FPL's consolidated balance sheets is the revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules. The net regulatory asset totaled $233289 million ($218266 million for FPL) and $206283 million ($195268 million for FPL) at December 31, 20132016 and 20122015, respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized.
NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. Production tax credits (PTCs) are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. FPL recognizes ITCs as a reduction to income tax expense over the depreciable life of the related energy property. At December 31, 2016 and 2015, FPL’s accumulated deferred ITCs were approximately $123 million and $3 million, respectively, and are included in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. NEE and FPL record a deferred income tax benefit created by the convertible ITCs on the difference between the financial statement and tax bases of renewable property. For NEER, this deferred income tax benefit is recorded in income tax expense in the year that the renewable property is placed in service. For FPL, this deferred income tax benefit is offset by a regulatory liability, which is amortized as a reduction of depreciation expense over the approximate lives of the related renewable property in accordance with the regulatory treatment. At December 31, 20132016 and 2012,2015, the net deferred income tax benefits associated with FPL's convertible ITCs were approximately $52$46 million and $54$48 million,, respectively, and are included in othernoncurrent regulatory assets and noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets.
A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets when it is more likely than not that such assets will not be realized. NEE recognizes interest income (expense) related to unrecognized tax benefits (liabilities) in interest income and interest expense, respectively, net of the amount deferred at FPL. At FPL, the offset to accrued interest receivable (payable) on income taxes is classified as a regulatory liability (regulatory asset) which will be amortized to income (expense) over a five-year period upon settlement in accordance with regulatory treatment. All tax positions taken by NEE in its income tax returns that are recognized in the financial statements must satisfy a more-likely-than-not threshold. NEE and its subsidiaries file income tax returns in the U.S. federal jurisdiction and various states, the most significant of which is Florida, and certain foreign jurisdictions. Federal tax liabilities, with the exception of certain refund claims, are effectively settled for all years prior to 2013. State and foreign tax liabilities, which have varied statutes of limitations regarding additional assessments, are generally effectively settled for years prior to 2009. At December 31, 2016, NEE had unrecognized tax benefits of approximately $40 million that, if disallowed, could impact the annual effective income tax rate. The amounts of unrecognized tax benefits and related interest accruals may change within the next 12 months; however, NEE and FPL do not expect these changes to have a significant impact on NEE’s or FPL’s financial statements. See Note 5.
Sale of Differential Membership Interests - Certain subsidiaries of NEER sold their Class B membership interest in entities that have ownership interests in wind and solar facilities, with generating capacity totaling approximately 3,541 megawatts (MW)6,847 MW and 374 MW, respectively, at December 31, 2013,2016, to third-party investors. In exchange for the cash received, the holders of the Class B membership interests will receive a portion of the economic attributes of the facilities, including income tax attributes, for variable periods. The transactions are not treated as a sale under the accounting rules and the proceeds received are deferred and recorded as a liability in deferral related to differential membership interests - VIEs on NEE's consolidated balance sheets. The deferred amount is being recognized in benefits associated with differential membership interests - net in NEE's consolidated statements of income as the Class B members receive their portion of the economic attributes. NEE continues to operate and manage the wind and solar facilities, and consolidates the entities that own the wind and solar facilities.
Variable Interest Entities (VIEs) - An entity is considered to be a VIE when its total equity investment at risk is not sufficient to permit the entity to finance its activities without additional subordinated financial support, or its equity investors, as a group, lack the characteristics of having a controlling financial interest. A reporting company is required to consolidate a VIE as its primary beneficiary when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. NEE and FPL evaluate whether an entity is a VIE whenever reconsideration events as defined by the accounting guidance occur. See Note 8.
2. Employee Retirement BenefitsLeases - In February 2016, the FASB issued an accounting standards update which requires, among other things, that lessees recognize a lease liability, initially measured at the present value of the future lease payments; and a right-of-use asset for all leases (with the exception of short-term leases). The standards update will be effective for NEE and FPL beginning January 1, 2019. Early adoption is permitted. Lessees and lessors must apply a modified retrospective approach for all leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. NEE and FPL are currently reviewing their portfolio of contracts and are in the process of determining the proper application of the standards update to these contracts in order to determine the impact the adoption will have on their consolidated financial statements, including timing of adoption.
Employee Benefit Plans and Other Postretirement PlanMerger Termination - NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees ofIn 2014, NEE and its subsidiaries. NEE also hasHawaiian Electric Industries, Inc. (HEI) entered into an Agreement and Plan of Merger (the HEI merger agreement) pursuant to which Hawaiian Electric Company, Inc. (HECO), HEI's wholly owned electric utility subsidiary, was to become a SERP, which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select groupwholly owned subsidiary of management and highly compensated employees. The impact of this SERP component is included within pension benefits inNEE. In July 2016, the following tables, and was not material to NEE's financial statements for the years ended December 31, 2013, 2012 and 2011. In addition to pension benefits, NEE sponsors a contributory postretirement plan for other benefits for retirees of NEE and its subsidiaries meeting certain eligibility requirements.Hawaii Public Utilities Commission issued an order dismissing
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
NEE's and HECO's merger application and, as a result, NEE terminated the HEI merger agreement. Pursuant to the terms of the HEI merger agreement, NEE paid HEI a termination fee of $90 million plus reimbursement to HEI for out-of-pocket expenses incurred in connection with the HEI merger agreement of $5 million, which is included in merger-related expenses in NEE's consolidated statements of income for the year ended December 31, 2016.
Assets and Liabilities Associated with Assets Held for Sale - In April 2016, a subsidiary of NEER completed the sale of its ownership interest in merchant natural gas generation facilities located in Texas with a total generating capacity of 2,884 MW for net cash proceeds of approximately $456 million, after transaction costs and working capital adjustments. A NEER affiliate continued to operate the facilities included in the sale through September 2016. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $254 million ($106 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2016 and is included in losses (gains) on disposal of assets - net. The carrying amounts of the major classes of assets and liabilities related to the facilities that were classified as held for sale on NEE's consolidated balance sheets as of December 31, 2015 primarily represent property, plant and equipment and the related long-term debt.
In 2016, a subsidiary of NEER initiated a plan, received internal authorization and completed the sale of its ownership interest in natural gas generation facilities located primarily in Pennsylvania with a total generating capacity of 840 MW for net cash proceeds of approximately $260 million, after transaction costs and working capital adjustments. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $191 million ($113 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2016 and is included in losses (gains) on disposal of assets - net.
In January 2017, an indirect wholly owned subsidiary of NEE completed the sale of its membership interests in its fiber-optic telecommunications business (FPL FiberNet) for net cash proceeds of approximately $1.1 billion, after repayment of $370 million of related long-term debt. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $1.1 billion (approximately $700 million after tax) will be recorded in NEE's consolidated statements of income during the three-months ended March 31, 2017. The carrying amounts of the major classes of assets and liabilities related to FPL FiberNet that were classified as held for sale on NEE's consolidated balance sheets as of December 31, 2016 primarily represent property, plant and equipment and the related long-term debt.
2. Employee Retirement Benefits
Employee Pension Plan and Other Benefits Plans - NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. NEE also has a supplemental executive retirement plan (SERP), which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees, and sponsors a contributory postretirement plan for other benefits for retirees of NEE and its subsidiaries meeting certain eligibility requirements. The total accrued benefit cost of the SERP and postretirement plans is approximately $325 million ($222 million for FPL) and $321 million ($230 million for FPL) at December 31, 2016 and 2015, respectively.
Pension Plan Assets, Benefit Obligations and Funded Status - The changes in assets, and benefit obligations and the funded status of the plans and the plans' funded statuspension plan are as follows:
|
| | | | | | | | | | | | | | | |
| | Pension Benefits | | Other Benefits |
| | 2013 | | 2012 | | 2013 | | 2012 |
| | (millions) |
| Change in plan assets: | | | | | | | |
| Fair value of plan assets at January 1 | $ | 3,385 |
| | $ | 3,122 |
| | $ | 26 |
| | $ | 28 |
|
| Actual return on plan assets | 455 |
| | 362 |
| | 2 |
| | 1 |
|
Employer contributions(a) | 1 |
| | 9 |
| | 28 |
| | 29 |
|
| Participant contributions | — |
| | — |
| | 5 |
| | 6 |
|
Benefit payments(a) | (149 | ) | | (108 | ) | | (35 | ) | | (38 | ) |
| Fair value of plan assets at December 31 | $ | 3,692 |
| | $ | 3,385 |
| | $ | 26 |
| | $ | 26 |
|
| Change in benefit obligation: | |
| | |
| | |
| | |
|
| Obligation at January 1 | $ | 2,372 |
| | $ | 2,123 |
| | $ | 397 |
| | $ | 427 |
|
| Service cost | 73 |
| | 65 |
| | 4 |
| | 5 |
|
| Interest cost | 95 |
| | 98 |
| | 14 |
| | 18 |
|
| Participant contributions | — |
| | — |
| | 5 |
| | 6 |
|
Plan amendments(b) | — |
| | 26 |
| | — |
| | (42 | ) |
Special termination benefits(c) | 46 |
| | — |
| | — |
| | — |
|
| Actuarial losses (gains) - net | (183 | ) | | 168 |
| | (31 | ) | | 21 |
|
Benefit payments(a) | (149 | ) | | (108 | ) | | (35 | ) | | (38 | ) |
Obligation at December 31(d) | $ | 2,254 |
| | $ | 2,372 |
| | $ | 354 |
| | $ | 397 |
|
| Funded status: | |
| | |
| | |
| | |
|
| Prepaid (accrued) benefit cost at NEE at December 31 | $ | 1,438 |
| | $ | 1,013 |
| | $ | (328 | ) | | $ | (371 | ) |
| Prepaid (accrued) benefit cost at FPL at December 31 | $ | 1,139 |
| | $ | 1,132 |
| | $ | (249 | ) | | $ | (261 | ) |
|
| | | | | | | |
| | 2016 | | 2015 |
| | (millions) |
| Change in pension plan assets: | | | |
| Fair value of plan assets at January 1 | $ | 3,563 |
| | $ | 3,698 |
|
| Actual return on plan assets | 217 |
| | (8 | ) |
| Benefit payments | (129 | ) | | (127 | ) |
| Fair value of plan assets at December 31 | $ | 3,651 |
| | $ | 3,563 |
|
| Change in pension benefit obligation: | |
| | |
|
| Obligation at January 1 | $ | 2,408 |
| | $ | 2,454 |
|
| Service cost | 62 |
| | 70 |
|
| Interest cost | 105 |
| | 97 |
|
| Plan amendments | (19 | ) | | — |
|
| Actuarial losses (gains) - net | 47 |
| | (86 | ) |
| Benefit payments | (129 | ) | | (127 | ) |
Obligation at December 31(a) | $ | 2,474 |
| | $ | 2,408 |
|
| Funded status: | |
| | |
|
| Prepaid pension benefit costs at NEE at December 31 | $ | 1,177 |
| | $ | 1,155 |
|
| Prepaid pension benefit costs at FPL at December 31 | $ | 1,301 |
| | $ | 1,243 |
|
_______________________________________________
| |
| (a) | Employer contributions and benefit payments include only those amounts contributed directly to, or paid directly from, plan assets. FPL's portion of contributions related to SERP benefits was less than $1 million and $7 million for 2013 and 2012, respectively. FPL's portion of contributions related to other benefits was $25 million and $27 million for 2013 and 2012, respectively.
|
| |
(b) | In 2012, certain active plan participants in the postretirement plan in other benefits elected a pension credit in lieu of retiree life insurance benefits. |
| |
(c) | Reflects an enhanced early retirement program offered in 2013 as part of an enterprise-wide cost savings initiative. |
| |
(d) | NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, for its pension plans at December 31, 20132016 and 20122015 was approximately $2,1972,439 million and $2,3052,366 million, respectively. |
NEE's and FPL's prepaid (accrued) benefit cost shown above are included on the consolidated balance sheets as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | Pension Benefits | | Other Benefits | | Pension Benefits | | Other Benefits |
| | 2013 | | 2012 | | 2013 | | 2012 | | 2013 | | 2012 | | 2013 | | 2012 |
| | | | | | | | (millions) | | | | | | |
| Prepaid benefit costs | $ | 1,456 |
| | $ | 1,031 |
| | $ | — |
| | $ | — |
| | $ | 1,142 |
| | $ | 1,135 |
| | $ | — |
| | $ | — |
|
| Accrued benefit cost included in other current liabilities | (5 | ) | | (2 | ) | | (26 | ) | | (28 | ) | | (2 | ) | | (2 | ) | | (22 | ) | | (23 | ) |
| Accrued benefit cost included in other liabilities | (13 | ) | | (16 | ) | | (302 | ) | | (343 | ) | | (1 | ) | | (1 | ) | | (227 | ) | | (238 | ) |
| Prepaid (accrued) benefit cost at December 31 | $ | 1,438 |
| | $ | 1,013 |
| | $ | (328 | ) | | $ | (371 | ) | | $ | 1,139 |
| | $ | 1,132 |
| | $ | (249 | ) | | $ | (261 | ) |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid (accrued)pension benefit costcosts are as follows:
|
| | | | | | | | | | | | | | | |
| | Pension Benefits | | Other Benefits |
| | 2013 | | 2012 | | 2013 | | 2012 |
| | | | (millions) | | |
| Components of AOCI: | | | | | | | |
| Unrecognized prior service benefit (cost) (net of $4 tax benefit, $5 tax benefit, $2 tax expense and $3 tax expense, respectively) | $ | (8 | ) | | $ | (9 | ) | | $ | 4 |
| | $ | 4 |
|
| Unrecognized gain (loss) (net of $18 tax expense, $39 tax benefit, $3 tax benefit and $6 tax benefit, respectively) | 30 |
| | (63 | ) | | (3 | ) | | (6 | ) |
| Total | $ | 22 |
| | $ | (72 | ) | | $ | 1 |
| | $ | (2 | ) |
|
| | | | | | | |
| | 2016 | | 2015 |
| | (millions) |
| Unrecognized prior service benefit (cost) (net of $2 tax expense and $1 tax benefit, respectively) | $ | 3 |
| | $ | (2 | ) |
| Unrecognized losses (net of $55 and $38 tax benefit, respectively) | (87 | ) | | (60 | ) |
| Total | $ | (84 | ) | | $ | (62 | ) |
NEE's unrecognized amounts included in regulatory assets (liabilities) yet to be recognized as components of net prepaid (accrued)pension benefit costcosts are as follows:
| | | | Regulatory
Assets (Liabilities)
(Pension) | | Regulatory
Assets (Liabilities)
(SERP and Other) | | | | | |
| | 2013 | | 2012 | | 2013 | | 2012 | 2016 | | 2015 |
| | (millions) | (millions) |
| Unrecognized prior service cost (benefit) | $ | 25 |
| | $ | 30 |
| | $ | (14 | ) | | $ | (16 | ) | $ | (4 | ) | | $ | 9 |
|
| Unrecognized losses (gains) | (98 | ) | | 154 |
| | 29 |
| | 58 |
| |
| Unrecognized losses | | 280 |
| | 232 |
|
| Total | $ | (73 | ) | | $ | 184 |
| | $ | 15 |
| | $ | 42 |
| $ | 276 |
| | $ | 241 |
|
The following table provides the weighted-average assumptions used to determine the benefit obligationsobligation for the plans.pension plan. These rates are used in determining net periodic benefit costincome in the following year.
| | | | Pension Benefits | | Other Benefits | 2016 | | 2015 |
| | 2013 | | 2012 | | 2013 | | 2012 | |
| Discount rate | 4.80 | % | | 4.00 | % | | 4.60 | % | | 3.75 | % | |
Discount rate(a) | | 4.09 | % | | 4.35 | % |
| Salary increase | 4.00 | % | | 4.00 | % | | 4.00 | % | | 4.00 | % | 4.10 | % | | 4.10 | % |
_________________________
With regard to the other benefits plan, currently the retiree cost sharing structure largely insulates NEE and FPL from the effects of any future increase in health care costs. An increase or decrease of one percentage point in assumed health care cost trend rates would have a corresponding effect on the other benefits accumulated obligation of approximately $2 million at December 31, 2013.
| |
| (a) | Beginning in 2017, NEE changed its method of estimating the interest cost component of net periodic benefit costs and will use a full yield curve approach by applying a specific spot rate along the yield curve rather than a single weighted-average discount rate. Such change is not expected to have a material impact on the pension and postretirement plans' net periodic benefit costs. |
NEE's investment policy for the pension plan recognizes the benefit of protecting the plan's funded status, thereby avoiding the necessity of future employer contributions. Its broad objectives are to achieve a high rate of total return with a prudent level of risk taking while maintaining sufficient liquidity and diversification to avoid large losses and preserve capital over the long term.
The NEE pension plan fund's current target asset allocation, which is expected to be reached over time, is 45% equity investments, 32% fixed income investments, 13% alternative investments and 10% convertible securities. The pension fund's investment strategy emphasizes traditional investments, broadly diversified across the global equity and fixed income markets, using a combination of different investment styles and vehicles. The pension fund's equity and fixed income holdings consist of both directly held securities as well as commingled investment arrangements such as common and collective trusts, pooled separate accounts, registered investment companies and limited partnerships. The pension fund's convertible security assets are principally direct holdings of convertible securities and includesinclude a convertible security oriented limited partnership. The pension fund's alternative investment holdings areinvestments consist primarily of private equity and real estate oriented investments in limited partnerships as well as absolute return oriented limited partnerships that use a broad range of investment strategies on a global basis.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The fair value measurements of NEE's pension plan assets by fair value hierarchy level are as follows:
| | | | December 31, 2013(a) | December 31, 2016(a) |
| | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) | | Total | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) | | Total |
| | (millions) | (millions) |
Equity securities(b) | $ | 1,028 |
| | $ | — |
| | $ | — |
| | $ | 1,028 |
| $ | 879 |
| | $ | 16 |
| | $ | 3 |
| | $ | 898 |
|
Equity commingled vehicles(c) | — |
| | 656 |
| | — |
| | 656 |
| — |
| | 845 |
| | — |
| | 845 |
|
| U.S. Government and municipal bonds | 115 |
| | 35 |
| | — |
| | 150 |
| 143 |
| | 12 |
| | — |
| | 155 |
|
Corporate debt securities(d) | — |
| | 348 |
| | — |
| | 348 |
| 3 |
| | 246 |
| | 1 |
| | 250 |
|
| Asset-backed securities | — |
| | 249 |
| | — |
| | 249 |
| — |
| | 124 |
| | — |
| | 124 |
|
Debt security commingled vehicles(e) | — |
| | 526 |
| | — |
| | 526 |
| — |
| | 22 |
| | — |
| | 22 |
|
Convertible securities | 46 |
| | 236 |
| | — |
| | 282 |
| 21 |
| | 277 |
| | — |
| | 298 |
|
Limited partnerships(f) | — |
| | 226 |
| | 227 |
| | 453 |
| |
| Total | $ | 1,189 |
| | $ | 2,276 |
| | $ | 227 |
| | $ | 3,692 |
| |
| Total investments in the fair value hierarchy | | $ | 1,046 |
| | $ | 1,542 |
| | $ | 4 |
| | 2,592 |
|
Total investments measured at net asset value(f) | | | | | | | | 1,059 |
|
| Total fair value of plan assets | | | | | | | | $ | 3,651 |
|
______________________
| |
| (a) | See Note 4 for discussion of fair value measurement techniques and inputs. |
| |
| (b) | Includes foreign investments of $337370 million. |
| |
| (c) | Includes foreign investments of $234261 million. |
| |
| (d) | Includes foreign investments of $67 million. $67 million. |
| |
| (e) | Includes foreign investments of $54 million and $145 million of short-term commingled vehicles. $31 million. |
| |
| (f) | Includes foreign investments of $104$282 million. Also includes fixed income oriented commingled investment arrangements of $244 million, convertible security oriented limited partnerships of $80 million and alternative investments of $129 million. Fair values have been estimated using net asset value (NAV) per share of the investments. Those investments subject to certain restrictions have been classified as Level 3. |
| | | | December 31, 2012(a) | December 31, 2015(a) |
| | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) | | Total | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) | | Total |
| | (millions) | (millions) |
Equity securities(b) | $ | 833 |
| | $ | — |
| | $ | — |
| | $ | 833 |
| $ | 910 |
| | $ | 21 |
| | $ | 1 |
| | $ | 932 |
|
Equity commingled vehicles(c) | — |
| | 590 |
| | — |
| | 590 |
| — |
| | 792 |
| | — |
| | 792 |
|
| U.S. Government and municipal bonds | 166 |
| | 50 |
| | — |
| | 216 |
| 110 |
| | 13 |
| | — |
| | 123 |
|
Corporate debt securities(d) | — |
| | 349 |
| | — |
| | 349 |
| 2 |
| | 277 |
| | 1 |
| | 280 |
|
| Asset-backed securities | — |
| | 273 |
| | — |
| | 273 |
| — |
| | 167 |
| | — |
| | 167 |
|
Debt security commingled vehicles(e) | — |
| | 589 |
| | — |
| | 589 |
| — |
| | 21 |
| | — |
| | 21 |
|
Convertible securities | — |
| | 261 |
| | — |
| | 261 |
| 16 |
| | 258 |
| | — |
| | 274 |
|
Limited partnerships(f) | — |
| | 134 |
| | 140 |
| | 274 |
| |
| Total | $ | 999 |
| | $ | 2,246 |
| | $ | 140 |
| | $ | 3,385 |
| |
| Total investments in the fair value hierarchy | | $ | 1,038 |
| | $ | 1,549 |
| | $ | 2 |
| | 2,589 |
|
Total investments measured at net asset value(f) | | | | | | | | 974 |
|
| Total fair value of plan assets | | | | | | | | $ | 3,563 |
|
______________________
| |
| (a) | See Note 4 for discussion of fair value measurement techniques and inputs. |
| |
| (b) | Includes foreign investments of $308384 million. |
| |
| (c) | Includes foreign investments of $204249 million. |
| |
| (d) | Includes foreign investments of $6668 million. |
| |
| (e) | Includes foreign investments of $60 million and $135 million of short-term commingled vehicles. $23 million. |
| |
| (f) | Includes foreign investments of $39$283 million. Also, includes fixed income oriented commingled investment arrangements of $90 million, convertible security oriented limited partnerships of $77 million and alternative investments of $107 million. Fair values have been estimated using NAV per share of the investments. Those investments subject to certain restrictions have been classified as Level 3. |
With regard to its other benefits plan, NEE's policy is to fund claims as incurred during the year through NEE contributions, participant contributions and plan assets. The other benefits plan's assets are invested with a focus on assuring the availability of funds to pay benefits while maintaining sufficient diversification to avoid large losses and preserve capital. The other benefits plan's fund has a strategic asset allocation that targets a mix of 60% equity investments and 40% fixed income investments. The fund's investment strategy consists of traditional investments, diversified across the global equity and fixed income markets. The fund's equity and fixed income investments are comprised of assets classified as commingled vehicles such as common and collective trusts, pooled separate accounts, registered investment companies or other forms of pooled investment arrangements.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The fair value measurements of NEE's other benefits plan assets at December 31, 2013 and 2012 are substantially all Level 2 and include approximately $18 million and $18 million of equity commingled vehicles (of which $5 million and $4 million were foreign investments) and $6 million and $7 million of debt security commingled vehicles, respectively.
Expected Cash Flows - NEE anticipates paying approximately $26 million for eligible retiree medical expenses on behalf of the other benefits plan during 2014.
The following table provides information about benefit payments expected to be paid by the plans, net of government drug subsidy,pension plan for each of the following calendar years:
years (in millions):
|
| | | | | | | |
| | Pension Benefits | | Other Benefits |
| | (millions) |
| 2014 | $ | 275 |
| | $ | 34 |
|
| 2015 | $ | 139 |
| | $ | 31 |
|
| 2016 | $ | 146 |
| | $ | 29 |
|
| 2017 | $ | 150 |
| | $ | 30 |
|
| 2018 | $ | 155 |
| | $ | 29 |
|
| 2019 - 2023 | $ | 817 |
| | $ | 132 |
|
|
| | | |
| 2017 | $ | 155 |
|
| 2018 | $ | 156 |
|
| 2019 | $ | 160 |
|
| 2020 | $ | 163 |
|
| 2021 | $ | 170 |
|
| 2022 - 2026 | $ | 879 |
|
Net Periodic (Income) Cost - The components of net periodic benefit (income) cost for the plans are as follows:
| | | | Pension Benefits | | Other Benefits | Pension Benefits | | Postretirement Benefits |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 | | 2016 | | 2015 | | 2014 |
| | | | | | (millions) | | | | | | | (millions) | | |
| Service cost | $ | 73 |
| | $ | 65 |
| | $ | 64 |
| | $ | 4 |
| | $ | 5 |
| | $ | 6 |
| $ | 62 |
| | $ | 70 |
| | $ | 61 |
| | $ | 2 |
| | $ | 3 |
| | $ | 3 |
|
| Interest cost | 95 |
| | 98 |
| | 98 |
| | 14 |
| | 18 |
| | 21 |
| 105 |
| | 97 |
| | 101 |
| | 13 |
| | 13 |
| | 16 |
|
| Expected return on plan assets | (237 | ) | | (238 | ) | | (238 | ) | | (1 | ) | | (2 | ) | | (2 | ) | (260 | ) | | (253 | ) | | (241 | ) | | (1 | ) | | (1 | ) | | (1 | ) |
| Amortization of transition obligation | — |
| | — |
| | — |
| | — |
| | 1 |
| | 3 |
| |
| Amortization of prior service cost (benefit) | 7 |
| | 5 |
| | (3 | ) | | (2 | ) | | (1 | ) | | — |
| 1 |
| | 1 |
| | 5 |
| | (2 | ) | | (3 | ) | | (3 | ) |
| Amortization of losses | 2 |
| | — |
| | — |
| | 2 |
| | — |
| | — |
| — |
| | — |
| | — |
| | — |
| | 2 |
| | — |
|
| SERP settlements | — |
| | 3 |
| | — |
| | — |
| | — |
| | — |
| |
| Special termination benefits | 46 |
| | — |
| | — |
| | — |
| | — |
| | — |
| |
| Net periodic benefit (income) cost at NEE | $ | (14 | ) | | $ | (67 | ) | | $ | (79 | ) | | $ | 17 |
| | $ | 21 |
| | $ | 28 |
| |
| Net periodic benefit (income) cost at FPL | $ | (5 | ) | | $ | (43 | ) | | $ | (51 | ) | | $ | 13 |
| | $ | 16 |
| | $ | 21 |
| |
| Net periodic (income) cost at NEE | | $ | (92 | ) | | $ | (85 | ) | | $ | (74 | ) | | $ | 12 |
| | $ | 14 |
| | $ | 15 |
|
| Net periodic (income) cost at FPL | | $ | (58 | ) | | $ | (55 | ) | | $ | (47 | ) | | $ | 9 |
| | $ | 11 |
| | $ | 11 |
|
Other Comprehensive Income - The components of net periodic benefit income (cost) recognized in OCI for the planspension plan are as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Benefits | | Other Benefits |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 |
| | | | | | (millions) | | | | |
| Prior service benefit (cost) (net of $3 tax benefit, $4 tax expense and $2 tax benefit, respectively) | $ | — |
| | $ | (6 | ) | | $ | — |
| | $ | — |
| | $ | 7 |
| | $ | (3 | ) |
| Net gains (losses) (net of $58 tax expense, $16 tax benefit, $32 tax benefit, $3 tax expense, $3 tax benefit, and $2 tax expense, respectively) | 91 |
| | (25 | ) | | (45 | ) | | 4 |
| | (5 | ) | | 3 |
|
| Amortization of prior service benefit (cost) | 2 |
| | 1 |
| | (1 | ) | | — |
| | — |
| | — |
|
| Amortization of transition obligation | — |
| | — |
| | — |
| | — |
| | — |
| | 1 |
|
| Total | $ | 93 |
| | $ | (30 | ) | | $ | (46 | ) | | $ | 4 |
| | $ | 2 |
| | $ | 1 |
|
|
| | | | | | | | | | | |
| | 2016 | | 2015 | | 2014 |
| | (millions) |
| Prior service benefit (net of $3 and $3 tax expense, respectively) | $ | 4 |
| | $ | — |
| | $ | 4 |
|
| Net losses (net of $16, $27 and $29 tax benefit, respectively) | (26 | ) | | (44 | ) | | (45 | ) |
| Amortization of prior service benefit | — |
| | — |
| | 1 |
|
| Total | $ | (22 | ) | | $ | (44 | ) | | $ | (40 | ) |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Regulatory Assets (Liabilities) - The components of net periodic benefit (income) cost recognized during the year in regulatory assets (liabilities) for the planspension plan are as follows:
|
| | | | | | | | | | | | | | | |
| | Regulatory Assets (Liabilities) (Pension) | | Regulatory Assets (Liabilities) (SERP and Other) |
| | 2013 | | 2012 | | 2013 | | 2012 |
| | (millions) |
| Prior service cost (benefit) | $ | — |
| | $ | 17 |
| | $ | — |
| | $ | (29 | ) |
| Unrecognized losses (gains) | (252 | ) | | 1 |
| | (26 | ) | | 16 |
|
| Amortization of prior service cost (benefit) | (4 | ) | | (3 | ) | | 1 |
| | — |
|
| Amortization of transition obligation | — |
| | — |
| | — |
| | (1 | ) |
| Amortization of unrecognized losses | (1 | ) | | — |
| | (2 | ) | | (3 | ) |
| Total | $ | (257 | ) | | $ | 15 |
| | $ | (27 | ) | | $ | (17 | ) |
|
| | | | | | | |
| | 2016 | | 2015 |
| | (millions) |
| Prior service benefit | $ | (12 | ) | | $ | — |
|
| Unrecognized losses | 48 |
| | 104 |
|
| Amortization of prior service benefit | (1 | ) | | (1 | ) |
| Total | $ | 35 |
| | $ | 103 |
|
The weighted-average assumptions used to determine net periodic benefit (income) costincome for the planspension plan are as follows:
| | | | Pension Benefits | | Other Benefits | | | | | | |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| Discount rate | 4.00 | % | | 4.65 | % | | 5.00 | % | | 3.75 | % | | 4.53 | % | (a) | 5.25 | % | 4.35 | % | | 3.95 | % | | 4.80 | % |
| Salary increase | 4.00 | % | | 4.00 | % | | 4.00 | % | | 4.00 | % | | 4.00 | % | | 4.00 | % | 4.10 | % | | 4.10 | % | | 4.00 | % |
Expected long-term rate of return(b) | 7.75 | % | | 7.75 | % | | 7.75 | % | | 7.75 | % | | 8.00 | % | | 8.00 | % | |
Expected long-term rate of return(a)(b) | | 7.35 | % | | 7.35 | % | | 7.75 | % |
______________________
| |
| (a) | Reflects a mid-year rate change due to cost remeasurement resulting from a plan amendment. |
| |
(b) | In developing the expected long-term rate of return on assets assumption for its plans,pension plan, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. NEE considered different models, capital market return assumptions and historical returns for a portfolio with an equity/bond asset mix similar to its funds.pension fund. NEE also considered its funds'pension fund's historical compounded returns. |
| |
| (b) | In 2016 and 2015, an expected long-term rate of return of 7.75% is presented net of investment management fees. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Employee Contribution PlansPlan - NEE offers an employee retirement savings plansplan which allowallows eligible participants to contribute a percentage of qualified compensation through payroll deductions. NEE makes matching contributions to participants' accounts. Defined contribution expense pursuant to these plansthis plan was approximately $4652 million, $4463 million and $4259 million for NEE ($3032 million, $2940 million and $2837 million for FPL) for the years ended December 31, 20132016, 20122015 and 20112014, respectively. See Note 10 - Employee Stock Ownership Plan.
3. 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 primarily with outstanding and forecastedexpected future debt issuances and borrowings, 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 over-the-counter (OTC) markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge the commodity price risk associated with the fuel requirements of the assets, where applicable, as well as to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in the energy markets based on differences between actual forward market levels and management's view of fundamental market conditions, including supply/demand imbalances, changes in traditional flows of energy, changes in short- and long-term weather patterns and anticipated regulatory and legislative outcomes. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel and purchased power cost recovery clause (fuel clause). 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 equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the 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 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,In January 2016, NEE discontinued hedge accounting is only applied where specific criteria are metfor its cash flow and it is practicablefair value hedges related 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 changeand, therefore, all changes in the derivatives' fair value, ofas well as 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 thetransaction gain or loss on a derivative instrument designated as a cash flow hedge is reported as a componentforeign denominated debt, are recognized in interest expense in NEE's consolidated statements of OCI and isincome. In addition, for the year ended December 31, 2016, NEE reclassified into earnings in the period(s) during which the transaction being hedged affects earnings or whenapproximately $18 million ($11 million after tax), respectively, from AOCI to interest expense primarily because it becomesbecame probable that a forecastedrelated future 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 13 - Spain Solar Projects). At December 31, 2013,2016, NEE's AOCI included amounts related to the discontinued interest rate cash flow hedges with expiration dates through June 2031March 2035 and foreign currency cash flow hedges with expiration dates through September 2030. Approximately $64$80 million of net losses included in AOCI at December 31, 20132016 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.
In 2011, subsidiaries of NEER sold their ownership interests in five natural gas-fired generating plants. See Note 4 - Nonrecurring Fair Value Measurements. Certain of the plants had hedged their exposure to interest rate and commodity price fluctuations by entering into derivative contracts. Because the plants were sold to a third party, it became probable that the future hedged transactions would not occur. Therefore, NEE was required to reclassify any gains or losses in AOCI related to those hedges to earnings. During the year ended December 31, 2011, NEE reclassified approximately $21 million of net losses to earnings, with $30 million of losses recorded in loss on sale of natural gas-fired generating assets and $9 million of gains recorded in other - net.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Fair Value of Derivative Instruments - The tables below present NEE's and FPL's gross derivative positions at December 31, 20132016 and December 31, 2012,2015, as required by disclosure rules. However, the majority of the underlying contracts are subject to master netting agreements and generally would not be contractually settled on a gross basis. Therefore, the tables below also present the derivative positions on a net basis, which reflect the offsetting of positions of certain transactions within the portfolio, the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral (see Note 4 - Recurring Fair Value Measurements for netting information), as well as the location of the net derivative position on the consolidated balance sheets.
| | | | December 31, 2013 | December 31, 2016 |
| | Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis | | Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis | | Total Derivatives Combined - Net Basis | Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis | | Fair Values of Derivatives Not
Designated as Hedging
Instruments for Accounting
Purposes - Net Basis |
| | Assets | | Liabilities | | Assets | | Liabilities | | Assets | | Liabilities | Assets | | Liabilities | | Assets | | Liabilities |
| | (millions) | (millions) |
| NEE: | | | | | | | | | | | | | | | | | | |
| Commodity contracts | $ | — |
| | $ | — |
| | $ | 4,543 |
| | $ | 3,633 |
| | $ | 1,571 |
| | $ | 940 |
| $ | 4,590 |
|
| $ | 2,968 |
| | $ | 1,938 |
|
| $ | 483 |
|
| Interest rate contracts | 89 |
| | 127 |
| | 1 |
| | 93 |
| | 90 |
| | 220 |
| 288 |
|
| 284 |
| | 296 |
|
| 292 |
|
| Foreign currency swaps | — |
| | 50 |
| | — |
| | 101 |
| | — |
| | 151 |
| |
| Foreign currency contracts | | 1 |
|
| 106 |
| | 1 |
|
| 106 |
|
| Total fair values | $ | 89 |
| | $ | 177 |
| | $ | 4,544 |
| | $ | 3,827 |
| | $ | 1,661 |
| | $ | 1,311 |
| $ | 4,879 |
|
| $ | 3,358 |
| | $ | 2,235 |
|
| $ | 881 |
|
| | | | | | | | | | | | | | | | |
|
|
|
| FPL: | | | | | | | | | | | | | | | |
|
|
|
| Commodity contracts | $ | — |
| | $ | — |
| | $ | 55 |
| | $ | 9 |
| | $ | 48 |
| | $ | 2 |
| $ | 212 |
|
| $ | 4 |
| | $ | 209 |
|
| $ | 1 |
|
| | | | | | | | | | | | | | | | | | | |
| Net fair value by NEE balance sheet line item: | | | | | | | | | | | | | | | | | | |
Current derivative assets(a) | | | | | | | | | $ | 498 |
| | | | | | | $ | 885 |
|
|
|
Noncurrent derivative assets(b) | | | | | | | | | 1,163 |
| | | | | | | 1,350 |
|
|
|
| Current derivative liabilities | | | | | | | | | | | $ | 838 |
| | | | |
|
|
| $ | 404 |
|
| Noncurrent derivative liabilities | | | | | | | | | | | 473 |
| | | | |
|
|
| 477 |
|
| Total derivatives | | | | | | | | | $ | 1,661 |
| | $ | 1,311 |
| | | | | $ | 2,235 |
|
| $ | 881 |
|
| | | | | | | | | | | | | | | | | | | |
| Net fair value by FPL balance sheet line item: | | | | | | | | | | | | | | | | | | |
| Current other assets | | | | | | | | | $ | 48 |
| | | |
| Current other liabilities | | | | | | | | | | | $ | 1 |
| |
| Noncurrent other liabilities | | | | | | | | | | | 1 |
| |
| Current derivative assets | | | | | | $ | 209 |
|
|
|
| Current derivative liabilities | | | | | |
|
| $ | 1 |
|
| Total derivatives | | | | | | | | | $ | 48 |
| | $ | 2 |
| | | | | $ | 209 |
|
| $ | 1 |
|
______________________
| |
| (a) | Reflects the netting of approximately $18196 million in margin cash collateral received from counterparties. |
| |
| (b) | Reflects the netting of approximately $9871 million in margin cash collateral received from counterparties. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
| | | | December 31, 2012 | December 31, 2015 |
| | Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis | | Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis | | Total Derivatives Combined - Net Basis | Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis | | Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis | | Total Derivatives Combined - Net Basis |
| | Assets | | Liabilities | | Assets | | Liabilities | | Assets | | Liabilities | Assets | | Liabilities | | Assets | | Liabilities | | Assets | | Liabilities |
| | (millions) | (millions) |
| NEE: | | | | | | | | | | | | | | | | | | | | | | |
| Commodity contracts | $ | — |
| | $ | — |
| | $ | 4,232 |
| | $ | 3,312 |
| | $ | 1,361 |
| | $ | 564 |
| $ | — |
| | $ | — |
| | $ | 5,906 |
| | $ | 4,580 |
| | $ | 1,937 |
| | $ | 982 |
|
| Interest rate contracts | 76 |
| | 387 |
| | — |
| | — |
| | 76 |
| | 387 |
| 33 |
| | 155 |
| | 2 |
| | 160 |
| | 34 |
| | 319 |
|
| Foreign currency swaps | — |
| | 33 |
| | — |
| | 33 |
| | — |
| | 66 |
| |
| Foreign currency contracts | | — |
| | 132 |
| | — |
| | — |
| | — |
| | 127 |
|
| Total fair values | $ | 76 |
| | $ | 420 |
| | $ | 4,232 |
| | $ | 3,345 |
| | $ | 1,437 |
| | $ | 1,017 |
| $ | 33 |
| | $ | 287 |
| | $ | 5,908 |
| | $ | 4,740 |
| | $ | 1,971 |
| | $ | 1,428 |
|
| | | | | | | | | | | | | | | | | | | | | | | |
| FPL: | | | | | | | | | | | | | | | | | | | | | | |
| Commodity contracts | $ | — |
| | $ | — |
| | $ | 17 |
| | $ | 32 |
| | $ | 5 |
| | $ | 20 |
| $ | — |
| | $ | — |
| | $ | 7 |
| | $ | 225 |
| | $ | 4 |
| | $ | 222 |
|
| | | | | | | | | | | | | | | | | | | | | | | |
| Net fair value by NEE balance sheet line item: | | | | | | | | | | | | | | | | | | | | | | |
Current derivative assets(a) | | | | | | | | | $ | 517 |
| | | | | | | | | | | $ | 712 |
| | |
| Assets held for sale | | | | | | | | | | 57 |
| | |
Noncurrent derivative assets(b) | | | | | | | | | 920 |
| | | | | | | | | | | 1,202 |
| | |
Current derivative liabilities(c) | | | | | | | | | | | $ | 430 |
| | | | | | | | | | | $ | 882 |
|
| Noncurrent derivative liabilities | | | | | | | | | | | 587 |
| |
| Liabilities associated with assets held for sale | | | | | | | | | | | | 16 |
|
Noncurrent derivative liabilities(d) | | | | | | | | | | | | 530 |
|
| Total derivatives | | | | | | | | | $ | 1,437 |
| | $ | 1,017 |
| | | | | | | | | $ | 1,971 |
| | $ | 1,428 |
|
| | | | | | | | | | | | | | | | | | | | | | | |
| Net fair value by FPL balance sheet line item: | | | | | | | | | | | | | | | | | | | | | | |
| Current other assets | | | | | | | | | $ | 4 |
| | | |
| Current derivative assets | | | | | | | | | | $ | 3 |
| | |
| Noncurrent other assets | | | | | | | | | 1 |
| | | | | | | | | | | 1 |
| | |
| Current other liabilities | | | | | | | | | | | $ | 20 |
| |
| Current derivative liabilities | | | | | | | | | | | | $ | 222 |
|
| Total derivatives | | | | | | | | | $ | 5 |
| | $ | 20 |
| | | | | | | | | $ | 4 |
| | $ | 222 |
|
______________________
| |
| (a) | Reflects the netting of approximately $43279 million in margin cash collateral received from counterparties. |
| |
| (b) | Reflects the netting of approximately $159151 million in margin cash collateral received from counterparties. |
| |
| (c) | Reflects the netting of approximately $7946 million in margin cash collateral providedpaid to counterparties. |
| |
| (d) | Reflects the netting of approximately $13 million in margin cash collateral paid to counterparties. |
At December 31, 20132016 and 2012,2015, NEE had approximately $245 million and $3027 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 consolidated balance sheets. Additionally, at December 31, 20132016 and 2012,2015, NEE had approximately $42129 million and $49116 million (none at FPL), respectively, in margin cash collateral providedpaid to counterparties that was not offset against derivative assets or liabilities in the above presentation. These amounts are included in current other assets on NEE's consolidated balance sheets.
Income Statement Impact of Derivative Instruments - Gains (losses)Losses related to NEE's cash flow hedges, which were previously designated as hedging instruments, are recorded in NEE's consolidated financial statements (none at FPL) as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Year Ended December 31, 2013 | | Year Ended December 31, 2012 | | Year Ended December 31, 2011 |
| | | Interest Rate Contracts | | Foreign Currency Swaps | | Total | | Commodity Contracts | | Interest Rate Contracts | | Foreign Currency Swaps | | Total | | Commodity Contracts | | Interest Rate Contracts | | Foreign Currency Swap | | Total |
| | (millions) |
| Gains (losses) recognized in OCI | | $ | 150 |
| | $ | (21 | ) | | $ | 129 |
| | $ | — |
| | $ | (131 | ) | | $ | (30 | ) | | $ | (161 | ) | | $ | — |
| | $ | (383 | ) | | $ | (17 | ) | | $ | (400 | ) |
Gains (losses) reclassified from AOCI to net income(a) | | $ | (61 | ) | | $ | (44 | ) | (b) | $ | (105 | ) | | $ | 8 |
| | $ | (56 | ) | | $ | (21 | ) | (c) | $ | (69 | ) | | $ | 41 |
| | $ | (76 | ) | | $ | 1 |
| (b) | $ | (34 | ) |
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | Year Ended
December 31, 2015 | | Year Ended
December 31, 2014 |
| | Interest Rate Contracts | | Foreign Currency Contracts | | Total | | Interest Rate Contracts | | Foreign Currency Contracts | | Total |
| | |
| Losses recognized in OCI | $ | (113 | ) | | $ | (12 | ) | | $ | (125 | ) | | $ | (132 | ) | | $ | (89 | ) | | $ | (221 | ) |
| Losses reclassified from AOCI to net income | $ | (73 | ) | (a) | $ | (15 | ) | (b) | $ | (88 | ) | | $ | (77 | ) | (a) | $ | (78 | ) | (b) | $ | (155 | ) |
______________________
| |
| (a) | Included in operating revenues for commodity contracts and interest expense for interest rate contracts. 2011 excludes approximately $21 million of net losses related to the discontinuance of certain cash flow hedges. See further discussion above. expense. |
| |
| (b) | LossFor 2015 and 2014, losses of approximately $4$11 million is and $8 million, respectively, are included in interest expense and the balance isbalances are included in other - net.
|
| |
(c) | Loss of approximately $3 million is included in interest expense and the balance is included in other - net.
|
For the year ended December 31, 2013, NEE recorded a loss of approximately $65 million on fair value hedges which resulted in a corresponding decrease in the related debt. For the years ended December 31, 2012 and 2011, NEE recorded gains of
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
approximately $44 million and $28 million, respectively, on fair value hedges which resulted in corresponding increases in the related debt.
Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's consolidated statements of income as follows:
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| | (millions) | (millions) |
Commodity contracts:(a) | | | | | | | | | | |
| Operating revenues | $ | 76 |
| | $ | 171 |
| | $ | 473 |
| $ | 459 |
| | $ | 932 |
| | $ | 420 |
|
| Fuel, purchased power and interchange | — |
| | 38 |
| | — |
| (1 | ) |
| 8 |
|
| 1 |
|
| Foreign currency swap - other - net | (72 | ) | | (60 | ) | | 22 |
| |
Interest rate contracts(b) | 3 |
| | — |
| | (11 | ) | |
| Foreign currency contracts - interest expense | | 14 |
| | — |
| | — |
|
| Foreign currency contracts - other - net | | (1 | ) | | — |
| | (1 | ) |
| Interest rate contracts - interest expense | | 181 |
| | 8 |
| | (64 | ) |
| Losses reclassified from AOCI to interest expense: | | | | | | |
| Interest rate contracts | | (90 | ) | | — |
| | — |
|
| Foreign currency contracts | | (11 | ) | | — |
| | — |
|
| Total | $ | 7 |
| | $ | 149 |
| | $ | 484 |
| $ | 551 |
| | $ | 948 |
| | $ | 356 |
|
______________________
| |
| (a) | For the year ended December 31, 2013, FPL recorded approximately $81 million of gains related to commodity contracts as regulatory liabilities on its consolidated balance sheet. For the years ended December 31, 20122016, 2015 and 2011,2014, FPL recorded gains (losses) of approximately $177203 million, $(326) million and $646(289) million of losses, respectively, related to commodity contracts as regulatory assetsliabilities (assets) on its consolidated balance sheets. |
| |
(b) | Included in interest expense for 2013 and other-net for 2011. |
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 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:
| | | | | December 31, 2013 | | December 31, 2012 | | December 31, 2016 | | December 31, 2015 |
| Commodity Type | | NEE | | FPL | | NEE | | FPL | | NEE | | FPL | | NEE | | FPL |
| | | (millions) | | (millions) |
| Power | | (276 | ) | | MWh(a) | | — |
| | (77 | ) | | MWh(a) | | — |
| | | (84 | ) | | MWh(a) | | — |
| | (112 | ) | | MWh(a) | | — |
| |
| Natural gas | | 1,140 |
| | MMBtu(b) | | 674 |
| | MMBtu(b) | | 1,293 |
| | MMBtu(b) | | 894 |
| | MMBtu(b) | | 1,002 |
| | MMBtu(b) | | 618 |
| | MMBtu(b) | | 1,321 |
| | MMBtu(b) | | 833 |
| | MMBtu(b) |
| Oil | | (10 | ) | | barrels | | — |
| | (8 | ) | | barrels | | — |
| | | (7 | ) | | barrels | | — |
| | (9 | ) | | barrels | | — |
| |
______________________
| |
| (b) | One million British thermal units |
At December 31, 20132016 and 2012,2015, NEE had interest rate contracts with a notional amountamounts totaling approximately $6.515.1 billion and $7.3$8.3 billion, respectively, and foreign currency swapscontracts with a notional amountamounts totaling approximately $662705 million. and $715 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 December 31, 20132016 and 2012,2015, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $2.11.3 billion ($95 million for FPL) and $1.8$2.2 billion ($32224 million for FPL), respectively.
If the credit-risk-related contingent features underlying these derivative 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 derivative 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 $400110 million ($20 millionnone at FPL) as of December 31, 2013 and $400$165 million ($20 million at FPL) as of December 31, 2012.2016 and 2015, respectively. 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 $2.3 billion990 million ($0.4 billion10 million at FPL) and $2.3$1.4 billion ($0.5 billion185 million at FPL) as of December 31, 20132016 and 2012,2015, respectively. Some derivative 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
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
triggered, applicable NEE subsidiaries could be required to post additional collateral of up to approximately $800225 million ($150115 million at FPL) and $700$270 million ($100120 million at FPL) as of December 31, 20132016 and 2012,2015, respectively.
Collateral related to derivatives may be posted in the form of cash or credit support in the normal course of business. At December 31, 2013 and 2012,2016, applicable NEE subsidiaries have posted approximately $210 million (none at FPL) and $150$1 million (none at FPL), respectively, in cash and $30 million (none at FPL) in the form of letters of credit which could be applied toward the collateral requirements described above. At December 31, 2015, applicable NEE subsidiaries have posted approximately $123 million ($3 million at FPL) 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.
4. 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 -and Restricted Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.- NEE primarily holds investments in money market funds. The fair value of these funds is calculatedestimated using a market approach based on current observable 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 a combination of market and income approaches utilizing prices observed on commodities exchanges and in the over-the-counterOTC 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 over-the-counterOTC 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
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value.
NEE uses interest rate contracts and foreign currency swapscontracts to mitigate and adjust interest rate and foreign currency exchange exposure related primarily to certain outstanding and forecastedexpected future 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 an income approach based on a discounted cash flows valuation technique based onutilizing 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:
| | | | December 31, 2013 | | December 31, 2016 | |
| | Level 1 | | Level 2 | | Level 3 | | Netting(a) | | Total | | Level 1 | | Level 2 | | Level 3 | | Netting(a) | | Total | |
| | (millions) | | (millions) | |
| Assets: | | | | | | | | | | | | | | | | | | | | |
| Cash equivalents: | | | | | | | | | | | |
Cash equivalents and restricted cash:(b) | | | | | | | | | | | |
| NEE - equity securities | $ | 20 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 20 |
| | $ | 982 |
| | $ | — |
| | $ | — |
| | | | $ | 982 |
| |
Special use funds:(b) | | | | | | | | | | | |
| FPL - equity securities | | $ | 120 |
| | $ | — |
| | $ | — |
| | | | $ | 120 |
| |
Special use funds:(c) | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Equity securities | $ | 1,170 |
| | $ | 1,336 |
| (c) | $ | — |
| | $ | — |
| | $ | 2,506 |
| | $ | 1,410 |
| | $ | 1,503 |
| (d) | $ | — |
| | | | $ | 2,913 |
| |
| U.S. Government and municipal bonds | $ | 647 |
| | $ | 180 |
| | $ | — |
| | $ | — |
| | $ | 827 |
| | $ | 296 |
| | $ | 170 |
| | $ | — |
| | | | $ | 466 |
| |
| Corporate debt securities | $ | — |
| | $ | 597 |
| | $ | — |
| | $ | — |
| | $ | 597 |
| | $ | 1 |
| | $ | 763 |
| | $ | — |
| | | | $ | 764 |
| |
| Mortgage-backed securities | $ | — |
| | $ | 479 |
| | $ | — |
| | $ | — |
| | $ | 479 |
| | $ | — |
| | $ | 498 |
| | $ | — |
| | | | $ | 498 |
| |
| Other debt securities | $ | 16 |
| | $ | 44 |
| | $ | — |
| | $ | — |
| | $ | 60 |
| | $ | — |
| | $ | 81 |
| | $ | — |
| | | | $ | 81 |
| |
| FPL: | | | | | | | | | | | | | | | | | | | | |
| Equity securities | $ | 291 |
| | $ | 1,176 |
| (c) | $ | — |
| | $ | — |
| | $ | 1,467 |
| | $ | 373 |
| | $ | 1,372 |
| (d) | $ | — |
| | | | $ | 1,745 |
| |
| U.S. Government and municipal bonds | $ | 584 |
| | $ | 154 |
| | $ | — |
| | $ | — |
| | $ | 738 |
| | $ | 221 |
| | $ | 141 |
| | $ | — |
| | | | $ | 362 |
| |
| Corporate debt securities | $ | — |
| | $ | 421 |
| | $ | — |
| | $ | — |
| | $ | 421 |
| | $ | — |
| | $ | 547 |
| | $ | — |
| | | | $ | 547 |
| |
| Mortgage-backed securities | $ | — |
| | $ | 401 |
| | $ | — |
| | $ | — |
| | $ | 401 |
| | $ | — |
| | $ | 384 |
| | $ | — |
| | | | $ | 384 |
| |
| Other debt securities | $ | 16 |
| | $ | 30 |
| | $ | — |
| | $ | — |
| | $ | 46 |
| | $ | — |
| | $ | 70 |
| | $ | — |
| | | | $ | 70 |
| |
| Other investments: | | | | | | | | | | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Equity securities | $ | 51 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 51 |
| | $ | 26 |
| | $ | 9 |
| | $ | — |
| | | | $ | 35 |
| |
| Debt securities | $ | 11 |
| | $ | 107 |
| | $ | — |
| | $ | — |
| | $ | 118 |
| | $ | 8 |
| | $ | 153 |
| | $ | — |
| | | | $ | 161 |
| |
| Derivatives: | | | | | | | | | | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Commodity contracts | $ | 1,368 |
| | $ | 2,106 |
| | $ | 1,069 |
| | $ | (2,972 | ) | | $ | 1,571 |
| (d) | $ | 1,563 |
| | $ | 1,827 |
| | $ | 1,200 |
| | $ | (2,652 | ) | | $ | 1,938 |
| (e) |
| Interest rate contracts | $ | — |
| | $ | 90 |
| | $ | — |
| | $ | — |
| | $ | 90 |
| (d) | $ | — |
| | $ | 285 |
| | $ | 3 |
| | $ | 8 |
| | $ | 296 |
| (e) |
| Foreign currency contracts | | $ | — |
| | $ | 1 |
| | $ | — |
| | $ | — |
| | $ | 1 |
| (e) |
| FPL - commodity contracts | $ | — |
| | $ | 53 |
| | $ | 2 |
| | $ | (7 | ) | | $ | 48 |
| (d) | $ | — |
| | $ | 208 |
| | $ | 4 |
| | $ | (3 | ) | | $ | 209 |
| (e) |
| Liabilities: | | | | | | | | | | | | | | | | | | | | |
| Derivatives: | | | | | | | | | | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Commodity contracts | $ | 1,285 |
| | $ | 1,994 |
| | $ | 354 |
| | $ | (2,693 | ) | | $ | 940 |
| (d) | $ | 1,476 |
| | $ | 980 |
| | $ | 512 |
| | $ | (2,485 | ) | | $ | 483 |
| (e) |
| Interest rate contracts | $ | — |
| | $ | 127 |
| | $ | 93 |
| | $ | — |
| | $ | 220 |
| (d) | $ | — |
| | $ | 171 |
| | $ | 113 |
| | $ | 8 |
| | $ | 292 |
| (e) |
| Foreign currency swaps | $ | — |
| | $ | 151 |
| | $ | — |
| | $ | — |
| | $ | 151 |
| (d) | |
| Foreign currency contracts | | $ | — |
| | $ | 106 |
| | $ | — |
| | $ | — |
| | $ | 106 |
| (e) |
| FPL - commodity contracts | $ | — |
| | $ | 7 |
| | $ | 2 |
| | $ | (7 | ) | | $ | 2 |
| (d) | $ | — |
| | $ | 1 |
| | $ | 3 |
| | $ | (3 | ) | | $ | 1 |
| (e) |
______________________
| |
| (a) | Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of 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 consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively. |
| |
| (b) | Includes restricted cash of approximately $164 million ($120 million for FPL) in other current assets on the consolidated balance sheets. |
| |
| (c) | Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at the Carrying AmountOther than Fair Value below. |
| |
(c)(d) | At NEE, approximately $1,300 million ($1,141 million at FPL) arePrimarily invested in commingled funds whose underlying investmentssecurities would be Level 1 if those investmentssecurities were held directly by NEE or FPL.
|
| |
(d)(e) | See Note 3 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's consolidated balance sheets. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
| | | | December 31, 2012 | | December 31, 2015 | |
| | Level 1 | | Level 2 | | Level 3 | | Netting(a) | | Total | | Level 1 | | Level 2 | | Level 3 | | Netting(a) | | Total | |
| | (millions) | | (millions) | |
| Assets: | | | | | | | | | | | | | | | | | | | | |
| Cash equivalents: | | | | | | | | | | | |
Cash equivalents and restricted cash:(b) | | | | | | | | | | | |
| NEE - equity securities | $ | 23 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 23 |
| | $ | 312 |
| | $ | — |
| | $ | — |
| | | | $ | 312 |
| |
Special use funds:(b) | | | | | | | | | | | |
| FPL - equity securities | | $ | 36 |
| | $ | — |
| | $ | — |
| | | | $ | 36 |
| |
Special use funds:(c) | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Equity securities | $ | 914 |
| | $ | 1,240 |
| (c) | $ | — |
| | $ | — |
| | $ | 2,154 |
| | $ | 1,320 |
| | $ | 1,354 |
| (d) | $ | — |
| | | | $ | 2,674 |
| |
| U.S. Government and municipal bonds | $ | 451 |
| | $ | 143 |
| | $ | — |
| | $ | — |
| | $ | 594 |
| | $ | 446 |
| | $ | 166 |
| | $ | — |
| | | | $ | 612 |
| |
| Corporate debt securities | $ | — |
| | $ | 572 |
| | $ | — |
| | $ | — |
| | $ | 572 |
| | $ | — |
| | $ | 713 |
| | $ | — |
| | | | $ | 713 |
| |
| Mortgage-backed securities | $ | — |
| | $ | 560 |
| | $ | — |
| | $ | — |
| | $ | 560 |
| | $ | — |
| | $ | 412 |
| | $ | — |
| | | | $ | 412 |
| |
| Other debt securities | $ | 15 |
| | $ | 26 |
| | $ | — |
| | $ | — |
| | $ | 41 |
| | $ | — |
| | $ | 52 |
| | $ | — |
| | | | $ | 52 |
| |
| FPL: | | | | | | | | | | | | | | | | | | | | |
| Equity securities | $ | 217 |
| | $ | 1,118 |
| (c) | $ | — |
| | $ | — |
| | $ | 1,335 |
| | $ | 364 |
| | $ | 1,234 |
| (d) | $ | — |
| | | | $ | 1,598 |
| |
| U.S. Government and municipal bonds | $ | 390 |
| | $ | 119 |
| | $ | — |
| | $ | — |
| | $ | 509 |
| | $ | 335 |
| | $ | 145 |
| | $ | — |
| | | | $ | 480 |
| |
| Corporate debt securities | $ | — |
| | $ | 397 |
| | $ | — |
| | $ | — |
| | $ | 397 |
| | $ | — |
| | $ | 531 |
| | $ | — |
| | | | $ | 531 |
| |
| Mortgage-backed securities | $ | — |
| | $ | 475 |
| | $ | — |
| | $ | — |
| | $ | 475 |
| | $ | — |
| | $ | 327 |
| | $ | — |
| | | | $ | 327 |
| |
| Other debt securities | $ | 16 |
| | $ | 16 |
| | $ | — |
| | $ | — |
| | $ | 32 |
| | $ | — |
| | $ | 40 |
| | $ | — |
| | | | $ | 40 |
| |
| Other investments: | | | | | | | | | | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Equity securities | $ | 7 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 7 |
| | $ | 30 |
| | $ | 10 |
| | $ | — |
| | | | $ | 40 |
| |
| Debt securities | $ | 11 |
| | $ | 106 |
| | $ | — |
| | $ | — |
| | $ | 117 |
| | $ | 39 |
| | $ | 132 |
| | $ | — |
| | | | $ | 171 |
| |
| Derivatives: | | | | | | | | | | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Commodity contracts | $ | 1,187 |
| | $ | 2,251 |
| | $ | 794 |
| | $ | (2,871 | ) | | $ | 1,361 |
| (d) | $ | 2,187 |
| | $ | 2,540 |
| | $ | 1,179 |
| | $ | (3,969 | ) | | $ | 1,937 |
| (e) |
| Interest rate contracts | $ | — |
| | $ | 76 |
| | $ | — |
| | $ | — |
| | $ | 76 |
| (d) | $ | — |
| | $ | 35 |
| | $ | — |
| | $ | (1 | ) | | $ | 34 |
| (e) |
| FPL - commodity contracts | $ | — |
| | $ | 14 |
| | $ | 3 |
| | $ | (12 | ) | | $ | 5 |
| (d) | $ | — |
| | $ | 1 |
| | $ | 6 |
| | $ | (3 | ) | | $ | 4 |
| (e) |
| Liabilities: | | | | | | | | | | | | | | | | | | | | |
| Derivatives: | | | | | | | | | | | | | | | | | | | | |
| NEE: | | | | | | | | | | | | | | | | | | | | |
| Commodity contracts | $ | 1,240 |
| | $ | 1,844 |
| | $ | 228 |
| | $ | (2,748 | ) | | $ | 564 |
| (d) | $ | 2,153 |
| | $ | 1,887 |
| | $ | 540 |
| | $ | (3,598 | ) | | $ | 982 |
| (e) |
| Interest rate contracts | $ | — |
| | $ | 387 |
| | $ | — |
| | $ | — |
| | $ | 387 |
| (d) | $ | — |
| | $ | 214 |
| | $ | 101 |
| | $ | 4 |
| | $ | 319 |
| (e) |
| Foreign currency swaps | $ | — |
| | $ | 66 |
| | $ | — |
| | $ | — |
| | $ | 66 |
| (d) | |
| Foreign currency contracts | | $ | — |
| | $ | 132 |
| | $ | — |
| | $ | (5 | ) | | $ | 127 |
| (e) |
| FPL - commodity contracts | $ | — |
| | $ | 31 |
| | $ | 1 |
| | $ | (12 | ) | | $ | 20 |
| (d) | $ | — |
| | $ | 219 |
| | $ | 6 |
| | $ | (3 | ) | | $ | 222 |
| (e) |
______________________
| |
| (a) | Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of 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 consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively. |
| |
| (b) | Includes restricted cash of approximately $61 million ($36 million for FPL) in other current assets on the consolidated balance sheets. |
| |
| (c) | Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at the Carrying AmountOther than Fair Value below. |
| |
(c)(d) | At NEE, approximately $1,214 million ($1,093 million at FPL) arePrimarily invested in commingled funds whose underlying investmentssecurities would be Level 1 if those investmentssecurities were held directly by NEE or FPL.
|
| |
(d)(e) | See Note 3 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's consolidated balance sheets. |
Significant Unobservable Inputs Used in Recurring Fair Value Measurements - The valuation of certain commodity contracts requires the use of significant unobservable inputs. All forward price, implied volatility, implied correlation and interest rate inputs used in the valuation of such contracts are directly based on third-party market data, such as broker quotes and exchange settlements, when that data is available. If third-party market data is not available, then industry standard methodologies are used to develop inputs that maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Observable inputs, including some forward prices, implied volatilities and interest rates used for determining fair value are updated daily to reflect the best available market information. Unobservable inputs which are related to observable inputs, such as illiquid portions of forward price or volatility curves, are updated daily as well, using industry standard techniques such as interpolation and extrapolation, combining observable forward inputs supplemented by historical market and other relevant data. Other unobservable inputs, such as implied correlations, customer migration rates from full requirements contracts and some implied volatility curves, are modeled using proprietary models based on historical data and industry standard techniques.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
All price, volatility, correlation and customer migration inputs used in valuation are subject to validation by the Trading Risk Management group. The Trading Risk Management group performs a risk management function responsible for assessing credit, market and operational risk impact, reviewing valuation methodology and modeling, confirming transactions, monitoring approval processes and developing and monitoring trading limits. The Trading Risk Management group is separate from the transacting group. For markets where independent third-party data is readily available, validation is conducted daily by directly reviewing this
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
market data against inputs utilized by the transacting group, and indirectly by critically reviewing daily risk reports. For markets where independent third-party data is not readily available, additional analytical reviews are performed on at least a quarterly basis. These analytical reviews are designed to ensure that all price and volatility curves used for fair valuing transactions are adequately validated each quarter, and are reviewed and approved by the Trading Risk Management group. In addition, other valuation assumptions such as implied correlations and customer migration rates are reviewed and approved by the Trading Risk Management group on a periodic basis. Newly created models used in the valuation process are also subject to testing and approval by the Trading Risk Management group prior to use and established models are reviewed annually, or more often as needed, by the Trading Risk Management group.
On a monthly basis, the Exposure Management Committee (EMC), which is comprised of certain members of senior management, meets with representatives from the Trading Risk Management group and the transacting group to discuss NEE's and FPL's energy risk profile and operations, to review risk reports and to discuss fair value issues as necessary. The EMC develops guidelines required for an appropriate risk management control infrastructure, which includes implementation and monitoring of compliance with Trading Risk Management policy. The EMC executes its risk management responsibilities through direct oversight and delegation of its responsibilities to the Trading Risk Management group, as well as to other corporate and business unit personnel.
The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at December 31, 20132016 are as follows:
| | | Transaction Type | | Fair Value at December 31, 2013 | | Valuation Technique(s) | | Significant Unobservable Inputs | | Range | | Fair Value at December 31, 2016 | | Valuation Technique(s) | | Significant Unobservable Inputs | | Range |
| | | Assets | | Liabilities | | | Assets | | Liabilities | |
| | | (millions) | | | (millions) | |
| Forward contracts - power | | $ | 677 |
| | $ | 74 |
| | Discounted cash flow | | Forward price (per MWh) | | $13 | — | $207 | | $ | 621 |
| | $ | 206 |
| | Discounted cash flow | | Forward price (per MWh) | | $— | — | $91 |
| Forward contracts - gas | | 82 |
| | 23 |
| | Discounted cash flow | | Forward price (per MMBtu) | | $2 | — | $16 | | 27 |
| | 10 |
| | Discounted cash flow | | Forward price (per MMBtu) | | $2 | — | $11 |
| Forward contracts - other commodity related | | 15 |
| | 11 |
| | Discounted cash flow | | Forward price (various) | | $1 | — | $245 | | 7 |
| | 1 |
| | Discounted cash flow | | Forward price (various) | | $(17) | — | $57 |
| Options - power | | 55 |
| | 49 |
| | Option models | | Implied correlations | | 7% | — | 96% | | 43 |
| | 10 |
| | Option models | | Implied correlations | | 1% | — | 100% |
| | | | | | | Implied volatilities | | 1% | — | 200% | | | | | | Implied volatilities | | 9% | — | 296% |
| Options - gas | | 22 |
| | 29 |
| | Option models | | Implied correlations | | 7% | — | 96% | |
| Options - primarily gas | | | 223 |
| | 230 |
| | Option models | | Implied correlations | | 1% | — | 100% |
| | | | | | | Implied volatilities | | 1% | — | 175% | | | | | | Implied volatilities | | 1% | — | 260% |
| Full requirements and unit contingent contracts | | 218 |
| | 168 |
| | Discounted cash flow | | Forward price (per MWh) | | $(32) | — | $222 | | 279 |
| | 55 |
| | Discounted cash flow | | Forward price (per MWh) | | $(20) | — | $220 |
| | | | | | | Customer migration rate(a) | | —% | — | 20% | | | | | | Customer migration rate(a) | | —% | — | 20% |
| Total | | $ | 1,069 |
| | $ | 354 |
| | | $ | 1,200 |
| | $ | 512 |
| |
______________________
| |
| (a) | Applies only to full requirements contracts. |
The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows:
|
| | | | |
| Significant Unobservable Input | | Position | | Impact on Fair Value Measurement |
| Forward price | | Purchase power/gas | | Increase (decrease) |
| | | Sell power/gas | | Decrease (increase) |
| Implied correlations | | Purchase option | | Decrease (increase) |
| | | Sell option | | Increase (decrease) |
| Implied volatilities | | Purchase option | | Increase (decrease) |
| | | Sell option | | Decrease (increase) |
| Customer migration rate | | Sell power(a) | | Decrease (increase) |
————————————
| |
| (a) | Assumes the contract is in a gain position. |
In addition, the fair value measurement of interest rate swapcontract net liabilities related to the solar projects in Spain of approximately $93$110 million at December 31, 20132016 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.contracts. See Note 11 - Spain Solar Projects Debt Restructuring for further discussion.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows:
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| | NEE | | FPL | | NEE | | FPL | | NEE | | FPL | NEE | | FPL | | NEE | | FPL | | NEE | | FPL |
| | (millions) | (millions) |
| Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year | $ | 566 |
| | $ | 2 |
| | $ | 486 |
| | $ | 4 |
| | $ | 296 |
| | $ | 7 |
| $ | 538 |
| | $ | — |
| | $ | 622 |
| | $ | 5 |
| | $ | 622 |
| | $ | — |
|
| Realized and unrealized gains (losses): | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | |
| | |
| | |
| | |
|
Included in earnings(a) | 299 |
| | — |
| | 218 |
| | — |
| | 454 |
| | — |
| 333 |
| | — |
| | 451 |
| | — |
| | (77 | ) | | — |
|
| Included in other comprehensive income | | 8 |
| | — |
| | 11 |
| | — |
| | 18 |
| | — |
|
| Included in regulatory assets and liabilities | — |
| | — |
| | 5 |
| | 5 |
| | 3 |
| | 3 |
| 1 |
| | 1 |
| | 3 |
| | 3 |
| | 7 |
| | 7 |
|
| Purchases | 101 |
| | — |
| | 273 |
| | (7 | ) | | 270 |
| | (6 | ) | 261 |
| | — |
| | 180 |
| | — |
| | 55 |
| | — |
|
| Settlements | (55 | ) | | (2 | ) | | (181 | ) | | — |
| | (166 | ) | | — |
| (390 | ) | | — |
| | (473 | ) | | (8 | ) | | 194 |
| | (2 | ) |
| Issuances | (173 | ) | | — |
| | (243 | ) | | — |
| | (362 | ) | | — |
| (195 | ) | | — |
| | (202 | ) | | — |
| | (122 | ) | | — |
|
Transfers in(b) | (120 | ) | | — |
| | 20 |
| | — |
| | 6 |
| | — |
| 19 |
| | — |
| | (13 | ) | | — |
| | 80 |
| | — |
|
Transfers out(b) | 4 |
| | — |
| | (12 | ) | | — |
| | (15 | ) | | — |
| 3 |
| | — |
| | (41 | ) | | — |
| | (155 | ) | | — |
|
| Fair value of net derivatives based on significant unobservable inputs at December 31 | $ | 622 |
| | $ | — |
| | $ | 566 |
| | $ | 2 |
| | $ | 486 |
| | $ | 4 |
| $ | 578 |
| | $ | 1 |
| | $ | 538 |
| | $ | — |
| | $ | 622 |
| | $ | 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) | $ | 329 |
| | $ | — |
| | $ | 152 |
| | $ | — |
| | $ | 423 |
| | $ | — |
| $ | 219 |
| | $ | — |
| | $ | 277 |
| | $ | — |
| | $ | 248 |
| | $ | — |
|
______________________
| |
| (a) | For the year ended December 31, 2013, $3022016, $397 million of realized and unrealized gains are reflected in the consolidated statement of income in operating revenues and the balance is primarily reflected in interest expense. For the years ended December 31, 2012 and 2011, $220 million and $441 million, respectively, of realized and unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased powerinterest expense. For the year ended December 31, 2015, $462 million of realized and interchange. unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is primarily reflected in interest expense. For the year December 31, 2014, $79 million of realized and unrealized losses are reflected in the consolidated statements of income in interest expense and the balance is primarily reflected in operating revenues. |
| |
| (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.data. Transfers from Level 3 to Level 2 were a result of increased observability of market data.data and, in 2016, a favorable change to a credit valuation adjustment. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period. |
| |
| (c) | For the yearyears ended December 31, 2013, $3302016, 2015 and 2014, $283 million, $289 million, and $328 million of unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is reflected in interest expense. For the years ended December 31, 2012 and 2011, $157 million and $423 million, respectively, of unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange. |
Contingent Consideration - NEE recorded a liability related to a contingent holdback as part of the 2015 acquisition of a portfolio of seven long-term contracted natural gas pipeline assets located in Texas (Texas pipelines). See Note 7 - Texas Pipeline Business.
Nonrecurring Fair Value Measurements - NEE tests long-lived assets for recoverability whenever events or changesIn 2013, NEER initiated a plan and received internal authorization to pursue the sale of its ownership interests in circumstances indicateoil-fired generation plants located in Maine (Maine fossil), which resulted in the recording of a loss during that period which was reflected within discontinued operations at NEE. In 2014, NEER decided not to pursue the carrying amount may not be recoverable. In February 2013, the Spanish government enacted a new law that made further changessale of Maine fossil due to the economic framework of renewable energy projects including, among other things, changes that negatively affectdivergence between the projected economicsachievable sales price and management's view of the 99.8 MWsassets' value, which increased as a result of solar thermal facilities that affiliatessignificant market changes. Accordingly, the Maine fossil assets were written-up to management's current estimate of NEER were constructing in Spain (Spain solar projects) (see Note 13 - 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 withresulting in a carrying amountgain of approximately $800$21 million were written down to their estimated fair value of approximately $500($12 million as of March 31, 2013, resulting in an impairment of $300 million (whichafter tax) which is recordedincluded as a separate line item in NEE's consolidated statements of income. The fair value measurement (Level 3) was estimated using an income forapproach based primarily on the year ended December 31, 2013) and other related charges ($342 million after-tax, see Note 5).updated capacity revenue forecasts.
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 13 - Spain Solar Projects for a discussion of additional developments that could potentially impact the Spain solar projects.
In 2011, market value indications and the potential impact of proposed environmental regulations suggested that the carrying value of certain NEER assets, primarily wind assets in West Texas and oil-fired assets in Maine, could be impaired. NEER performed a fair value analysis and concluded that an impairment charge related to the long-lived assets, primarily property, plant and equipment, was necessary. The fair value analysis was primarily based on the income approach using significant unobservable inputs (Level 3) including revenue and generation forecasts, projected capital and maintenance expenditures and discount rates. As a result, long-lived assets held and used with a carrying amount of approximately $79 million were written down to their fair value of $28 million, resulting in an impairment charge of $51 million ($31 million after-tax), which was recorded as a separate line item in NEE's consolidated statements of income for the year ended December 31, 2011.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
In 2011, subsidiaries of NEER completed the sales of their ownership interests in five natural gas-fired generating plants with a total generating capacity of approximately 2,700 MW for net cash proceeds of approximately $1.2 billion, after transaction costs and working capital and other adjustments. Approximately $363 million of these proceeds were used to repay debt associated with certain of the projects. A NEER affiliate will continue to operate the facilities that were sold under service contracts expiring through 2016. In connection with the sales, a loss of approximately $151 million ($98 million after-tax) was recorded in NEE's consolidated statements of income. The loss includes the reclassification of $30 million from AOCI as a result of the discontinuance of certain cash flow hedges because it became no longer probable that the future hedged transactions would occur. See Note 3.
See Note 6 for a discussion of the nonrecurring fair value measurement of certain discontinued operations.
Fair Value of Financial Instruments Recorded at the Carrying AmountOther than Fair Value - The carrying amounts of cash equivalents, commercial paper and other short-term debt and commercial paper approximate their fair values. The carrying amounts and estimated fair values of other financial instruments excluding those recorded at other than fair value and disclosed above in Recurring Fair Value Measurements, are as follows:
| | | | December 31, 2013 | | December 31, 2012 | | December 31, 2016 | | December 31, 2015 | |
| | Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value | |
| | (millions) | | (millions) | |
| NEE: | | | | |
Special use funds(a) | $ | 311 |
| | $ | 311 |
| | $ | 269 |
| | $ | 269 |
| | $ | 712 |
| | $ | 712 |
| | $ | 675 |
| | $ | 675 |
| |
| Other investments - primarily notes receivable | $ | 531 |
| | $ | 627 |
| (b) | $ | 590 |
| | $ | 774 |
| (b) | $ | 526 |
| | $ | 668 |
| (b) | $ | 512 |
| | $ | 722 |
| (b) |
Long-term debt, including current maturities | $ | 27,728 |
| | $ | 28,612 |
| (c) | $ | 26,647 |
| (d) | $ | 28,874 |
| (c) | $ | 30,418 |
| | $ | 31,623 |
| (d) | $ | 28,897 |
| | $ | 30,412 |
| (d) |
| FPL: | | | | | | | | | | | | | | | | |
Special use funds(a) | $ | 200 |
| | $ | 200 |
| | $ | 170 |
| | $ | 170 |
| | $ | 557 |
| | $ | 557 |
| | $ | 528 |
| | $ | 528 |
| |
| Long-term debt, including current maturities | $ | 8,829 |
| | $ | 9,451 |
| (c) | $ | 8,782 |
| | $ | 10,421 |
| (c) | $ | 10,072 |
| | $ | 11,211 |
| (d) | $ | 10,020 |
| | $ | 11,028 |
| (d) |
______________________
| |
| (a) | Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis. |
| |
| (b) | Primarily classified as held to maturity. Fair values are primarily estimated using an income approach utilizing a discounted cash flow valuation technique based on certain observable yield curves and indices considering the credit profile of the borrower (Level 3). Notes receivable bear interest primarily at fixed rates and mature by 2029. Notes receivable are considered impaired and placed in non-accrual status when it becomes probable that all amounts due cannot be collected in accordance with the contractual terms of the agreement. The assessment to place notes receivable in non-accrual status considers various credit indicators, such as credit ratings and market-related information. As of December 31, 2013 and 2012, NEE had no notes receivable reported in non-accrual status. |
| |
| (c) | Excludes debt totaling $373 million and $938 million, respectively, reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets for which the carrying amount approximates fair value. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale. |
| |
| (d) | As of December 31, 20132016 and 2012,2015, for NEE, approximately $17,92129,804 million and $18,96218,031 million, respectively, is estimated using a market approach based on quoted market prices for the same or similar issues (Level 2); the balance is estimated using an income approach utilizing a discounted cash flow valuation technique, considering the current credit spreadprofile of the debtor (Level 3). For FPL, primarily estimated using quoted market prices for the same or similar issues (Level 2). |
| |
(d) | Also includes long-term debt reflected in liabilities associated with assets held for sale on the consolidated balance sheets, for which the carrying amount approximates fair value. See Note 6. |
Special Use Funds - The special use funds noted above and those carried at fair value (see Recurring Fair Value Measurements)Measurements above) consist of FPL's storm fund assets of $74 million and NEE's and FPL's nuclear decommissioning fund assets of $4,706$5,434 million and $3,199$5,064 million, respectively, at December 31, 2013.2016 and 2015, respectively, ($3,665 million and $3,430 million, respectively, for FPL) and, in 2015, FPL's storm fund assets of $74 million. The investments held in the special use funds consist of equity and debt securities which are primarily classified as available for sale and carried at estimated fair value. The amortized cost of debt and equity securities is $1,954approximately $1,820 million and $1,384$1,543 million,, respectively, at December 31, 20132016 and $1,679$1,823 million and $1,500$1,505 million,, respectively, at December 31, 20122015 ($1,5951,373 million and $694$764 million,, respectively, at December 31, 20132016 and $1,339$1,409 million and $839$732 million,, respectively, at December 31, 20122015 for FPL). For FPL's special use funds, consistent with regulatory treatment, changes in fair value, including any other than temporary impairment losses, result in a corresponding adjustment to the related regulatory liability accounts. For NEE's non-rate regulated operations, changes in fair value result in a corresponding adjustment to OCI, except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NEE's consolidated statements of income. Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 20132016 of approximately sixnine years at both NEE and FPL. FPL's storm fund primarily consists of debt securities with a weighted-average maturity at December 31, 2013 of approximately three years. The cost of securities sold is determined using the specific identification method.
Realized gains and losses and proceeds from the sale or maturity of available for sale securities are as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | Years Ended December 31, | | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 | | 2016 | | 2015 | | 2014 |
| | (millions) |
| Realized gains | $ | 116 |
| | $ | 194 |
| | $ | 211 |
| | $ | 53 |
| | $ | 70 |
| | $ | 120 |
|
| Realized losses | $ | 76 |
| | $ | 87 |
| | $ | 115 |
| | $ | 44 |
| | $ | 43 |
| | $ | 94 |
|
| Proceeds from sale or maturity of securities | $ | 3,400 |
| | $ | 4,643 |
| | $ | 4,092 |
| | $ | 2,442 |
| | $ | 3,724 |
| | $ | 3,349 |
|
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Realized gains and losses and proceeds from the sale or maturity of available for sale securities are as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | Years Ended December 31, | | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 |
| | (millions) |
| Realized gains | $ | 246 |
| | $ | 252 |
| | $ | 183 |
| | $ | 182 |
| | $ | 98 |
| | $ | 74 |
|
| Realized losses | $ | 88 |
| | $ | 67 |
| | $ | 88 |
| | $ | 59 |
| | $ | 46 |
| | $ | 62 |
|
| Proceeds from sale or maturity of securities | $ | 4,190 |
| | $ | 5,028 |
| | $ | 4,348 |
| | $ | 3,342 |
| | $ | 3,790 |
| | $ | 2,988 |
|
The unrealized gains on available for sale securities are as follows:
| | | | NEE | | FPL | NEE | | FPL |
| | December 31, | | December 31, | December 31, | | December 31, |
| | 2013 | | 2012 | | 2013 | | 2012 | 2016 | | 2015 | | 2016 | | 2015 |
| | | | (millions) | | | | | (millions) | | |
| Equity securities | $ | 1,125 |
| | $ | 680 |
| | $ | 777 |
| | $ | 521 |
| $ | 1,396 |
| | $ | 1,166 |
| | $ | 1,007 |
| | $ | 863 |
|
| Debt securities | $ | 42 |
| | $ | 92 |
| | $ | 36 |
| | $ | 77 |
| $ | 22 |
| | $ | 17 |
| | $ | 17 |
| | $ | 14 |
|
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 | NEE | | FPL |
| | December 31, | | December 31, | December 31, | | December 31, |
| | 2013 | | 2012 | | 2013 | | 2012 | 2016 | | 2015 | | 2016 | | 2015 |
| | | | (millions) | | | | | (millions) | | |
Unrealized losses(a) | $ | 32 |
| | $ | 3 |
| | $ | 25 |
| | $ | 2 |
| $ | 34 |
| | $ | 51 |
| | $ | 28 |
| | $ | 45 |
|
| Fair value | $ | 1,069 |
| | $ | 277 |
| | $ | 844 |
| | $ | 223 |
| $ | 959 |
| | $ | 1,129 |
| | $ | 722 |
| | $ | 861 |
|
______________________
| |
| (a) | Unrealized losses on available for sale debt securities for securities in an unrealized loss position for greater than twelve months at December 31, 20132016 and 20122015 were not material to NEE or FPL. |
Regulations issued by the FERC and the NRC provide general risk management guidelines to protect nuclear decommissioning funds and to allow such funds to earn a reasonable return. The FERC regulations prohibit, 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 Seabrook, decommissioning fund contributions and withdrawals are also regulated by the NDFC pursuant to New Hampshire law.
The nuclear decommissioning reserve funds are managed by investment managers who must comply with the guidelines of 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.
Financial Instruments Accounting Standards Update - In January 2016, the FASB issued an accounting standards update which modifies current guidance for financial instruments. The standards update requires that equity investments (except investments accounted for under the equity method and investments that are consolidated) be measured at fair value with changes in fair value recognized in net income and provides an option for those equity investments that do not have readily determinable fair values to be measured at cost minus impairment (plus or minus changes resulting from observable price changes). The standards update also makes certain changes to presentation and disclosure requirements of financial instruments. The standards update is effective for NEE and FPL beginning January 1, 2018 and will be applied retrospectively with the cumulative effect recognized as of the date of initial application. NEE and FPL are currently evaluating the effect the adoption of this standards update will have, if any, on their consolidated financial statements.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
5. Income Taxes
The components of income taxes are as follows:
| | | | NEE | | FPL | NEE | | FPL |
| | Years Ended December 31, | | Years Ended December 31, | Years Ended December 31, | | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 | | 2016 | | 2015 | | 2014 |
| | (millions) | (millions) |
| Federal: | | | | | | | | | | | | | | | | | | | | | | |
Current(a) | $ | (145 | ) | | $ | (4 | ) | | $ | (35 | ) | | $ | 174 |
| | $ | (261 | ) | | $ | (64 | ) | $ | 72 |
| | $ | 10 |
| | $ | — |
| | $ | 72 |
| | $ | 423 |
| | $ | 240 |
|
| Deferred | 874 |
| | 636 |
| | 572 |
| | 540 |
| | 906 |
| | 622 |
| 1,075 |
| | 1,194 |
| | 1,077 |
| | 830 |
| | 399 |
| | 542 |
|
| Total federal | 729 |
| | 632 |
| | 537 |
| | 714 |
| | 645 |
| | 558 |
| 1,147 |
| | 1,204 |
| | 1,077 |
| | 902 |
| | 822 |
| | 782 |
|
| State: | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | |
| | |
| | |
| | |
|
Current(a) | 69 |
| | 14 |
| | 11 |
| | 44 |
| | 26 |
| | 43 |
| 76 |
| | 31 |
| | (29 | ) | | 57 |
| | 58 |
| | 68 |
|
| Deferred | 3 |
| | 46 |
| | (19 | ) | | 77 |
| | 81 |
| | 53 |
| 160 |
| | (7 | ) | | 128 |
| | 92 |
| | 77 |
| | 60 |
|
| Total state | 72 |
| | 60 |
| | (8 | ) | | 121 |
| | 107 |
| | 96 |
| 236 |
| | 24 |
| | 99 |
| | 149 |
| | 135 |
| | 128 |
|
| Total income taxes | $ | 801 |
| | $ | 692 |
| | $ | 529 |
| | $ | 835 |
| | $ | 752 |
| | $ | 654 |
| $ | 1,383 |
| | $ | 1,228 |
| | $ | 1,176 |
| | $ | 1,051 |
| | $ | 957 |
| | $ | 910 |
|
______________________
| |
(a)
| Includes provision for unrecognized tax benefits. |
A reconciliation between the effective income tax rates and the applicable statutory rate is as follows:
|
| | | | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | Years Ended December 31, | | Years Ended December 31, |
| | 2016 | | 2015 | | 2014 | | 2016 | | 2015 | | 2014 |
| Statutory federal income tax rate | 35.0 | % | | 35.0 | % | | 35.0 | % | | 35.0 | % | | 35.0 | % | | 35.0 | % |
| Increases (reductions) resulting from: | |
| | |
| | |
| | |
| | |
| | |
|
| State income taxes - net of federal income tax benefit | 3.5 |
| | 0.4 |
| | 1.8 |
| | 3.5 |
| | 3.4 |
| | 3.4 |
|
| PTCs and ITCs - NEER | (3.9 | ) | | (4.1 | ) | | (5.1 | ) | | — |
| | — |
| | — |
|
| Convertible ITCs - NEER | (1.7 | ) | | (0.8 | ) | | (1.4 | ) | | — |
| | — |
| | — |
|
| Adjustments associated with Canadian assets | (0.7 | ) | | — |
| | 1.3 |
| | — |
| | — |
| | — |
|
| Other - net | (0.7 | ) | | 0.3 |
| | 0.7 |
| | (0.7 | ) | | (1.7 | ) | | (0.9 | ) |
| Effective income tax rate | 31.5 | % | | 30.8 | % | | 32.3 | % | | 37.8 | % | | 36.7 | % | | 37.5 | % |
|
| | | | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | Years Ended December 31, | | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | | 2013 | | 2012 | | 2011 |
| Statutory federal income tax rate | 35.0 | % | | 35.0 | % | | 35.0 | % | | 35.0 | % | | 35.0 | % | | 35.0 | % |
| Increases (reductions) resulting from: | |
| | |
| | |
| | |
| | |
| | |
|
| State income taxes - net of federal income tax benefit | 1.9 |
| | 1.5 |
| | (0.2 | ) | | 3.6 |
| | 3.5 |
| | 3.6 |
|
| PTCs and ITCs - NEER | (8.3 | ) | | (7.8 | ) | | (11.1 | ) | | — |
| | — |
| | — |
|
| Convertible ITCs - NEER | (2.4 | ) | | (1.5 | ) | | (0.1 | ) | | — |
| | — |
| | — |
|
Valuation allowance associated with Spain solar projects(a) | 5.1 |
| | — |
| | — |
| | — |
| | — |
| | — |
|
| Other - net | 0.5 |
| | (0.6 | ) | | (2.0 | ) | | (0.4 | ) | | (0.7 | ) | | (0.6 | ) |
| Effective income tax rate | 31.8 | % | | 26.6 | % | | 21.6 | % | | 38.2 | % | | 37.8 | % | | 38.0 | % |
______________________
| |
(a)
| Reflects a full valuation allowance on deferred tax assets associated with the Spain solar projects. See Note 4 - Nonrecurring Fair Value Measurements. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows:
| | | | NEE | | FPL | NEE | | FPL |
| | December 31, | | December 31, | December 31, | | December 31, |
| | 2013 | | 2012 | | 2013 | | 2012 | 2016 | | 2015 | | 2016 | | 2015 |
| | (millions) | (millions) |
| Deferred tax liabilities: | | | | | | | | | | | | | | |
| Property-related | $ | 11,247 |
| | $ | 10,206 |
| | $ | 6,948 |
| | $ | 6,193 |
| $ | 13,094 |
| | $ | 12,204 |
| | $ | 8,882 |
| | $ | 8,040 |
|
| Pension | 567 |
| | 403 |
| | 441 |
| | 438 |
| 454 |
| | 455 |
| | 502 |
| | 480 |
|
| Storm reserve deficiency | 180 |
| | 212 |
| | 180 |
| | 212 |
| |
| Nuclear decommissioning trusts | 188 |
| | 115 |
| | — |
| | — |
| 253 |
| | 219 |
| | — |
| | — |
|
| Net unrealized gains on derivatives | 260 |
| | 245 |
| | — |
| | — |
| 581 |
| | 528 |
| | — |
| | — |
|
| Investments in partnerships and joint ventures | | 603 |
| | 403 |
| | — |
| | — |
|
| Other | 686 |
| | 563 |
| | 219 |
| | 162 |
| 1,272 |
| | 1,196 |
| | 796 |
| | 695 |
|
| Total deferred tax liabilities | 13,128 |
| | 11,744 |
| | 7,788 |
| | 7,005 |
| 16,257 |
| | 15,005 |
| | 10,180 |
| | 9,215 |
|
| Deferred tax assets and valuation allowance: | | | | | | | | | | | | | | |
| Decommissioning reserves | 431 |
| | 418 |
| | 361 |
| | 348 |
| 454 |
| | 438 |
| | 401 |
| | 386 |
|
| Postretirement benefits | 145 |
| | 162 |
| | 107 |
| | 114 |
| 145 |
| | 141 |
| | 93 |
| | 95 |
|
| Net operating loss carryforwards | 1,343 |
| | 1,216 |
| | 96 |
| | 6 |
| 427 |
| | 604 |
| | 3 |
| | 4 |
|
| Tax credit carryforwards | 2,522 |
| | 2,312 |
| | — |
| | — |
| 3,059 |
| | 2,916 |
| | — |
| | — |
|
| ARO and accrued asset removal costs | 795 |
| | 832 |
| | 670 |
| | 723 |
| 777 |
| | 759 |
| | 699 |
| | 697 |
|
| Other | 959 |
| | 790 |
| | 297 |
| | 197 |
| 1,024 |
| | 836 |
| | 443 |
| | 303 |
|
Valuation allowance(a) | (325 | ) | | (192 | ) | | — |
| | — |
| (269 | ) | | (223 | ) | | — |
| | — |
|
| Net deferred tax assets | 5,870 |
| | 5,538 |
| | 1,531 |
| | 1,388 |
| 5,617 |
| | 5,471 |
| | 1,639 |
| | 1,485 |
|
| Net accumulated deferred income taxes | $ | 7,258 |
| | $ | 6,206 |
| | $ | 6,257 |
| | $ | 5,617 |
| |
| Net deferred income taxes | | $ | 10,640 |
| | $ | 9,534 |
| | $ | 8,541 |
| | $ | 7,730 |
|
______________________
| |
| (a) | Amount relates to a valuation allowance related to the Spain solar projects in Spain, deferred state tax credits and state operating loss carryforwards. |
Deferred tax assets and liabilities are included on the consolidated balance sheets as follows:
|
| | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | December 31, | | December 31, |
| | 2016 | | 2015 | | 2016 | | 2015 |
| | | | (millions) | | |
| Noncurrent other assets | $ | 461 |
| | $ | 293 |
| | $ | — |
| | $ | — |
|
| Deferred income taxes - noncurrent liabilities | (11,101 | ) | | (9,827 | ) | | (8,541 | ) | | (7,730 | ) |
| Net deferred income taxes | $ | (10,640 | ) | | $ | (9,534 | ) | | $ | (8,541 | ) | | $ | (7,730 | ) |
The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2016 are as follows:
|
| | | | | | | | | | | | | | | |
| | NEE | | FPL |
| | December 31, | | December 31, |
| | 2013 | | 2012 | | 2013 | | 2012 |
| | | | (millions) | | |
| Deferred income taxes - current assets | $ | 753 |
| | $ | 397 |
| (a) | $ | 98 |
| (b) | $ | — |
|
| Noncurrent other assets | 139 |
| | 113 |
| | — |
| | — |
|
| Other current liabilities | (6 | ) | | (13 | ) | | — |
| | (33 | ) |
| Deferred income taxes - noncurrent liabilities | (8,144 | ) | | (6,703 | ) | | (6,355 | ) | | (5,584 | ) |
| Net accumulated deferred income taxes | $ | (7,258 | ) | | $ | (6,206 | ) | | $ | (6,257 | ) | | $ | (5,617 | ) |
|
| | | | | |
| | Amount | | Expiration Dates |
| | (millions) | | |
| Net operating loss carryforwards: | | | |
| Federal | $ | 165 |
| | 2026-2036 |
| State | 174 |
| | 2017-2036 |
| Foreign | 88 |
| (a) | 2017-2036 |
| Net operating loss carryforwards | $ | 427 |
| | |
| Tax credit carryforwards: | | | |
| Federal | $ | 2,697 |
| | 2022-2036 |
| State | 362 |
| (b) | 2017-2044 |
| Tax credit carryforwards | $ | 3,059 |
| | |
______________________
| |
| (a) | NEE reclassified approximately $430Includes $60 million of federalnet operating loss carryforwards from current deferred income taxes to noncurrent deferred income taxes in the first quarter of 2013 as a result of increased tax depreciation deductions available under the American Taxpayer Relief Act of 2012, which was enacted in January 2013.
with an indefinite expiration period. |
| |
| (b) | Included in other current assets on FPL's consolidated balance sheets.Includes $188 million of ITC carryforwards with an indefinite expiration period. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2013 are as follows:
|
| | | | | |
| | Amount | | Expiration Dates |
| | (millions) | | |
| Net operating loss carryforwards: | | | |
| Federal | $ | 1,066 |
| | 2026-2032 |
| State | 161 |
| | 2014-2033 |
| Foreign | 116 |
| | 2017-2033 |
| Net operating loss carryforwards | $ | 1,343 |
| | |
| Tax credit carryforwards: | | | |
| Federal | $ | 2,218 |
| | 2022-2033 |
| State | 304 |
| | 2014-2034 |
| Tax credit carryforwards | $ | 2,522 |
| | |
6. Discontinued Operations
In 2013, a subsidiary of NEER completed the sale of its ownership interest in a portfolio of hydropower generation plants and related assets with a total generating capacity of 351 MW located in Maine and New Hampshire. 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 consolidated statements of income for the year ended December 31, 2013. The carrying amounts of the major classes of assets and liabilities related to the plants that were classified as held for sale on NEE's consolidated balance sheet at December 31, 2012 primarily represent property, plant and equipment and the related long-term debt. The operations of the hydropower generation plants, exclusive of the gain, were not material to NEE's consolidated statements of income for the years ended December 31, 2013, 2012 and 2011.
In 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 consolidated statements of income for the year ended December 31, 2013. The fair value measurement (Level 3) was based on the estimated sales price less the estimated costs to sell. The estimated sales price was estimated using an income approach based primarily on capacity revenue forecasts. The carrying amount of the assets and liabilities and the operations, exclusive of the loss, of Maine fossil were not material to NEE's consolidated financial statements as of December 31, 2013 or for the years ended December 31, 2013, 2012 and 2011.
7.Jointly-Owned Electric Plants
Certain NEE subsidiaries own undivided interests in the jointly-owned facilities described below, and are entitled to a proportionate share of the output from those facilities. The subsidiaries are responsible for their share of the operating costs, as well as providing their own financing. Accordingly, each subsidiary includes itssubsidiary's proportionate share of the facilities and related revenues and expenses is included in the appropriate balance sheet and statement of income captions. NEE's and FPL's respective shares of direct expenses for these facilities are included in fuel, purchased power and interchange expense, O&M expenses, depreciation and amortization expense and taxes other than income taxes and other - net in NEE's and FPL's consolidated statements of income.
NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows:
|
| | | | | | | | | | | | | | |
| | December 31, 2016 |
| | Ownership Interest | | Gross Investment(a) | | Accumulated Depreciation(a) | | Construction Work in Progress |
| | | | (millions) |
| FPL: | | | | | | | |
| St. Lucie Unit No. 2 | 85 | % | | $ | 2,172 |
| | $ | 815 |
| | $ | 33 |
|
| St. Johns River Power Park units and coal terminal | 20 | % | | $ | 393 |
| | $ | 208 |
| | $ | — |
|
| Scherer Unit No. 4 | 76 | % | | $ | 1,138 |
| | $ | 395 |
| | $ | 3 |
|
| NEER: | | | | | | | |
| Duane Arnold | 70 | % | | $ | 466 |
| | $ | 146 |
| | $ | 16 |
|
| Seabrook | 88.23 | % | | $ | 1,138 |
| | $ | 271 |
| | $ | 77 |
|
| Wyman Station Unit No. 4 | 84.35 | % | | $ | 25 |
| | $ | 3 |
| | $ | — |
|
| Corporate and Other: | | | | | | | |
| Transmission substation assets located in Seabrook, New Hampshire | 88.23 | % | | $ | 76 |
| | $ | 17 |
| | $ | 3 |
|
______________________
| |
| (a) | Excludes nuclear fuel. |
7. Business Acquisitions
Texas Pipeline Business - On October 1, 2015, a subsidiary of NEP acquired 100% of the membership interests in NET Holdings Management, LLC (Texas pipeline business), a developer, owner and operator of the Texas pipelines. One of the acquired pipelines is subject to a 10% noncontrolling interest. The aggregate purchase price of approximately $2 billion included approximately $934 million in cash consideration and the assumption of approximately $706 million in existing debt of the Texas pipeline business and its subsidiaries at closing and excluded post-closing working capital adjustments of approximately $2 million. The purchase price is subject to (i) a $200 million holdback payable, in whole or in part, upon satisfaction of financial performance and capital expenditure thresholds relating to planned expansion projects (contingent holdback) and (ii) a $200 million holdback retained to satisfy any indemnification obligations of the sellers through April 2017. NEP incurred approximately $13 million in acquisition-related costs during the year ended December 31, 2015, which are reflected in O&M expenses in NEE's consolidated statements of income.
Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on October 1, 2015 based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed, including the noncontrolling interest, were based on significant estimates and assumptions, including Level 3 inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The excess of the purchase price over the estimated fair value of assets acquired and liabilities assumed was recognized as goodwill at the acquisition date. The goodwill arising from the acquisition consists largely of growth opportunities from the Texas pipeline business. Approximately $380 million of the goodwill is expected to be deductible for income tax purposes over a 15 year period. A liability of approximately $186 million was recognized as of the acquisition date for each of the contingent holdback and the indemnity holdback, reflecting the fair value of the expected future payments. NEE determined this fair value measurement based on management's probability assessment. The significant inputs and assumptions used in the fair value measurement included the estimated probability of executing contracts related to financial performance and capital expenditure thresholds as well as the appropriate discount rate. In 2016, NEE recorded fair value adjustments to eliminate the entire contingent holdback as the contracts contemplated in the acquisition were not executed by December 31, 2016. The fair value adjustments are reflected as revaluation of contingent consideration in NEE's consolidated statements of income. At December 31, 2016, the carrying amount of the indemnity holdback was approximately $199 million. The indemnity holdback is included in current other liabilities at December 31, 2016 and the contingent and indemnity holdbacks are included in noncurrent other liabilities at December 31, 2015 on NEE's consolidated balance sheets.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
NEE'sThe following table summarizes the estimated fair value of assets acquired and FPL's proportionateliabilities assumed for the acquisition of the Texas pipeline business:
|
| | | |
| | Amounts Recognized
as of October 1, 2015 |
| | (millions) |
| Assets: | |
| Property, plant and equipment | $ | 806 |
|
| Cash | 1 |
|
| Other receivables and current other assets | 21 |
|
| Noncurrent other assets (other intangible assets, see Note 1 - Goodwill and Other Intangible Assets) | 720 |
|
| Noncurrent other assets (goodwill, see Note 1 - Goodwill and Other Intangible Assets) | 622 |
|
| Total assets | $ | 2,170 |
|
| | |
| Liabilities: | |
| Long-term debt, including current portion | $ | 706 |
|
| Accounts payable and current other liabilities | 46 |
|
| Noncurrent other liabilities, primarily acquisition holdbacks | 415 |
|
| Total liabilities | 1,167 |
|
| Less noncontrolling interest at fair value | 69 |
|
| Total cash consideration | $ | 934 |
|
Pending Oncor-Related Transactions - In July 2016, NEE, EFH Merger Co., LLC (Merger Sub), a direct wholly owned subsidiary of NEE, Energy Future Holdings Corp. (EFH Corp.) and Energy Future Intermediate Holding Company LLC (EFIH), a direct wholly owned subsidiary of EFH Corp., entered into an agreement and plan of merger (EFH merger agreement). Pursuant to the EFH merger agreement and after the reorganization of EFH Corp. (reorganized EFH) under the United States Bankruptcy Code, Merger Sub will acquire 100% of the equity of reorganized EFH Corp. and certain of its direct and indirect subsidiaries, including its indirect ownership of 80.03% of the outstanding equity interests of Oncor Electric Delivery Company LLC (Oncor), a regulated electric distribution and transmission business that operates the largest distribution and transmission system in Texas. The EFH merger agreement, as amended in September 2016, provides that the consideration for the transaction funded by NEE will be $9.796 billion, which will be paid almost all in cash, with the balance in shares of NEE common stock. The amount of consideration will be subject to adjustment as provided in the EFH merger agreement. On February 17, 2017, the U.S. Bankruptcy Court for the District of Delaware confirmed EFH Corp.'s Eighth Amended Joint Plan of Reorganization. Completion of the merger and the actual closing date remain subject to, among other things, approval by the Public Utility Commission of Texas (PUCT) and receipt of a supplemental private letter ruling from the Internal Revenue Service. NEE, Merger Sub, EFH Corp. and EFIH have certain specified termination rights under the EFH merger agreement. In October 2016, NEE and Oncor filed a joint application with the PUCT requesting the approval of the EFH Corp. merger, as well as the TTHC merger described below. The PUCT hearings regarding the merger transactions were conducted the week of February 20, 2017.
In October 2016, NEE and its direct wholly owned subsidiary WSS Acquisition Company (TTHC Merger Sub) entered into an agreement (TTHC merger agreement) with Texas Transmission Holdings Corporation (TTHC) and certain stockholders of TTHC, Cheyne Walk Investment Pte Ltd, Borealis Power Holdings Inc. and BPC Health Corporation (together, the Primary Holders). Pursuant to the TTHC merger agreement, TTHC Merger Sub would merge with TTHC for a total cash merger consideration to be paid by NEE of approximately $2.410 billion, subject to adjustment as provided in the TTHC merger agreement. TTHC, through Texas Transmission Investment LLC (TTI), a wholly owned subsidiary, owns an approximately 20% interest in jointly-owned facilitiesOncor. Completion of the TTHC merger and actual closing date remain subject to, among other things, approval by the PUCT. NEE, TTHC Merger Sub, TTHC and the Primary Holders have certain specified termination rights under the TTHC merger agreement.
In October 2016, T & D Equity Acquisition, LLC (OMI purchaser), a direct wholly owned subsidiary of NEE, Oncor Management Investment LLC (OMI) and Oncor entered into an agreement for the OMI purchaser to purchase OMI's 0.22% interest in Oncor for approximately $27 million. This transaction is as follows:subject to NEE closing its agreement to acquire EFH Corp. described above.
The TTHC and OMI transactions, when combined with NEE’s agreement to acquire EFH Corp. described above, if completed, would result in NEE owning 100% of Oncor. NEE expects the EFH Corp. merger and the other Oncor-related transactions to be completed in the first half of 2017.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
|
| | | | | | | | | | | | | | |
| | December 31, 2013 |
| | Ownership Interest | | Gross Investment(a) | | Accumulated Depreciation(a) | | Construction Work in Progress |
| | | | (millions) |
| FPL: | | | | | | | |
| St. Lucie Unit No. 2 | 85 | % | | $ | 1,813 |
| | $ | 606 |
| | $ | 14 |
|
| St. Johns River Power Park units and coal terminal | 20 | % | | $ | 387 |
| | $ | 195 |
| | $ | 14 |
|
| Scherer Unit No. 4 | 76 | % | | $ | 1,093 |
| | $ | 329 |
| | $ | — |
|
| NEER: | | | | | | | |
| Duane Arnold | 70 | % | | $ | 386 |
| | $ | 104 |
| | $ | 41 |
|
| Seabrook | 88.23 | % | | $ | 965 |
| | $ | 188 |
| | $ | 85 |
|
| Wyman Station Unit No. 4 | 84.35 | % | | $ | 109 |
| | $ | 44 |
| | $ | — |
|
| Corporate and Other: | | | | | | | |
| Transmission substation assets located in Seabrook, New Hampshire | 88.23 | % | | $ | 70 |
| | $ | 15 |
| | $ | 2 |
|
______________________
| |
(a) | Excludes nuclear fuel. |
8.Variable Interest Entities (VIEs)
In February 2015, the FASB issued an accounting standards update that modified consolidation guidance. The standards update makes changes to both the variable interest entity model and the voting interest entity model, including modifying the evaluation of whether limited partnerships or similar legal entities are VIEs or voting interest entities and amending the guidance for assessing how relationships of related parties affect the consolidation analysis of VIEs. The standards update was effective for NEE and FPL beginning January 1, 2016, and the modified retrospective approach was adopted. The adoption of the standards update did not result in any changes to the previous consolidation conclusions; however, it did result in a limited number of entities being considered VIEs and the related disclosure was provided for the current period.
As of December 31, 20132016, NEE has fourteenthirty-three 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-ownedwholly 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 $324216 million and $366230 million at December 31, 20132016 and 2012,2015, respectively, and consisted primarily of storm-recovery property, which are included in securitized storm-recovery costsboth current and noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. The liabilities of the VIE were approximately $394214 million and $447278 million at December 31, 20132016 and 2012,2015, respectively, and consisted primarily of storm-recovery bonds, which are included in long-term debt on NEE's and FPL's 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 19941995 with this 250a 330 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. 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 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 years ended December 31, 2013, 2012 and 2011, FPL purchased 784,155 MWh, 680,500 MWh and 1,188,649 MWh, respectively, from the facility at a total cost of approximately $152 million, $174 million and $189 million, respectively.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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. See Note 13 - Contracts for a discussion of FPL's purchase of the 330 MW coal-fired facility.
NEER - NEE consolidates thirteenthirty-two 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, as well as construction, and through its 100% equity ownership has the obligation to absorb expected losses of these VIEs.
A subsidiary of NEER is the primary beneficiary of, and therefore consolidates, NEP, which consolidates NEP OpCo because of NEP’s controlling interest in the general partner of NEP OpCo. NEP is a limited partnership formed to acquire, manage and own contracted clean energy projects with stable, long-term cash flows through a limited partner interest in NEP OpCo. NEE owns a controlling non-economic general partner interest in NEP and a limited partner interest in NEP OpCo, and presents NEP's limited partner interest as a noncontrolling interest in NEE's consolidated financial statements. At December 31, 2016, NEE owns common units of NEP OpCo representing noncontrolling interest in NEP’s operating projects of approximately 65.2%. The assets and liabilities of NEP were approximately $7.2 billion and $5.0 billion, respectively, at December 31, 2016, and primarily consisted of property, plant and equipment and long-term debt.
A NEER VIE consolidates two entities which own and operate natural gas/oil electric generatinggeneration facilities with the capability of producing 110 MW. This VIE sells itsThese entities sell their electric output under power sales contracts to a third party, with expiration dates in 2018 and 2020.2020. 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 partyThe entities have third-party debt and equity to finance its operations. The debtwhich is secured by liens against the generatinggeneration 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 $8595 million and $6342 million, respectively, at December 31, 20132016 and $9084 million and $7047 million, respectively, at December 31, 20122015, and consisted primarily of property, plant and equipment and long-term debt.
The other twelve
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Two indirect subsidiaries of NEER VIEs consolidate severaleach contributed, to a NEP subsidiary, an approximately 50% ownership interest in three entities which own and operate wind electric generatingsolar PV facilities with the capability of producing a total of 3,541approximately 277 MW. TenEach of the two indirect subsidiaries of NEER is considered a VIE since the non-managing members have no substantive rights over the managing members, and is consolidated by NEER. These three entities sell their electric output to third parties under power sales contracts with expiration dates in 2035 and 2036. The three entities have third-party debt which is secured by liens against the assets of the 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 were approximately $571 million and $487 million, respectively, at December 31, 2016 and $657 million and $626 million, respectively, at December 31, 2015, and consisted primarily of property, plant and equipment and long-term debt.
NEER consolidates a special purpose entity that has insufficient equity at risk and is considered a VIE. The entity provided a loan in the form of a note receivable (see Note 4 - Fair Value of Financial Instruments Recorded at Other than Fair Value) to an unrelated third party, and also issued senior secured bonds which are collateralized by the note receivable. The assets and liabilities of the VIE were approximately $502 million and $511 million, respectively, at December 31, 2016, and consisted primarily of notes receivables (included in other investments) and long-term debt.
The other twenty-seven NEER VIEs that are consolidated relate to certain subsidiaries which have sold differential membership interests in entities which own and operate wind electric generation and solar PV facilities with the capability of producing a total of approximately 6,847 MW and 374 MW, respectively. These entities sell their electric output either under power sales contracts to third parties with expiration dates ranging from 2018 through 2038; the other two VIEs sell their electric output2046 or in the spot market. The VIEs use third-party debt and/or equity to finance their operations. Certain investors that holdhave no equity interestat risk in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of the generatinggeneration facilities, including certain tax attributes. TheCertain entities have third-party debt which is secured by liens against the generatinggeneration facilities and the other assets of these entities or by pledges of NEER's ownership interest in these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of these VIEs totaled approximately $5.3$10.9 billion and $3.36.9 billion, respectively, at December 31, 20132016. NineTwenty of the twelvetwenty-seven were VIEs at December 31, 20122015 and were consolidated; the assets and liabilities of those VIEs totaled approximately $4.67.6 billion and $3.25.0 billion, respectively, at December 31, 20122015. At December 31, 20132016 and 2012,2015, 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 December 31, 20132016 and 2012,2015, several NEE subsidiaries have investments totaling approximately $668$2,505 million ($5052,049 million at FPL) and $753602 million ($583476 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 consolidated balance sheets and in special use funds on FPL's consolidated balance sheets. As ofAt December 31, 20132016, these investments represented primarily commingled funds, and at December 31, 2015, mortgage-backed securities. NEE subsidiaries, including FPL, 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.
Certain subsidiaries of NEE have noncontrolling interests in entities accounted for under the equity method. These entities are limited partnerships or similar entity structures in which the limited partners or nonmanaging members do not have substantive rights, and therefore are considered VIEs. NEE is not the primary beneficiary because it does not have a controlling financial interest in these entities, and therefore does not consolidate any of these entities. NEE’s investment in these entities totaled approximately $234 million at December 31, 2016, which are included in other investments on NEE’s consolidated balance sheets. Subsidiaries of NEE have committed to invest an additional approximately $30 million in two of the entities.
9. Investments in Partnerships and Joint Ventures
NEER-Certain subsidiaries of NEE, primarily NEER, has non-controllinghave noncontrolling non-majority owned interests in various partnerships and joint ventures, essentially all of which are in the process of developing or constructing natural gas pipelines or own electric generatinggeneration facilities. At December 31, 20132016 and 20122015, NEER'sNEE's investments in partnerships and joint ventures totaled approximately $1,767 million and $365 million and $2431,063 million, respectively, which isare included in other investments on NEE's consolidated balance sheets. NEER's interest in these partnerships and joint ventures primarily range from approximately 20%31% to 50%. At December 31, 2013,2016 and 2015, the principal entities included in NEER's investments in partnerships and joint ventures were Sabal Trail Transmission, LLC, Desert Sunlight Investment Holdings, LLC, and Northeast Energy, LP and in 2012 also included Evacuacion Valdecaballeros, SL, Luz Solar Partners Ltd., V and Luz Solar Partners Ltd., III.Cedar Point II Wind, LP.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Summarized combined information for these principal entities is as follows:
| | | | 2013 | | 2012 | 2016 | | 2015 |
| | (millions) | (millions) |
| Net income | $ | 37 |
| | $ | 27 |
| $ | 264 |
| | $ | 213 |
|
| Total assets | $ | 1,955 |
| | $ | 1,512 |
| $ | 4,502 |
| | $ | 3,339 |
|
| Total liabilities | $ | 1,299 |
| | $ | 1,053 |
| $ | 1,364 |
| | $ | 1,307 |
|
| Partners'/members' equity | $ | 656 |
| | $ | 459 |
| $ | 3,138 |
| | $ | 2,032 |
|
| | | | | | | |
| NEER's share of underlying equity in the principal entities | $ | 328 |
| | $ | 223 |
| $ | 1,423 |
| | $ | 874 |
|
Difference between investment carrying amount and underlying equity in net assets(a) | (5 | ) | | 1 |
| 65 |
| | (3 | ) |
| NEER's investment carrying amount for the principal entities | $ | 323 |
| | $ | 224 |
| $ | 1,488 |
| | $ | 871 |
|
______________________
| |
| (a) | The majoritySubstantially all of the difference between the investment carrying amount and the underlying equity in net assets is being amortized over the remaining life of the investee's assets.a 25-year period. |
Certain subsidiaries of NEER provide services to the partnerships and joint ventures, including operations and maintenance and business management services. NEE's operating revenues for the years ended December 31, 2013, 2012 and 2011 include approximately $41 million, $33 million and $26 million, respectively, related to such services. The net receivables at December 31, 2013 and 2012, for these services, as well as for affiliate energy commodity transactions, payroll and other payments made on behalf of these investees, were approximately $23 million and $11 million, respectively, and are included in other receivables on NEE's consolidated balance sheets.
NEE - In 2004, a trust created by NEE sold $300 million of 5 7/8% preferred trust securities to the public and $9 million of common trust securities to NEE. The trust is an unconsolidated 100%-owned finance subsidiary. The proceeds from the sale of the preferred and common trust securities were used to buy 5 7/8% junior subordinated debentures maturing in March 2044 from NEECH. NEE has fully and unconditionally guaranteed the preferred trust securities and the junior subordinated debentures.
10.Common Shareholders' Equity
Stock-Based Compensation - On March 30, 2016, the FASB issued an accounting standards update related to the accounting for employee share-based payment awards including simplification in areas such as (i) income tax consequences; (ii) classification of awards as either equity or liabilities; and (iii) classification on the statement of cash flows. The standards update was effective for NEE beginning January 1, 2017, however, NEE early adopted the provisions of the standards update during the three months ended June 30, 2016 with an effective date of January 1, 2016. Upon adoption, NEE recorded approximately $18 million primarily related to previously unrecognized excess tax benefits in deferred income taxes with a resulting increase to retained earnings as of January 1, 2016. For the year ended December 31, 2016, the impact of the standards update resulted in approximately $30 million of excess tax benefits being recorded in NEE's consolidated statements of income. All other provisions of the standards update did not have a material impact to NEE's consolidated financial statements. The standards update had no effect on FPL.
Earnings Per Share - The reconciliation of NEE's basic and diluted earnings per share of common stock from continuing operationsattributable to NEE is as follows:
| | | | Years Ended December 31, | Years Ended December 31, |
| | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| | (millions, except per share amounts) | (millions, except per share amounts) |
| Numerator - income from continuing operations | $ | 1,720 |
| | $ | 1,911 |
| | $ | 1,923 |
| |
| Numerator - net income attributable to NEE | | $ | 2,912 |
| | $ | 2,752 |
| | $ | 2,465 |
|
| Denominator: | |
| | |
| | |
| |
| | |
| | |
|
| Weighted-average number of common shares outstanding - basic | 424.2 |
| | 416.7 |
| | 416.6 |
| 463.1 |
| | 450.5 |
| | 434.4 |
|
Performance share awards, options, equity units and restricted stock(a) | 2.8 |
| | 2.5 |
| | 2.4 |
| |
Equity units, performance share awards, stock options, forward sale agreement and restricted stock(a) | | 2.7 |
| | 3.5 |
| | 5.7 |
|
| Weighted-average number of common shares outstanding - assuming dilution | 427.0 |
| | 419.2 |
| | 419.0 |
| 465.8 |
| | 454.0 |
| | 440.1 |
|
| Earnings per share of common stock from continuing operations: | | | |
| | |
| |
| Earnings per share attributable to NEE: | | | | |
| | |
|
| Basic | $ | 4.06 |
| | $ | 4.59 |
| | $ | 4.62 |
| $ | 6.29 |
| | $ | 6.11 |
| | $ | 5.67 |
|
| Assuming dilution | $ | 4.03 |
| | $ | 4.56 |
| | $ | 4.59 |
| $ | 6.25 |
| | $ | 6.06 |
| | $ | 5.60 |
|
______________________
| |
| (a) | Calculated using the treasury stock method. Performance share awards are included in diluted weighted-average number of common shares outstanding based upon what would be issued if the end of the reporting period was the end of the term of the award. Options, performance share awards, restricted stock and equity units are included in diluted weighted-average number of common shares outstanding by applying the treasury stock method. |
Common shares issuable pursuant to equity units, the forward sale agreement described below,performance share awards, stock options and performance share awardsforward sale agreements and restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 7.17.9 million,, 11.4 3.5 million and 14.62.6 million for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively.
Issuance of Common Stock and Forward Sale Agreement - In November 2013, NEE sold 4.5 million shares of its common stock at a price of $88.03 per share, and a forward counterparty borrowed and sold 6.6 million shares of NEE's common stock (borrowed shares) in connection with a forward sale agreement. In December 2014, NEE physically settled the forward sale agreement described below.by delivering 6.6 million shares of its common stock to the forward counterparty in exchange for cash proceeds of approximately $552 million. The forward sale price used to determine the cash proceeds received by NEE was calculated based on the initial forward sale price of $88.03 per share less certain adjustments as specified in the forward sale agreement. Prior to the settlement date, the forward sale agreement had a dilutive effect on NEE’s earnings per share when the average market price per share of NEE’s common stock was above the adjusted forward sale price per share.
In connection with the offering and sale of the borrowed shares, NEE entered into a confirmation of forward sale transaction (forward sale agreement) with a forward counterparty for the borrowed shares, to be settled on a date or dates, to be specified at NEE's
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Forward Sale Agreements - In November 2016, NEE entered into forward sale agreements with several forward counterparties to be settled on a date or dates to be specified at NEE’s direction, no later than December 31, 2014.November 1, 2017. NEE may elect physical settlement, cash settlement or net share settlement for all or a portion of its rights or obligations under the forward sale agreement.agreements. If NEE physically settles, it will deliver the shares of its common stock to the applicable forward counterparty in exchange for cash proceeds at the then applicable forward sale price, which represents the initial forward sale price of $88.03$124.00 per share, less certain adjustments as specified in the forward sale agreement.agreements. The forward sale transaction istransactions are classified as an equity transactiontransactions because it isthey are indexed to NEE's common stock and physical settlement is within NEE's control. With respect to the borrowed shares, NEE will not receive any proceeds or issue any shares until the settlement of the forward sale agreement. At December 31, 2013,2016, if NEE had settled the forward sale agreementagreements by delivery of the 6.612 million shares of its common stock to the forward counterparty,counterparties, NEE would have received net proceeds of approximately $576 million.
$1.5 billion. Prior to the settlement date, the forward sale agreementagreements will have a dilutive effect on NEE’sNEE's earnings per share when the average market price per share of NEE’sNEE's common stock is above the adjusted forward sale price per share. As of December 31, 2013,2016, the adjusted forward sale price per share was greater than the average market price per share;share of NEE's common stock; accordingly the 6.612 million shares were antidilutive.
Common Stock Dividend Restrictions - NEE's charter does not limit the dividends that may be paid on its common stock. FPL's mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends and other distributions to NEE. These restrictions do not currently limit FPL's ability to pay dividends to NEE.
Employee Stock Ownership Plan - The employee retirement savings plans of NEE include a leveraged ESOP feature. Shares of common stock held by the trust for the employee retirement savings plans (Trust) are used to provide all or a portion of the employers' matching contributions. Dividends received on all shares, along with cash contributions from the employers, are used to pay principal and interest on an ESOP loan held by a subsidiary of NEECH. Dividends on shares allocated to employee accounts and used by the Trust for debt service are replaced with shares of common stock, at prevailing market prices, in an equivalent amount. For purposes of computing basic and fully diluted earnings per share, ESOP shares that have been committed to be released are considered outstanding.
ESOP-related compensation expense was approximately $46 million, $44 million and $42 million in 2013, 2012 and 2011, respectively. The related share release was based on the fair value of shares allocated to employee accounts during the period. Interest income on the ESOP loan is eliminated in consolidation. ESOP-related unearned compensation included as a reduction of common shareholders' equity at December 31, 2013 was approximately $26 million, representing unallocated shares at the original issue price. The fair value of the ESOP-related unearned compensation account using the closing price of NEE common stock at December 31, 2013 was approximately $155 million.
Stock-Based Compensation - Net income for the years ended December 31, 2013, 20122016, 2015 and 20112014 includes approximately $67$77 million,, $57 $60 million and $49$60 million,, respectively, of compensation costs and $26$30 million,, $22 $23 million and $19$23 million,, respectively, of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended December 31, 2013, 20122016, 2015 and 20112014 was not material. As of December 31, 2013,2016, there were approximately $59$78 million of unrecognized compensation costs related to nonvested/nonexercisable stock-based compensation arrangements. These costs are expected to be recognized over a weighted-average period of 1.951.8 years.
At December 31, 2013,2016, approximately 1816 million shares of common stock were authorized for awards to officers, employees and non-employee directors of NEE and its subsidiaries under NEE's: (a) Amended and Restated 2011 Long Term Incentive Plan, (b) 2007 Non-Employee Directors Stock Plan and (c) earlier equity compensation plans under which shares are reserved for issuance under existing grants, but no additional shares are available for grant under the earlier plans. NEE satisfies restricted stock and performance share awards by issuing new shares of its common stock or by purchasing shares of its common stock in the open market. NEE satisfies stock option exercises by issuing new shares of its common stock. NEE generally grants most of its stock-based compensation awards in the first quarter of each year.
Restricted Stock and Performance Share Awards - Restricted stock typically vests within three years after the date of grant and is subject to, among other things, restrictions on transferability prior to vesting. The fair value of restricted stock is measured based upon the closing market price of NEE common stock as of the date of grant. Performance share awards are typically payable at the end of a three-year performance period if the specified performance criteria are met. The fair value of performance share awards is estimated primarily based upon the closing market price of NEE common stock as of the date of grant less the present value of expected dividends, multiplied by an estimated performance multiple which is subsequently trued up based on actual performance.
The activity in restricted stock and performance share awards for the year ended December 31, 2016 was as follows:
|
| | | | | | |
| | Shares | | Weighted- Average Grant Date Fair Value Per Share |
| Restricted Stock: | | | |
| Nonvested balance, January 1, 2016 | 563,660 |
| | $ | 89.60 |
|
| Granted | 291,422 |
| | $ | 112.86 |
|
| Vested | (274,144 | ) | | $ | 85.62 |
|
| Forfeited | (24,290 | ) | | $ | 100.78 |
|
| Nonvested balance, December 31, 2016 | 556,648 |
| | $ | 103.26 |
|
| Performance Share Awards: | | | |
| Nonvested balance, January 1, 2016 | 915,199 |
| | $ | 81.90 |
|
| Granted | 604,686 |
| | $ | 89.23 |
|
| Vested | (630,773 | ) | | $ | 69.40 |
|
| Forfeited | (54,679 | ) | | $ | 95.62 |
|
| Nonvested balance, December 31, 2016 | 834,433 |
| | $ | 95.76 |
|
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The activity in restricted stock and performance share awards for the year ended December 31, 2013 was as follows:
|
| | | | | | |
| | Shares | | Weighted- Average Grant Date Fair Value Per Share |
| Restricted Stock: | | | |
| Nonvested balance, January 1, 2013 | 863,625 |
| | $ | 55.26 |
|
| Granted | 320,555 |
| | $ | 74.02 |
|
| Vested | (425,920 | ) | | $ | 54.75 |
|
| Forfeited | (44,424 | ) | | $ | 61.65 |
|
| Nonvested balance, December 31, 2013 | 713,836 |
| | $ | 63.59 |
|
| Performance Share Awards: | | | |
| Nonvested balance, January 1, 2013 | 1,285,089 |
| | $ | 46.65 |
|
| Granted | 681,770 |
| | $ | 58.53 |
|
| Vested | (691,769 | ) | | $ | 42.12 |
|
| Forfeited | (79,173 | ) | | $ | 54.36 |
|
| Nonvested balance, December 31, 2013 | 1,195,917 |
| | $ | 55.55 |
|
The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 20122015 and 20112014 was $60.78$103.58 and $54.77$93.46 respectively. The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 20122015 and 20112014 was $51.23$77.12 and $50.13,$71.52, respectively.
The total fair value of restricted stock and performance share awards vested was $82$99 million,, $71 $108 million and $53$85 million for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively.
Options - Options typically vest within three years after the date of grant and have a maximum term of ten years. The exercise price of each option granted equals the closing market price of NEE common stock on the date of grant. The fair value of the options is estimated on the date of the grant using the Black-Scholes option-pricing model and based on the following assumptions:
| | | | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
Expected volatility(a) | 20.08 - 20.15% | | 21.00% | | 21.54% | 16.37% | | 18.91% | | 20.32% |
| Expected dividends | 3.28 - 3.64% | | 3.99% | | 4.03% | 3.16% | | 3.11% | | 3.11% |
Expected term (years)(b) | 7.0 | | 6.7 | | 6.0 | 7.0 | | 7.0 | | 7.0 |
| Risk-free rate | 1.15 - 1.40% | | 1.37% | | 2.80% | 1.50% | | 1.84% | | 2.17% |
______________________
| |
| (a) | Based on historical experience. |
| |
| (b) | Based on historical exercise and post-vesting cancellation experience adjusted for outstanding awards. |
Option activity for the year ended December 31, 20132016 was as follows:
|
| | | | | | | | | | | | |
| | Shares Underlying Options | | Weighted- Average Exercise Price Per Share | | Weighted- Average Remaining Contractual Term (years) | | Aggregate Intrinsic Value (millions) |
| Balance, January 1, 2013 | 3,191,090 |
| | $ | 50.69 |
| | | | |
| Granted | 393,396 |
| | $ | 72.63 |
| | | | |
| Exercised | (363,279 | ) | | $ | 38.19 |
| | | | |
| Forfeited | (28,860 | ) | | $ | 64.46 |
| | | | |
| Expired | (800 | ) | | $ | 28.38 |
| | | | |
| Balance, December 31, 2013 | 3,191,547 |
| | $ | 54.70 |
| | 5.9 | | $ | 99 |
|
| | | | | | | | |
| Exercisable, December 31, 2013 | 2,453,246 |
| | $ | 51.78 |
| | 5.1 | | $ | 83 |
|
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued) |
| | | | | | | | | | | | |
| | Shares Underlying Options | | Weighted- Average Exercise Price Per Share | | Weighted- Average Remaining Contractual Term (years) | | Aggregate Intrinsic Value (millions) |
| Balance, January 1, 2016 | 2,866,501 |
| | $ | 63.39 |
| | | | |
| Granted | 294,889 |
| | $ | 111.67 |
| | | | |
| Exercised | (651,492 | ) | | $ | 55.37 |
| | | | |
| Forfeited | (4,690 | ) | | $ | 106.64 |
| | | | |
| Balance, December 31, 2016 | 2,505,208 |
| | $ | 71.08 |
| | 5.4 | | $ | 121 |
|
| | | | | | | | |
| Exercisable, December 31, 2016 | 2,043,899 |
| | $ | 62.90 |
| | 4.7 | | $ | 116 |
|
The weighted-average grant date fair value of options granted was $9.20, $7.69$11.74, $13.62 and $7.78$14.09 per share for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively. The total intrinsic value of stock options exercised was approximately $14$42 million,, $57 $11 million and $29$30 million for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively.
Cash received from option exercises was approximately $36 million, $14 million, $559 million and $3126 million for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively. The tax benefits realized from options exercised were approximately $16 million, $5 million, $224 million and $11 million for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively.
Accelerated Share Repurchase (ASR) of NEE Common Stock - In December 2011, NEE purchased approximately 6.7 million shares of its common stock at a price of $55.76 per share for an aggregate price of $375 million pursuant to an ASR agreement. The approximately 6.7 million shares repurchased were retired, which resulted in a decrease in common stock and additional paid-in capital on NEE's consolidated statement of common stockholders' equity. In February 2012, NEE elected to settle the ASR agreement in cash; the settlement amount was not material.
Preferred Stock - NEE's charter authorizes the issuance of 100 million shares of serial preferred stock, $0.01 par value, none of which are outstanding. FPL's charter authorizes the issuance of 10,414,100 shares of preferred stock, $100 par value;value, 5 million shares of subordinated preferred stock, no par value, and 5 million shares of preferred stock, no par value, none of which are outstanding.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Accumulated Other Comprehensive Income (Loss) - The components of AOCI, net of tax, are as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | Accumulated Other Comprehensive Income (Loss) |
| | Net Unrealized Gains (Losses) on Cash Flow Hedges | | Net Unrealized Gains (Losses) on Available for Sale Securities | | Defined Benefit Pension and Other Benefits Plans | | Net Unrealized Gains (Losses) on Foreign Currency Translation | | Other Comprehensive Income (Loss) Related to Equity Method Investee | | Total |
| | (millions) |
| Balances, December 31, 2010 | $ | 24 |
| | $ | 133 |
| | $ | (1 | ) | | $ | 10 |
| | $ | — |
| | $ | 166 |
|
| Other comprehensive loss | (228 | ) | | (30 | ) | | (45 | ) | | (5 | ) | | (12 | ) | | (320 | ) |
| Balances, December 31, 2011 | (204 | ) | | 103 |
| | (46 | ) | | 5 |
| | (12 | ) | | (154 | ) |
| Other comprehensive income (loss) | (62 | ) | | (7 | ) | | (28 | ) | | 7 |
| | (11 | ) | | (101 | ) |
| Balances, December 31, 2012 | (266 | ) | | 96 |
| | (74 | ) | | 12 |
| | (23 | ) | | (255 | ) |
| Other comprehensive income (loss) before reclassifications | 84 |
| | 118 |
| | 95 |
| | (45 | ) | | 7 |
| | 259 |
|
| Amounts reclassified from AOCI | 67 |
| (a) | (17 | ) | (b) | 2 |
| | — |
| | — |
| | 52 |
|
| Net other comprehensive income (loss) | 151 |
| | 101 |
| | 97 |
| | (45 | ) | | 7 |
| | 311 |
|
| Balances, December 31, 2013 | $ | (115 | ) | | $ | 197 |
| | $ | 23 |
| | $ | (33 | ) | | $ | (16 | ) | | $ | 56 |
|
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | 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 Losses on Foreign Currency Translation | | Other Comprehensive Income (Loss) Related to Equity Method Investee | | Total |
| | (millions) |
| Balances, December 31, 2013 | $ | (115 | ) | | $ | 197 |
| | $ | 23 |
| | $ | (33 | ) | | $ | (16 | ) | | $ | 56 |
|
| Other comprehensive income (loss) before reclassifications | (141 | ) | | 62 |
| | (44 | ) | | (25 | ) | | (8 | ) | | (156 | ) |
| Amounts reclassified from AOCI | 98 |
| (a) | (41 | ) | (b) | 1 |
| | — |
| | — |
| | 58 |
|
| Net other comprehensive income (loss) | (43 | ) | | 21 |
| | (43 | ) | | (25 | ) | | (8 | ) | | (98 | ) |
| Less other comprehensive loss attributable to noncontrolling interests | (2 | ) | | — |
| | — |
| | — |
| | — |
| | (2 | ) |
| Balances, December 31, 2014 | (156 | ) | | 218 |
| | (20 | ) | | (58 | ) | | (24 | ) | | (40 | ) |
| Other comprehensive loss before reclassifications | (88 | ) | | (7 | ) | | (42 | ) | | (27 | ) | | — |
| | (164 | ) |
| Amounts reclassified from AOCI | 63 |
| (a) | (37 | ) | (b) | — |
| | — |
| | — |
| | 26 |
|
| Net other comprehensive loss | (25 | ) |
| (44 | ) |
| (42 | ) | | (27 | ) | | — |
| | (138 | ) |
| Less other comprehensive loss attributable to noncontrolling interests | (11 | ) | | — |
| | — |
| | — |
| | — |
| | (11 | ) |
| Balances, December 31, 2015 | (170 | ) | | 174 |
| | (62 | ) | | (85 | ) | | (24 | ) | | (167 | ) |
| Other comprehensive income (loss) before reclassifications | — |
| | 69 |
| | (21 | ) | | (5 | ) | | 2 |
| | 45 |
|
| Amounts reclassified from AOCI | 70 |
| (a) | (18 | ) | (b) | — |
| | — |
| | — |
| | 52 |
|
| Net other comprehensive income (loss) | 70 |
| | 51 |
| | (21 | ) | | (5 | ) | | 2 |
| | 97 |
|
| Less other comprehensive income attributable to noncontrolling interests | — |
| | — |
| | — |
| | — |
| | — |
| | — |
|
| Balances, December 31, 2016 | $ | (100 | ) | | $ | 225 |
| | $ | (83 | ) | | $ | (90 | ) | | $ | (22 | ) | | $ | (70 | ) |
————————————
| |
(a) | Reclassified to interest expense and also to other - net in 2014 and 2015 in NEE's consolidated statements of income. See Note 3 - Income Statement Impact of Derivative Instruments. |
| |
| (b) | Reclassified to gains on disposal of assetsinvestments and other property - net in NEE's consolidated statements of income. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
11. Debt
Long-term debt consists of the following:
|
| | | | | | | |
| | December 31, |
| | 2013 | | 2012 |
| | (millions) |
| FPL: | | | |
| First mortgage bonds - maturing 2017 through 2042 - 2.75% to 6.20% | $ | 7,490 |
| | $ | 7,390 |
|
Storm-recovery bonds - maturing 2017 through 2021 - 5.0440% to 5.2555%(a) | 386 |
| | 439 |
|
Pollution control, solid waste disposal and industrial development revenue bonds - maturing 2020 through 2029 - variable 0.07% and 0.16% weighted-average interest rates, respectively(b)(c) | 633 |
| | 633 |
|
Other long-term debt maturing 2014 through 2040 - primarily variable, 0.66% and 0.66% weighted-average interest rates, respectively(c) | 355 |
| | 355 |
|
| Unamortized discount | (35 | ) | | (35 | ) |
| Total long-term debt of FPL | 8,829 |
| | 8,782 |
|
| Less current maturities of long-term debt | 356 |
| | 453 |
|
| Long-term debt of FPL, excluding current maturities | 8,473 |
| | 8,329 |
|
| NEECH: | |
| | |
|
Debentures - maturing 2015 through 2023 - 1.2% to 7 7/8%(d) | 2,550 |
| | 2,800 |
|
Debentures, related to NEE's equity units - maturing 2014 through 2018 - 1.339% to 1.90%(e) | 2,503 |
| | 2,003 |
|
| Junior subordinated debentures - maturing 2044 through 2073 - 5.00% to 8.75% | 3,353 |
| | 3,253 |
|
Senior secured bonds - maturing 2030 - 7.500%(f) | 500 |
| | 500 |
|
Japanese yen denominated senior notes - maturing 2030 - 5.1325%(d) | 95 |
| | 115 |
|
Japanese yen denominated term loans - maturing 2014 - variable, 1.45% and 1.56% weighted-average interest rates, respectively(c)(d) | 419 |
| | 508 |
|
Term loans - maturing 2014 through 2018 - primarily variable, 1.27% and 1.30% weighted-average interest rates, respectively(c) | 1,815 |
| | 1,563 |
|
| Fair value swaps (see Note 3) | 4 |
| | 75 |
|
| Total long-term debt of NEECH | 11,239 |
| | 10,817 |
|
| Less current maturities of long-term debt | 1,469 |
| | 1,575 |
|
| Long-term debt of NEECH, excluding current maturities | 9,770 |
| | 9,242 |
|
| NEER: | |
| | |
|
| Senior secured limited-recourse bonds and notes - maturing 2017 through 2038 - 4.125% to 7.59% | 2,523 |
| | 2,483 |
|
Senior secured limited-recourse term loans - maturing 2015 through 2031 - primarily variable, 3.15% and 2.77% weighted-average interest rates, respectively(c)(d) | 3,874 |
| | 2,617 |
|
Other long-term debt - maturing 2015 through 2030 - primarily variable, 3.45% and 2.83% weighted-average interest rates, respectively(c)(d)(g) | 808 |
| | 836 |
|
Canadian revolving credit facilities - maturing 2014 and 2016 - variable, 2.33% and 2.33% weighted-average interest rates, respectively(c) | 472 |
| | 413 |
|
| Unamortized discount | (10 | ) | | — |
|
| Total long-term debt of NEER | 7,667 |
| | 6,349 |
|
Less current maturities of long-term debt(g) | 1,941 |
| | 743 |
|
| Long-term debt of NEER, excluding current maturities | 5,726 |
| | 5,606 |
|
| Total long-term debt | $ | 23,969 |
| | $ | 23,177 |
|
|
| | | | | | | | | | | | | | | |
| | | | December 31, |
| | | | 2016 | | 2015 |
| | Maturity
Date | | Balance | | Weighted-
Average
Interest Rate | | Balance | | Weighted-
Average
Interest Rate |
| | | | (millions) | | | | (millions) | | |
| FPL: | | | | | | | | | |
| First mortgage bonds - fixed | 2017 - 2044 | | $ | 8,690 |
| | 4.78 | % | | $ | 8,690 |
| | 4.77 | % |
Storm-recovery bonds - fixed(a) | 2021 | | 210 |
| | 5.26 | % | | 273 |
| | 5.26 | % |
Pollution control, solid waste disposal and industrial development revenue bonds - variable(b) | 2020 - 2046 | | 778 |
| | 0.77 | % | | 718 |
| | 0.04 | % |
Other long-term debt - variable(c) | 2018 - 2019 | | 450 |
| | 1.66 | % | | 400 |
| | 1.11 | % |
| Other long-term debt - fixed | 2016 - 2040 | | 52 |
| | 5.09 | % | | 53 |
| | 5.06 | % |
| Unamortized debt issuance costs and discount | | | (108 | ) | | | | (114 | ) | | |
| Total long-term debt of FPL | | | 10,072 |
| | | | 10,020 |
| | |
| Less current maturities of long-term debt | | | 367 |
| | | | 64 |
| | |
| Long-term debt of FPL, excluding current maturities | | | 9,705 |
| | | | 9,956 |
| | |
| NEECH: | | | | | | | |
| | |
Debentures - fixed(d) | 2017 - 2023 | | 4,100 |
| | 2.87 | % | | 3,100 |
| | 3.15 | % |
| Debentures, related to NEE's equity units - fixed | 2018 - 2021 | | 2,200 |
| | 1.88 | % | | 1,200 |
| | 1.98 | % |
Junior subordinated debentures - primarily fixed(d) | 2044 - 2076 | | 3,460 |
| | 5.40 | % | | 2,978 |
| | 5.84 | % |
Japanese yen denominated senior notes - fixed(d) | 2030 | | 85 |
| | 5.13 | % | | 83 |
| | 5.13 | % |
Japanese yen denominated term loans - variable(c)(d) | 2017 | | 470 |
| | 1.83 | % | | 456 |
| | 1.83 | % |
| Other long-term debt - fixed | 2016 - 2044 | | 924 |
| | 2.45 | % | | 1,307 |
| | 4.55 | % |
Other long-term debt - variable(c) | 2016 - 2019 | | 60 |
| (e) | 1.77 | % | | 1,513 |
| | 1.81 | % |
| Fair value hedge adjustment | | | 8 |
| | | | 24 |
| | |
| Unamortized debt issuance costs and discount | | | (101 | ) | | | | (94 | ) | | |
| Total long-term debt of NEECH | | | 11,206 |
| | | | 10,567 |
| | |
| Less current maturities of long-term debt | | | 1,724 |
| | | | 667 |
| | |
| Long-term debt of NEECH, excluding current maturities | | | 9,482 |
| | | | 9,900 |
| | |
| NEER: | | | | | | | |
| | |
| Senior secured limited-recourse bonds and notes - fixed | 2017 - 2038 | | 2,091 |
| (f) | 6.00 | % | | 2,203 |
| | 5.88 | % |
Senior secured limited-recourse term loans - primarily variable(c)(d) | 2016 - 2035 | | 4,959 |
| | 2.78 | % | | 3,969 |
| (g) | 2.51 | % |
Other long-term debt - primarily variable(c)(d) | 2016 - 2040 | | 2,262 |
| | 2.97 | % | | 2,273 |
| | 2.72 | % |
| Unamortized debt issuance costs and premium - net | | | (168 | ) | | | | (131 | ) | | |
| Total long-term debt of NEER | | | 9,144 |
| | | | 8,314 |
| | |
| Less current maturities of long-term debt | | | 513 |
| | | | 1,489 |
| (h) | |
| Long-term debt of NEER, excluding current maturities | | | 8,631 |
| | | | 6,825 |
| | |
| Total long-term debt | | | $ | 27,818 |
| | | | $ | 26,681 |
| | |
______________________
| |
| (a) | Principal on the storm-recovery bonds is due on the final maturity date (the date by which the principal must be repaid to prevent a default) for each tranche, however, it is being paid semiannually and sequentially. |
| |
| (b) | Tax exempt bonds that permit individual bond holders to tender the bonds for purchase at any time prior to maturity. In the event bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture. If the remarketing is unsuccessful, FPL would be required to purchase the tax exempt bonds. As of December 31, 20132016, all tax exempt bonds tendered for purchase have been successfully remarketed. FPL's bank revolving line of credit facilities are available to support the purchase of tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent. |
| |
| (c) | Variable rate is based on an underlying index plus a margin except for in 2013 approximately $1.1 billion of NEER's senior secured limited-recourse term loans is based on the greater of an underlying index or a floor, plus a margin. |
| |
| (d) | Interest rate contracts, primarily swaps, have been entered into for the majoritywith respect to certain of these debt issuances. Additionally, a foreign currency swap has been entered into with respect to the Japanese yen denominated term loans - variable. See Note 3. |
| |
| (e) | During 2013, the debentures maturingExcludes debt totaling $373 million reflected in 2015 and bearing interest at the rate of 1.90% were remarketed and the interest rate was reset to 1.339% per year. See discussion below.
liabilities associated with assets held for sale on NEE's consolidated balance sheets. |
| |
| (f) | IssuedIncludes approximately $490 million of debt held by a wholly-ownedwholly owned subsidiary of NEECHNEER and collateralized by a third-party note receivable held by that subsidiary. See Note 48 - Fair Value of Financial Instruments Recorded at the Carrying Amount.NEER. |
| |
| (g) | Excludes debt totaling $938 million reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets. See Note 131 - Assets and Liabilities Associated with Assets Held for Sale. |
| |
| (h) | See Spain Solar Projects for discussion of events of default related to debt associated with the Spain solar projects.Debt Restructuring below. |
Minimum annual maturities of long-term debt for NEE are approximately $2,604 million, $2,118 million, $2,606 million, $1,842 million and $2,712 million for 2017, 2018, 2019, 2020 and 2021, respectively. The respective amounts for FPL are approximately $367 million, $347 million, $251 million, $10 million and $47 million.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Minimum annual maturities of long-term debt for NEE are approximately $3,766 million, $2,418 million, $1,782 million, $2,064 million and $1,369 million for 2014, 2015, 2016, 2017 and 2018, respectively. The respective amounts for FPL are approximately $356 million, $60 million, $64 million, $367 million and $72 million.
At December 31, 20132016 and 2012,2015, short-term borrowings had a weighted-average interest rate of 0.20% (0.11%1.07% (1.07% for FPL) and 0.49% (0.27%2.10% (0.83% for FPL), respectively. Available linesSubsidiaries of NEE, including FPL, had credit facilities with available capacity as of December 31, 2016 of approximately $10.2 billion ($3.6 billion for FPL), of which approximately $9.8 billion ($3.6 billion for FPL) relate to revolving line of credit aggregated approximately $7.9facilities and $0.4 billion ($4.9 billion for NEECH and $3.0 billion (none for FPL) at December 31, 2013. Theserelate to letter of credit facilities. Certain of the revolving line of credit facilities provide for the issuance of letters of credit of up to approximately $6.6$3.4 billion ($4.1 ($0.7 billion for NEECH and $2.5 billion for FPL). The issuance of letters of credit under certain revolving line of credit facilities is subject to the aggregate commitment of the relevant banks to issue letters of credit under the applicable facility. While
In February 2017, NEECH entered into two variable rate bi-lateral term loan agreements each providing for a $3.75 billion short-term, non-revolving term loan facility, for a total of $7.5 billion. The obligation to make loans pursuant to these bi-lateral term loan agreements terminates in August 2017 and each loan agreement expires in February 2018. There are currently no direct borrowings were outstanding at December 31, 2013, letters of credit totaling $1,128 million and $3 million wereamounts outstanding under the NEECH and FPL credit facilities, respectively.these facilities.
NEE has guaranteed certain payment obligations of NEECH, including most of those under NEECH's debt, including all of its debentures and commercial paper issuances, as well as most of its payment guarantees and indemnifications. NEECH has guaranteed certain debt and other obligations of NEER and its subsidiaries.
In May 2012, NEE sold $600 million of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series E Debenture due June 1, 2017 issued in the principal amount of $1,000 by NEECH (see table above). Each stock purchase contract requires the holder to purchase by no later than June 1, 2015, (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range of $64.35 to $77.22. If purchased on the final settlement date, as of December 31, 2013, the number of shares issued would (subject to antidilution adjustments) range from 0.7794 shares if the applicable market value of a share of common stock is less than or equal to $64.35, to 0.6495 shares if the applicable market value of a share is equal to or greater than $77.22, with applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending May 27, 2015. Total annual distributions on the equity units will be at the rate of 5.599%, consisting of interest on the debentures (1.70% per year) and payments under the stock purchase contracts (3.899% per year). The interest rate on the debentures is expected to be reset on or after December 1, 2014. The holder of 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.
Also, in May 2012, NEECH completed a remarketing of $350$600 million aggregate principal amount of its Series CE Debentures due June 1, 20142017 (Debentures). The Debentures that were issued in May 20092012 as components of equity units issued concurrently by NEE (2009(May 2012 equity units). The Debentures are fully and unconditionally guaranteed by NEE. In connection with the remarketing of the Debentures, the interest rate on the Debentures was reset to 1.611%1.586% per year, and interest is payable on June 1 and December 1 of each year, commencing June 1, 2012.2015. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the 2009May 2012 equity units, on June 1, 2012,2015, NEE issued 5,400,5007,860,000 shares of common stock in exchange for $350 million.$600 million.
In September 2012, NEE sold $650 million of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series F Debenture due September 1, 2017 issued in the principal amount of $1,000 by NEECH (see table above). Each stock purchase contract requires the holder to purchase by no later than September 1, 2015 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range of $67.15 to $80.58. If purchased on the final settlement date, as of December 31, 2013, the number of shares issued would (subject to antidilution adjustments) range from 0.7468 shares if the applicable market value of a share of common stock is less than or equal to $67.15, to 0.6223 shares if the applicable market value of a share is equal to or greater than $80.58, with applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 27, 2015. Total annual distributions on the equity units will be at the rate of 5.889%, consisting of interest on the debentures (1.60% per year) and payments under the stock purchase contracts (4.289% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2015. The holder of 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.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
In August 2013,2015, NEECH completed a remarketing of approximately $402.4$650 million aggregate principal amount of its Series DF Debentures due September 1, 2015,2017, which constitutes a portion of the $402.5$650 million aggregate principal amount of such debentures (Debentures) that were issued in September 20102012 as components of equity units issued concurrently by NEE (2010(September 2012 equity units). The Debentures are fully and unconditionally guaranteed by NEE. In connection with the remarketing of the Debentures, the interest rate on all of the Debentures was reset to 1.339%2.056% per year and interest is payable on March 1 and September 1 of each year, commencing September 1, 2013.2015. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the 2010September 2012 equity units, in August and September 2013,2015, NEE issued a total of 5,946,5308,173,099 shares of common stock in exchange for $402.5$650 million.
In September 2013,2015, NEE sold $500$700 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 GH Debenture due September 1, 20182020 issued in the principal amount of $1,000 by NEECH (see table above).NEECH. Each stock purchase contract requires the holder to purchase by no later than September 1, 20162018 (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$95.35 to $99.24.$114.42. If purchased on the final settlement date, as of December 31, 2013,2016, the number of shares issued would (subject to antidilution adjustments) range from 0.6046 shares if the applicable market value of a share of common stock is less than or equal to $82.70 to0.50380.5261 shares if the applicable market value of a share isof common stock is less than or equal to $95.35 to 0.4385 shares if the applicable market value of a share is equal to or greater than $99.24,$114.42, with applicable market value to be determined using the average closing prices of NEE common stock overover a 20-day trading period ending August 29, 2016.2018. Total annual distributions on the equity units will be at the rate of 5.799%6.371%, consisting of interest on the debentures (1.45%(2.36% per year) and payments under the stock purchase contracts (4.349%(4.011% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2016. The2018. A holder of thean 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.
In August 2016, NEE sold $1.5 billion 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 I Debenture due September 1, 2021 issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than September 1, 2019 (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 $127.63 to $159.54. If purchased on the final settlement date, as of December 31, 2016, the number of shares issued would (subject to antidilution adjustments) range from 0.3918 shares if the applicable market value of a share of common stock is less than or equal to $127.63 to 0.3134 shares if the applicable market value of a share is equal to or greater than $159.54, with applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 28, 2019. Total annual distributions on the equity units will be at the rate of 6.123%, consisting of interest on the debentures (1.65% per year) and payments under the stock purchase contracts (4.473% per year). The interest rate on the debentures is expected to
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
be reset on or after March 1, 2019. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.
In September 2016, NEECH completed a remarketing of $500 million aggregate principal amount of its Series G Debentures due September 1, 2018 (Debentures) that were issued in September 2013 as components of equity units issued concurrently by NEE (September 2013 equity units). The Debentures are fully and unconditionally guaranteed by NEE. In connection with the remarketing of the Debentures, the interest rate on the Debentures was reset to 1.649% per year, and interest is payable on March 1 and September 1 of each year, commencing March 1, 2017. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the September 2013 equity units, on September 1, 2016, NEE issued 5,101,000 shares of common stock in exchange for $500 million.
Prior to the issuance of NEE’s common stock, the stock purchase contracts, if dilutive, will be reflected in NEE’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of shares of NEE common stock used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon settlement of the stock purchase contracts over the number of shares that could be purchased by NEE in the market, at the average market price during the period, using the proceeds receivable upon settlement.
Spain Solar Projects Debt Restructuring - In August 2016, NextEra Energy España, S.L., the NEER subsidiary in Spain that is the direct shareholder of the subsidiaries that own the solar projects in Spain (project-level subsidiaries), and the project-level subsidiaries entered into an agreement with the lenders to restructure the project-level debt, which included, among other things, a re-amortization of the debt, including extending the maturity date from 2030 to 2037, and reducing the original interest rate under the project-level financing agreements. At closing, the NEECH affiliates' remaining letter of credit posting obligation on behalf of the project-level subsidiaries of approximately €23 million (approximately $26 million) was used primarily to make a prepayment of the restructured project-level debt. The noncurrent portions of the restructured project-level debt, net of unamortized debt issuance costs, and associated derivative liabilities related to the interest rate swaps were both reclassified from current to long-term debt and noncurrent derivative liabilities, respectively, on NEE's consolidated balance sheets as of December 31, 2016 and totaled approximately $498 million and $122 million, respectively, at that date. The restructured debt is secured solely by the assets of the project-level subsidiaries.
12. Asset Retirement Obligations
FPL's ARO relatesAROs relate primarily to the nuclear decommissioning obligationobligations of its nuclear units. FPL's AROs other than nuclear decommissioning obligations are not significant. The accounting provisions result in timing differences in the recognition of legal asset retirement costs for financial reporting purposes and the method the FPSC allows FPL to recover in rates. NEER's ARO relatesAROs relate primarily to the nuclear decommissioning obligationobligations of its nuclear plants and obligations for the dismantlement of certain of its wind facilities located on leased property.and solar facilities. See Note 1 - Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs.
A rollforward of NEE's and FPL's AROAROs is as follows:
|
| | | | | | | | | | | |
| | FPL | | NEER | | NEE |
| | | | (millions) | | |
| Balances, December 31, 2014 | $ | 1,355 |
| | $ | 631 |
| | $ | 1,986 |
|
| Liabilities incurred | 5 |
| | 46 |
| | 51 |
|
| Accretion expense | 73 |
| | 43 |
| | 116 |
|
| Liabilities settled | (20 | ) | | (2 | ) | | (22 | ) |
| Revision in estimated cash flows - net | 409 |
| (a) | (71 | ) | (b) | 338 |
|
| Balances, December 31, 2015 | 1,822 |
| | 647 |
| | 2,469 |
|
| Liabilities incurred | 1 |
| | 56 |
| | 57 |
|
| Accretion expense | 91 |
| | 47 |
| | 138 |
|
| Liabilities settled | — |
| | (2 | ) | | (2 | ) |
| Revision in estimated cash flows - net | 5 |
| | 69 |
| (c) | 74 |
|
| Balances, December 31, 2016 | $ | 1,919 |
| | $ | 817 |
| | $ | 2,736 |
|
______________________
| |
| (a) | Primarily reflects the effect of revised cost estimates for decommissioning FPL's nuclear units consistent with the updated nuclear decommissioning studies approved by the FPSC. |
| |
| (b) | Primarily reflects the effect of revised cost estimates for decommissioning NEER’s nuclear units and a change in assumptions relating to spent fuel costs, partly offset by increased escalation rates. |
| |
| (c) | Primarily reflects the effect of revised cost estimates to dismantle certain of NEER’s wind and solar facilities. |
|
| | | | | | | | | | | |
| | FPL | | NEER | | NEE |
| | | | (millions) | | |
| Balances, December 31, 2011 | $ | 1,144 |
| | $ | 467 |
| | $ | 1,611 |
|
| Liabilities incurred | 9 |
| | 11 |
| | 20 |
|
| Accretion expense | 62 |
| | 32 |
| | 94 |
|
| Liabilities settled | (8 | ) | | — |
| | (8 | ) |
| Revision in estimated cash flows - net | (1 | ) | | (1 | ) | | (2 | ) |
| Balances, December 31, 2012 | 1,206 |
| | 509 |
| | 1,715 |
|
| Liabilities incurred | 1 |
| | 24 |
| | 25 |
|
| Accretion expense | 64 |
| | 35 |
| | 99 |
|
| Liabilities settled | (1 | ) | | (2 | ) | | (3 | ) |
| Revision in estimated cash flows - net | 15 |
| | (1 | ) | | 14 |
|
| Balances, December 31, 2013 | $ | 1,285 |
| | $ | 565 |
| | $ | 1,850 |
|
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Restricted funds for the payment of future expenditures to decommission NEE's and FPL's nuclear units included in special use funds on NEE's and FPL's consolidated balance sheets are as follows (see Note 4)4 - Special Use Funds):
|
| | | | | | | | | | | |
| | FPL | | NEER | | NEE |
| | | | (millions) | | |
| Balances, December 31, 2013 | $ | 3,199 |
| | $ | 1,507 |
| | $ | 4,706 |
|
| Balances, December 31, 2012 | $ | 2,845 |
| | $ | 1,272 |
| | $ | 4,117 |
|
|
| | | | | | | | | | | |
| | FPL | | NEER | | NEE |
| | | | (millions) | | |
| Balances, December 31, 2016 | $ | 3,665 |
| | $ | 1,769 |
| | $ | 5,434 |
|
| Balances, December 31, 2015 | $ | 3,430 |
| | $ | 1,634 |
| | $ | 5,064 |
|
NEE and FPL have identified but not recognized ARO liabilities related to electric transmission and distribution and telecommunications assets resulting from easements over property not owned by NEE or FPL. These easements are generally perpetual and only require retirement action upon abandonment or cessation of use of the property or facility for its specified purpose. The ARO liability is not estimable for such easements as NEE and FPL intend to use these properties indefinitely. In the event NEE and FPL decide to abandon or cease the use of a particular easement, an ARO liability would be recorded at that time.
13. Commitments and Contingencies
Commitments - NEE and its subsidiaries have made commitments in connection with a portion of their projected capital expenditures. Capital expenditures at FPL include, among other things, the cost for construction or acquisition of additional facilities and equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities and the procurement of nuclear fuel. At NEER, capital expenditures include, among other things, the cost, including capitalized interest, for construction and development of wind and solar projects and the procurement of nuclear fuel.fuel, as well as the investment in the development and construction of its natural gas pipeline assets. Capital expenditures for Corporate and Other primarily include the cost for construction of a natural gas pipeline system for new natural gas transportation infrastructure in Florida, as well as the cost to meet customer-specific requirements and maintain the fiber-optic network for the fiber-optic telecommunications business (FPL FiberNet) and the cost to maintain existing transmission facilities at NextEra Energy Transmission, LLC (NEET).
At December 31, 2013,2016, estimated capital expenditures for 20142017 through 20182021 for which applicable internal approvals (and also, if required, FPSC approvals for FPL or regulatory approvals for acquisitions) have been received were as follows:
| | | | 2014 | | 2015 | | 2016 | | 2017 | | 2018 | | Total | 2017 | | 2018 | | 2019 | | 2020 | | 2021 | | Total |
| | (millions) | (millions) |
| FPL: | | | | | | | | | | | | | | | | | | | | | | |
Generation:(a) | | | | | | | | | | | | | | | | | | | | | | |
New(c)(b) | $ | 730 |
| | $ | 255 |
| | $ | 80 |
| | $ | — |
| | $ | — |
| | $ | 1,065 |
| $ | 1,385 |
| | $ | 655 |
| | $ | 485 |
| | $ | 35 |
| | $ | 5 |
| | $ | 2,565 |
|
| Existing | 805 |
| | 680 |
| | 610 |
| | 580 |
| | 545 |
| | 3,220 |
| 1,240 |
| | 635 |
| | 680 |
| | 645 |
| | 600 |
| | 3,800 |
|
| Transmission and distribution | 1,370 |
| | 1,200 |
| | 1,125 |
| | 955 |
| | 1,020 |
| | 5,670 |
| 2,190 |
| | 2,010 |
| | 2,860 |
| | 2,475 |
| | 2,945 |
| | 12,480 |
|
| Nuclear fuel | 140 |
| | 210 |
| | 220 |
| | 225 |
| | 180 |
| | 975 |
| 125 |
| | 190 |
| | 170 |
| | 210 |
| | 120 |
| | 815 |
|
| General and other | 175 |
| | 155 |
| | 120 |
| | 165 |
| | 160 |
| | 775 |
| 440 |
| | 275 |
| | 285 |
| | 220 |
| | 330 |
| | 1,550 |
|
Total(d) | $ | 3,220 |
| | $ | 2,500 |
| | $ | 2,155 |
| | $ | 1,925 |
| | $ | 1,905 |
| | $ | 11,705 |
| $ | 5,380 |
| | $ | 3,765 |
| | $ | 4,480 |
| | $ | 3,585 |
| | $ | 4,000 |
| | $ | 21,210 |
|
| NEER: | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | |
| | |
| | |
| | |
|
Wind(e)(c) | $ | 1,660 |
| | $ | 75 |
| | $ | 5 |
| | $ | 5 |
| | $ | 15 |
| | $ | 1,760 |
| $ | 570 |
| | $ | 955 |
| | $ | 705 |
| | $ | 75 |
| | $ | 25 |
| | $ | 2,330 |
|
Solar(f)(d) | 570 |
| | 740 |
| | 530 |
| | — |
| | — |
| | 1,840 |
| 80 |
| | 75 |
| | 15 |
| | — |
| | — |
| | 170 |
|
Nuclear(g) | 310 |
| | 285 |
| | 300 |
| | 255 |
| | 270 |
| | 1,420 |
| |
Other(h) | 535 |
| | 25 |
| | 75 |
| | 40 |
| | 75 |
| | 750 |
| |
| Nuclear, including nuclear fuel | | 240 |
| | 250 |
| | 230 |
| | 225 |
| | 245 |
| | 1,190 |
|
Natural gas pipelines(e) | | 890 |
| | 845 |
| | 50 |
| | 20 |
| | 10 |
| | 1,815 |
|
| Other | | 335 |
| | 55 |
| | 40 |
| | 40 |
| | 35 |
| | 505 |
|
| Total | $ | 3,075 |
| | $ | 1,125 |
| | $ | 910 |
| | $ | 300 |
| | $ | 360 |
| | $ | 5,770 |
| $ | 2,115 |
| | $ | 2,180 |
| | $ | 1,040 |
| | $ | 360 |
| | $ | 315 |
| | $ | 6,010 |
|
Corporate and Other(i) | $ | 170 |
| | $ | 415 |
| | $ | 735 |
| | $ | 345 |
| | $ | 95 |
| | $ | 1,760 |
| |
| Corporate and Other | | $ | 45 |
| | $ | 30 |
| | $ | 85 |
| | $ | 55 |
| | $ | 35 |
| | $ | 250 |
|
______________________
| |
| (a) | Includes AFUDC of approximately $45$81 million,, $53 $79 million, $46 million and $28$6 million for 20142017 through 2016,2020, respectively. |
| |
| (b) | Includes land, generatinggeneration 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.new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,760 MW. |
| |
| (d) | FPL has identified $1.5 billion to $2.5 billion in potential incremental capital expenditures through 2016 in addition to what is included in the table above.
|
| |
(e) | Consists of capital expenditures for new wind projects and related transmission totaling approximately 1,390 MW, including approximately 465 MW in Canada, that have received applicable internal approvals. NEER expects to add new U.S. wind generation of 2,000 MW to 2,500 MW in 2013 through 2015, including 250 MW added in 2013, at a total cost of approximately $3.5 billion to $4.5 billion.
|
| |
(f) | Consists ofIncludes capital expenditures for new solar projects and related transmission totaling approximately 765 MW that have received applicable internal approvals, including equity contributions associated with a 50% equity investment in a 550 MW solar project. Includes approximately $1 billion of total estimated costs associated with the pending acquisition of the development rights for a 250 MW solar project that is expected to close in early 2014, subject to certain conditions precedent, and construction, which is expected to be completed in 2016. Excludes solar projects requiring internal approvals with generation totaling 40 MW with an estimated cost of approximately $100 million.
225 MW. |
| |
(g) | Includes nuclear fuel. |
| |
(h) | Consists of capital expenditures that have received applicable internal approvals. |
| |
(i)(e) | Includes capital expenditures totaling approximately $1.4 billion for 2014 through 2018 for construction of athree natural gas pipeline system that has received applicable internal approvals,pipelines, including approximately $880 million of equity contributions associated with a 33% equity investmentinvestments in joint ventures for two pipelines and AFUDC associated with the northern portion of the natural gas pipeline system and $520 million for the southern portion, which includes AFUDC of approximately $2 million, $8 million, $20 million and $11 million for 2014 through 2017, respectively.third pipeline. The natural gas pipeline system ispipelines are subject to certain conditions, including FERC approval. A FERC decision is expected in 2015.conditions. See Contracts below. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The above estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.
Contracts - In addition to the commitments made in connection with the estimated capital expenditures included in the table in Commitments above, FPL has commitments under long-term purchased power and fuel contracts. As of December 31, 2013,2016, FPL is obligated under a take-or-pay purchased power contracts with JEA and with subsidiaries of The Southern Company (Southern subsidiaries)contract 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 705114 MW from certain cogenerators and small power producers (qualifying facilities) with expiration dates ranging from 20242026 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
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
are subject to the qualifying facilities meeting certain contract conditions. FPL has contracts with expiration dates through 2036 for the purchase and transportation of natural gas and coal, and storage of natural gas. In addition, FPL has entered into 25-year natural gas transportation agreements with each of Sabal Trail Transmission, LLC (Sabal Trail, an entity in which a NEECHwholly owned NEER subsidiary has a 33%42.5% ownership interest), and Florida Southeast Connection, LLC (Florida Southeast Connection, a wholly-owned NEECHwholly owned NEER subsidiary), each of which will build, own and operate a pipeline that will be part of a natural gas pipeline system, for a quantity of 400,000 MMBtu/day beginning on May 1, 2017mid-2017 and increasing to 600,000 MMBtu/day on May 1, 2020.in mid-2020. These agreements contain firm commitments that are contingent upon the occurrence of certain events, including FERC approval andthe completion of construction of the pipeline system to be built by each of Sabal Trail and Florida Southeast Connection. See Commitments above.
As of December 31, 2013,2016, NEER has entered into contracts with expiration dates ranging from April 2014late February 2017 through 20302032 primarily for the purchase of wind turbines, andwind towers and solar modules and related construction and development activities, as well as for the supply of uranium, and the conversion, enrichment and fabrication of nuclear fuel.fuel and has made commitments for the construction of the natural gas pipelines. Approximately $1.63.1 billion of related 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 March 20142017 through 20332019.
Included in Corporate and Other in the table below is the remaining commitment by a NEECH subsidiary of over $900 million to invest in Sabal Trail for the construction of the northern portion of the natural gas pipeline system. Amounts committed for 2014 through 2018 are also included in the estimated capital expenditures table in Commitments above.
The required capacity and/or minimum payments under the contracts discussed above as of December 31, 20132016 were estimated as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | 2014 | | 2015 | | 2016 | | 2017 | | 2018 | | Thereafter |
| | (millions) |
| FPL: | | | | | | | | | | | |
Capacity charges:(a) | | | | | | | | | | | |
| Qualifying facilities | $ | 285 |
| | $ | 290 |
| | $ | 250 |
| | $ | 255 |
| | $ | 260 |
| | $ | 1,965 |
|
| JEA and Southern subsidiaries | $ | 215 |
| | $ | 195 |
| | $ | 70 |
| | $ | 50 |
| | $ | 10 |
| | $ | — |
|
| Minimum charges, at projected prices: | | | | | | | | | | | |
Natural gas, including transportation and storage(b) | $ | 1,520 |
| | $ | 605 |
| | $ | 550 |
| | $ | 745 |
| | $ | 825 |
| | $ | 14,510 |
|
Coal(b) | $ | 65 |
| | $ | 40 |
| | $ | 20 |
| | $ | — |
| | $ | — |
| | $ | — |
|
| NEER | $ | 1,220 |
| | $ | 145 |
| | $ | 170 |
| | $ | 100 |
| | $ | 105 |
| | $ | 490 |
|
Corporate and Other(c)(d) | $ | 90 |
| | $ | 220 |
| | $ | 460 |
| | $ | 180 |
| | $ | 20 |
| | $ | 55 |
|
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | 2017 | | 2018 | | 2019 | | 2020 | | 2021 | | Thereafter |
| | (millions) |
| FPL: | | | | | | | | | | | |
Capacity charges(a) | $ | 75 |
| | $ | 65 |
| | $ | 50 |
| | $ | 20 |
| | $ | 20 |
| | $ | 250 |
|
Minimum charges, at projected prices:(b) | | | | | | | | | | | |
Natural gas, including transportation and storage(c) | $ | 1,305 |
| | $ | 900 |
| | $ | 900 |
| | $ | 910 |
| | $ | 905 |
| | $ | 12,065 |
|
| Coal, including transportation | $ | 125 |
| | $ | 5 |
| | $ | 5 |
| | $ | — |
| | $ | — |
| | $ | — |
|
| NEER | $ | 1,385 |
| | $ | 1,380 |
| | $ | 140 |
| | $ | 90 |
| | $ | 75 |
| | $ | 285 |
|
Corporate and Other(d)(e) | $ | 45 |
| | $ | 10 |
| | $ | — |
| | $ | 5 |
| | $ | — |
| | $ | — |
|
______________________
| |
| (a) | Capacity charges, under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $487175 million, $523434 million and $511485 million for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively. Energy charges, under these contracts, which are recoverable through the fuel clause, totaled approximately $263126 million, $276262 million and $403299 million for the years ended December 31, 2013, 20122016, 2015 and 2011,2014, respectively. |
| |
| (b) | Recoverable through the fuel clause. |
| |
| (c) | Includes approximately $198$200 million,, $294 $295 million, $290 million, $360 million, $390 million and $8,528$7,495 million in 2017, 2018, 2019, 2020, 2021 and thereafter, respectively, of firm commitments, subject to certain conditions as noted above, related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection. |
| |
(c)(d) | Includes an approximately $5230 million commitment to invest in clean power and technology businesses through 2021.primarily in 2017. |
| |
(d)(e) | Excludes approximately $68263 million, and $148 million in 2014,2017 and 2018, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above. |
In January 2017, FPL assumed ownership of a 330 MW coal-fired generation facility located in Indiantown, Florida for a purchase price of $451 million (including existing debt of approximately $218 million). FPL will record a regulatory asset for approximately $451 million, which will be amortized over nine years and recovered through the capacity clause with a return on the portion of the unamortized balance of the regulatory asset. Prior to assuming ownership of this facility, FPL had a long-term purchased power agreement with this facility for substantially all of its capacity and energy. FPL expects to reduce the plant’s operations with the intention of eventually phasing the plant out of service. FPL will recover the fuel costs of the facility through the fuel clause and operating costs through the capacity clause until FPL's next base rate filing where non-fuel cost recovery will be through base rates.
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 $375450 million of private liability insurance per site, which is the maximum obtainable, and participates in a secondary financial protection system, which provides up to $13.213.0 billion of liability insurance coverage per incident at any nuclear reactor in the United States.U.S. 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,U.S., payable at a rate not to exceed $152 million ($76 million for FPL) per incident per year. NEE and FPL are contractually
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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 $15 million, $38 million and $19 million, plus any applicable taxes, per incident, respectively.
NEE participates in a nuclear insurance mutual company that provides $2.75 billion of limited insurance coverage per occurrence per site for property damage, decontamination and premature decommissioning risks at its nuclear plants and a sublimit of $1.5 billion for non-nuclear perils. The proceeds from such insurance, however, must first be used for reactor stabilization and site decontamination before they can be used for plant repair. NEE also participates in an insurance program that provides limited coverage for replacement power costs if a nuclear plant is out of service for an extended period of time because of an accident. In the event of an accident at one of NEE's or another participating insured's nuclear plants, NEE could be assessed up to $198186 million
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
($($118112 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 either its transmission and distribution property and has no property insurance coverage for FPL FiberNet's fiber-optic cable.or natural gas pipeline assets. 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 February 2017, the FPSC approved FPL's request to recover through an interim surcharge the 2016 eligible storm restoration costs that exceeded the reserve amount. See Note 1 - Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve.
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/orand FPL and/or Lone Star, as the case may be, and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.
Spain Solar Projects - On March 28, 2013 and May 3, 2013, events of default occurred under the project-level financing agreements for the Spain solar projects (project-level financing) as a result of changes of law that occurred in December 2012 and February 2013. These changes of law negatively affected the projected economics of the projects and have caused the project-level financing to be unsupportable by expected future project cash flows. Under the project-level financing, events of default provide for, among other things, a right by the lenders (which they did not exercise for the project-level financing) to accelerate the payment of the project-level debt. Accordingly, in 2013, the project-level debt and the associated derivative liabilities related to interest rate swaps were classified as current maturities of long-term debt and current derivative liabilities, respectively, with balances of $799 million and $93 million, respectively, on NEE's consolidated balance sheets as of December 31, 2013. In July 2013, the Spanish government published a new law that created a new economic framework for the Spanish renewable energy sector. Additional regulatory pronouncements from the Spanish government are needed to complete and implement the framework. In February 2014, a draft of the regulatory pronouncements was made public and is subject to public comment through February 25, 2014. It is uncertain when the final regulatory pronouncements will be issued. At this time, NEE is unable to assess the framework's ultimate impact on the Spain solar projects which could include further impairment of the Spain solar projects and/or a partial refund of tariff revenues collected since July 2013.
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 were limited, as a result of changes of law, to guaranteeing the payment of the remaining unfunded portion of a specified base equity commitment under the project-level financing agreements as opposed to guaranteeing the payment of all debt outstanding under the project-level financing agreements as well as associated interest rate swap breakage and other specified costs. On December 20, 2013, NEECH, NextEra Energy España, S.L. (NEE España), which is the NEER subsidiary in Spain that is the direct shareholder of the project-level subsidiaries, and the project-level subsidiaries entered into agreements with the lenders which settled the lawsuit and terminated all guarantee obligations that the lenders claimed that NEECH had under the project-level financing agreements, thereby limiting all future recourse of the lenders under the project-level financing agreements effectively to the letters of credit described below and to the assets of NEE España and the project-level subsidiaries.
As part of the settlement: (1) the lenders irrevocably waived events of default related to changes of law, including those described above, and agreed not to exercise any rights with respect to any additional events of default that may occur with respect to implementing existing changes of law between the settlement date through June 1, 2014; (2) NEECH affiliates provided for the project-level subsidiaries to post approximately €37 million (approximately $50 million as of December 31, 2013) in letters of credit to fund operating and debt service reserves under the project-level financing agreements and €10 million (approximately $14 million as of December 31, 2013) in a letter of credit to provide support for a performance guarantee under the project-level financing agreements; and (3) an affiliate of NEECH repaid the approximately €155 million (approximately $212 million as of December 20, 2013) outstanding under a variable rate revolving loan agreement that had been used to fund a portion of the base equity commitment under the project-level financing agreements and that had an original maturity date in April 2014, and NEE España’s payment obligations to a NEECH affiliate under the variable rate revolving loan agreement were forgiven.
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
As a result of some of the foregoing actions, NEE España’s net equity was restored to a level above what is required by Spanish law to avoid mandatory liquidation and the shareholder of NEE España rescinded the liquidation process of NEE España that resulted from the impairment recorded due to the changes in law. See Note 4 - Nonrecurring Fair Value Measurements.
NEE España, the project-level subsidiaries and the lenders have agreed to use commercially reasonable efforts to seek to restructure the project-level financing on or before June 1, 2014.
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
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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.
14. 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 operating revenues derived from the sale of electricity represented approximately 92%90%, 93%92% and 95%91% of NEE's operating revenues for the years ended December 31, 20132016, 20122015 and 20112014., respectively. Approximately 1%2% of operating revenues were from foreign sources for each of the three years ended December 31, 20132016, 20122015 and 20112014. At each of December 31, 20132016 and 20122015, approximately 4%3% of long-lived assets were located in foreign countries.
NEE's segment information is as follows:
| | | | 2013 | | 2012 | | 2011 | 2016 | | 2015 | | 2014 |
| | FPL | | NEER(a) | | Corp. and Other | | Total | | FPL | | NEER(a) | | Corp. and Other | | Total | | FPL | | NEER(a) | | Corp. and Other | | Total | FPL | | NEER(a) | | Corp. and Other | | NEE Consoli- dated | | FPL | | NEER(a) | | Corp. and Other | | NEE Consoli- dated | | FPL | | NEER(a) | | Corp. and Other | | NEE Consoli- dated |
| | | | | | | | | | (millions) | | | | | | | | | | | | | | | | | (millions) | | | | | | | | |
| Operating revenues | $ | 10,445 |
| | $ | 4,333 |
| | $ | 358 |
| | $ | 15,136 |
| | $ | 10,114 |
| | $ | 3,895 |
| | $ | 247 |
| | $ | 14,256 |
| | $ | 10,613 |
| | $ | 4,502 |
| | $ | 226 |
| | $ | 15,341 |
| $ | 10,895 |
| | $ | 4,893 |
| | $ | 367 |
| | $ | 16,155 |
| | $ | 11,651 |
| | $ | 5,444 |
| | $ | 391 |
| | $ | 17,486 |
| | $ | 11,421 |
| | $ | 5,196 |
| | $ | 404 |
| | $ | 17,021 |
|
Operating expenses(b) | $ | 7,906 |
| | $ | 3,730 |
| | $ | 259 |
| | $ | 11,895 |
| | $ | 7,757 |
| | $ | 3,024 |
| | $ | 199 |
| | $ | 10,980 |
| | $ | 8,537 |
| | $ | 3,351 |
| | $ | 192 |
| | $ | 12,080 |
| |
| Operating expenses - net | | $ | 7,737 |
| | $ | 3,419 |
| | $ | 391 |
| | $ | 11,547 |
| | $ | 8,674 |
| | $ | 3,865 |
| | $ | 315 |
| | $ | 12,854 |
| | $ | 8,593 |
| | $ | 3,727 |
| | $ | 317 |
| | $ | 12,637 |
|
| Interest expense | $ | 415 |
| | $ | 528 |
| | $ | 178 |
| | $ | 1,121 |
| | $ | 417 |
| | $ | 474 |
| | $ | 147 |
| | $ | 1,038 |
| | $ | 387 |
| | $ | 530 |
| | $ | 118 |
| | $ | 1,035 |
| $ | 456 |
| | $ | 732 |
| | $ | (95 | ) | | $ | 1,093 |
| | $ | 445 |
| | $ | 625 |
| | $ | 141 |
| | $ | 1,211 |
| | $ | 439 |
| | $ | 667 |
| | $ | 155 |
| | $ | 1,261 |
|
| Interest income | $ | 6 |
| | $ | 19 |
| | $ | 53 |
| | $ | 78 |
| | $ | 6 |
| | $ | 20 |
| | $ | 60 |
| | $ | 86 |
| | $ | 3 |
| | $ | 23 |
| | $ | 53 |
| | $ | 79 |
| $ | 2 |
| | $ | 34 |
| | $ | 46 |
| | $ | 82 |
| | $ | 7 |
| | $ | 28 |
| | $ | 51 |
| | $ | 86 |
| | $ | 3 |
| | $ | 26 |
| | $ | 51 |
| | $ | 80 |
|
| Depreciation and amortization | $ | 1,159 |
| | $ | 949 |
| | $ | 55 |
| | $ | 2,163 |
| | $ | 659 |
| | $ | 818 |
| | $ | 41 |
| | $ | 1,518 |
| | $ | 798 |
| | $ | 736 |
| | $ | 33 |
| | $ | 1,567 |
| $ | 1,651 |
| | $ | 1,366 |
| | $ | 60 |
| | $ | 3,077 |
| | $ | 1,576 |
| | $ | 1,183 |
| | $ | 72 |
| | $ | 2,831 |
| | $ | 1,432 |
| | $ | 1,051 |
| | $ | 68 |
| | $ | 2,551 |
|
| Equity in earnings (losses) of equity method investees | $ | — |
| | $ | 26 |
| | $ | (1 | ) | | $ | 25 |
| | $ | — |
| | $ | 19 |
| | $ | (6 | ) | | $ | 13 |
| | $ | — |
| | $ | 55 |
| | $ | — |
| | $ | 55 |
| $ | — |
| | $ | 119 |
| | $ | 29 |
| | $ | 148 |
| | $ | — |
| | $ | 103 |
| | $ | 4 |
| | $ | 107 |
| | $ | — |
| | $ | 95 |
| | $ | (2 | ) | | $ | 93 |
|
Income tax expense (benefit)(d)(b) | $ | 835 |
| | $ | (16 | ) | | $ | (18 | ) | | $ | 801 |
| | $ | 752 |
| | $ | (7 | ) | | $ | (53 | ) | | $ | 692 |
| | $ | 654 |
| | $ | (24 | ) | | $ | (101 | ) | | $ | 529 |
| $ | 1,051 |
| | $ | 242 |
| | $ | 90 |
| | $ | 1,383 |
| | $ | 957 |
| | $ | 289 |
| | $ | (18 | ) | | $ | 1,228 |
| | $ | 910 |
| | $ | 283 |
| | $ | (17 | ) | | $ | 1,176 |
|
Income (loss) from continuing operations(b)(e) | $ | 1,349 |
| | $ | 381 |
| | $ | (10 | ) | | $ | 1,720 |
| | $ | 1,240 |
| | $ | 687 |
| | $ | (16 | ) | | $ | 1,911 |
| | $ | 1,068 |
| | $ | 774 |
| | $ | 81 |
| | $ | 1,923 |
| |
Net gain from discontinued operations, net of income taxes(f) | $ | — |
| | $ | 175 |
| | $ | 13 |
| | $ | 188 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | — |
| |
Net income (loss)(b)(e) | $ | 1,349 |
| | $ | 556 |
| | $ | 3 |
| | $ | 1,908 |
| | $ | 1,240 |
| | $ | 687 |
| | $ | (16 | ) | | $ | 1,911 |
| | $ | 1,068 |
| | $ | 774 |
| | $ | 81 |
| | $ | 1,923 |
| |
| Net income (loss) | | $ | 1,727 |
| | $ | 1,218 |
| | $ | 60 |
| | $ | 3,005 |
| | $ | 1,648 |
| | $ | 1,102 |
| | $ | 12 |
| | $ | 2,762 |
| | $ | 1,517 |
| | $ | 993 |
| | $ | (41 | ) | | $ | 2,469 |
|
| Net income (loss) attributable to NEE | | $ | 1,727 |
| | $ | 1,125 |
| | $ | 60 |
| | $ | 2,912 |
| | $ | 1,648 |
| | $ | 1,092 |
| | $ | 12 |
| | $ | 2,752 |
| | $ | 1,517 |
| | $ | 989 |
| | $ | (41 | ) | | $ | 2,465 |
|
| Capital expenditures, independent power and other investments and nuclear fuel purchases | $ | 2,903 |
| | $ | 3,613 |
| | $ | 166 |
| | $ | 6,682 |
| | $ | 4,285 |
| | $ | 4,681 |
| | $ | 495 |
| | $ | 9,461 |
| | $ | 3,502 |
| | $ | 2,774 |
| | $ | 352 |
| | $ | 6,628 |
| $ | 3,934 |
| | $ | 5,521 |
| | $ | 181 |
| | $ | 9,636 |
| | $ | 3,633 |
| | $ | 4,661 |
| | $ | 83 |
| | $ | 8,377 |
| | $ | 3,241 |
| | $ | 3,701 |
| | $ | 75 |
| | $ | 7,017 |
|
| Property, plant and equipment | $ | 39,896 |
| | $ | 28,080 |
| | $ | 1,472 |
| | $ | 69,448 |
| | $ | 38,249 |
| | $ | 25,333 |
| | $ | 1,335 |
| | $ | 64,917 |
| | $ | 35,170 |
| | $ | 21,482 |
| | $ | 900 |
| | $ | 57,552 |
| $ | 48,313 |
| | $ | 37,644 |
| | $ | 1,056 |
| | $ | 87,013 |
| | $ | 45,383 |
| | $ | 33,340 |
| | $ | 1,607 |
| | $ | 80,330 |
| | $ | 41,938 |
| | $ | 30,178 |
| | $ | 1,523 |
| | $ | 73,639 |
|
| Accumulated depreciation and amortization | $ | 10,944 |
| | $ | 5,455 |
| | $ | 329 |
| | $ | 16,728 |
| | $ | 10,698 |
| | $ | 4,535 |
| | $ | 271 |
| | $ | 15,504 |
| | $ | 10,916 |
| | $ | 3,914 |
| | $ | 232 |
| | $ | 15,062 |
| $ | 12,304 |
| | $ | 7,655 |
| | $ | 142 |
| | $ | 20,101 |
| | $ | 11,862 |
| | $ | 6,640 |
| | $ | 442 |
| | $ | 18,944 |
| | $ | 11,282 |
| | $ | 6,268 |
| | $ | 384 |
| | $ | 17,934 |
|
Total assets(g) | $ | 36,488 |
| | $ | 30,154 |
| | $ | 2,664 |
| | $ | 69,306 |
| | $ | 34,853 |
| | $ | 27,139 |
| | $ | 2,447 |
| | $ | 64,439 |
| | $ | 31,816 |
| | $ | 23,459 |
| | $ | 1,913 |
| | $ | 57,188 |
| |
| Total assets | | $ | 45,501 |
| | $ | 41,743 |
| | $ | 2,749 |
| | $ | 89,993 |
| | $ | 42,523 |
| | $ | 37,647 |
| | $ | 2,309 |
| | $ | 82,479 |
| | $ | 39,222 |
| | $ | 32,896 |
| | $ | 2,487 |
| | $ | 74,605 |
|
| Investment in equity method investees | $ | — |
| | $ | 365 |
| | $ | 57 |
| | $ | 422 |
| | $ | — |
| | $ | 243 |
| | $ | 19 |
| | $ | 262 |
| | $ | — |
| | $ | 193 |
| | $ | 9 |
| | $ | 202 |
| $ | — |
| | $ | 1,661 |
| | $ | 106 |
| | $ | 1,767 |
| | $ | — |
| | $ | 983 |
| | $ | 80 |
| | $ | 1,063 |
| | $ | — |
| | $ | 617 |
| | $ | 46 |
| | $ | 663 |
|
_______________________________________________
| |
| (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-utilityNEECH corporate interest expense is included in Corporate and Other. |
| |
| (b) | NEER includes impairment charges of $300 million and other related charges ($342 million after-tax) in 2013 and impairment charges of $51 million ($31 million after-tax) in 2011. See Note 4 - Nonrecurring Fair Value Measurements.
|
| |
(c) | NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes. |
| |
(d) | In 2011, Corporate and Other includes state deferred income tax benefits of approximately $64 million, net of federal income taxes, related to state tax law changes and an income tax benefit of $41 million related to the dissolution of a subsidiary.
|
| |
(e) | In 2011, NEER and Corporate and Other include an after-tax loss on sale of natural gas-fired generating assets of $92 million and $6 million, respectively. See Note 4 - Nonrecurring Fair Value Measurements.
|
| |
(g) | In 2012, NEER includes assets held for sale of approximately $335 million. See Note 6.
|
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
15. 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 itsNEECH’s debentures and payment guaranteesjunior subordinated debentures including those that were registered pursuant to the Securities Act of 1933, as amended, are fully and unconditionally guaranteed by NEE. Condensed consolidating financial information is as follows:
Condensed Consolidating Statements of Income
| | | | Year Ended
December 31, 2013 | | Year Ended
December 31, 2012 | | Year Ended
December 31, 2011 | Year Ended
December 31, 2016 | | Year Ended
December 31, 2015 | | Year Ended
December 31, 2014 |
| | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated |
| | (millions) | (millions) |
| Operating revenues | $ | — |
| | $ | 4,703 |
| | $ | 10,433 |
| | $ | 15,136 |
| | $ | — |
| | $ | 4,154 |
| | $ | 10,102 |
| | $ | 14,256 |
| | $ | — |
| | $ | 4,740 |
| | $ | 10,601 |
| | $ | 15,341 |
| $ | — |
| | $ | 5,283 |
| | $ | 10,872 |
| | $ | 16,155 |
| | $ | — |
| | $ | 5,849 |
| | $ | 11,637 |
| | $ | 17,486 |
| | $ | — |
| | $ | 5,614 |
| | $ | 11,407 |
| | $ | 17,021 |
|
| Operating expenses | (18 | ) | | (3,984 | ) | | (7,893 | ) | | (11,895 | ) | | (21 | ) | | (3,214 | ) | | (7,745 | ) | | (10,980 | ) | | (15 | ) | | (3,540 | ) | | (8,525 | ) | | (12,080 | ) | |
| Operating expenses - net | | (20 | ) | | (3,663 | ) | | (7,864 | ) | | (11,547 | ) | | (17 | ) | | (4,142 | ) | | (8,695 | ) | | (12,854 | ) | | (19 | ) | | (4,039 | ) | | (8,579 | ) | | (12,637 | ) |
| Interest expense | (8 | ) | | (705 | ) | | (408 | ) | | (1,121 | ) | | (11 | ) | | (619 | ) | | (408 | ) | | (1,038 | ) | | (14 | ) | | (645 | ) | | (376 | ) | | (1,035 | ) | (1 | ) | | (636 | ) | | (456 | ) | | (1,093 | ) | | (4 | ) | | (764 | ) | | (443 | ) | | (1,211 | ) | | (6 | ) | | (819 | ) | | (436 | ) | | (1,261 | ) |
| Equity in earnings of subsidiaries | 1,915 |
| | — |
| | (1,915 | ) | | — |
| | 1,925 |
| | — |
| | (1,925 | ) | | — |
| | 1,878 |
| | — |
| | (1,878 | ) | | — |
| 2,956 |
| | — |
| | (2,956 | ) | | — |
| | 2,754 |
| | — |
| | (2,754 | ) | | — |
| | 2,494 |
| | — |
| | (2,494 | ) | | — |
|
| Other income (deductions) - net | 1 |
| | 349 |
| | 51 |
| | 401 |
| | 7 |
| | 313 |
| | 45 |
| | 365 |
| | 1 |
| | 202 |
| | 23 |
| | 226 |
| |
| Income (loss) from continuing operations before income taxes | 1,890 |
| | 363 |
| | 268 |
| | 2,521 |
| | 1,900 |
| | 634 |
| | 69 |
| | 2,603 |
| | 1,850 |
| | 757 |
| | (155 | ) | | 2,452 |
| |
| Other income - net | | 5 |
| | 793 |
| | 75 |
| | 873 |
| | 1 |
| | 498 |
| | 70 |
| | 569 |
| | 1 |
| | 487 |
| | 34 |
| | 522 |
|
| Income (loss) before income taxes | | 2,940 |
| | 1,777 |
| | (329 | ) | | 4,388 |
| | 2,734 |
| | 1,441 |
| | (185 | ) | | 3,990 |
| | 2,470 |
| | 1,243 |
| | (68 | ) | | 3,645 |
|
| Income tax expense (benefit) | (5 | ) | | (29 | ) | | 835 |
| | 801 |
| | (11 | ) | | (50 | ) | | 753 |
| | 692 |
| | (73 | ) | | (53 | ) | | 655 |
| | 529 |
| 28 |
| | 354 |
| | 1,001 |
| | 1,383 |
| | (18 | ) | | 299 |
| | 947 |
| | 1,228 |
| | 5 |
| | 262 |
| | 909 |
| | 1,176 |
|
| Income (loss) from continuing operations | 1,895 |
| | 392 |
| | (567 | ) | | 1,720 |
| | 1,911 |
| | 684 |
| | (684 | ) | | 1,911 |
| | 1,923 |
| | 810 |
| | (810 | ) | | 1,923 |
| |
| Net gain from discontinued operations, net of income taxes | 13 |
| | 175 |
| | — |
| | 188 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| |
| Net income (loss) | $ | 1,908 |
| | $ | 567 |
| | $ | (567 | ) | | $ | 1,908 |
| | $ | 1,911 |
| | $ | 684 |
| | $ | (684 | ) | | $ | 1,911 |
| | $ | 1,923 |
| | $ | 810 |
| | $ | (810 | ) | | $ | 1,923 |
| 2,912 |
| | 1,423 |
| | (1,330 | ) | | 3,005 |
| | 2,752 |
| | 1,142 |
| | (1,132 | ) | | 2,762 |
| | 2,465 |
| | 981 |
| | (977 | ) | | 2,469 |
|
| Less net income attributable to noncontrolling interests | | — |
| | 93 |
| | — |
| | 93 |
| | — |
| | 10 |
| | — |
| | 10 |
| | — |
| | 4 |
| | — |
| | 4 |
|
| Net income (loss) attributable to NEE | | $ | 2,912 |
| | $ | 1,330 |
| | $ | (1,330 | ) | | $ | 2,912 |
| | $ | 2,752 |
| | $ | 1,132 |
| | $ | (1,132 | ) | | $ | 2,752 |
| | $ | 2,465 |
| | $ | 977 |
| | $ | (977 | ) | | $ | 2,465 |
|
______________________
| |
| (a) | Represents primarily FPL and consolidating adjustments. |
Condensed Consolidating Statements of Comprehensive Income
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Year Ended
December 31, 2013 | | Year Ended
December 31, 2012 | | Year Ended
December 31, 2011 |
| | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated |
| | (millions) |
| Comprehensive income (loss) | $ | 2,219 |
| | $ | 781 |
| | $ | (781 | ) | | $ | 2,219 |
| | $ | 1,810 |
| | $ | 611 |
| | $ | (611 | ) | | $ | 1,810 |
| | $ | 1,603 |
| | $ | 535 |
| | $ | (535 | ) | | $ | 1,603 |
|
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Year Ended
December 31, 2016 | | Year Ended
December 31, 2015 | | Year Ended
December 31, 2014 |
| | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE
(Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated |
| | (millions) |
| Comprehensive income (loss) attributable to NEE | $ | 3,009 |
| | $ | 1,448 |
| | $ | (1,448 | ) | | $ | 3,009 |
| | $ | 2,625 |
| | $ | 1,049 |
| | $ | (1,049 | ) | | $ | 2,625 |
| | $ | 2,369 |
| | $ | 924 |
| | $ | (924 | ) | | $ | 2,369 |
|
______________________
| |
| (a) | Represents primarily FPL and consolidating adjustments. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed Consolidating Balance Sheets
| | | | December 31, 2013 | | December 31, 2012 | December 31, 2016 | | December 31, 2015 |
| | NEE (Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE (Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | NEE (Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated | | NEE (Guaran-
tor) | | NEECH | | Other(a) | | NEE
Consoli-
dated |
| | (millions) | (millions) |
| PROPERTY, PLANT AND EQUIPMENT | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Electric plant in service and other property | $ | 31 |
| | $ | 29,511 |
| | $ | 39,906 |
| | $ | 69,448 |
| | $ | 31 |
| | $ | 26,638 |
| | $ | 38,248 |
| | $ | 64,917 |
| $ | 28 |
| | $ | 38,671 |
| | $ | 48,314 |
| | $ | 87,013 |
| | $ | 27 |
| | $ | 34,921 |
| | $ | 45,382 |
| | $ | 80,330 |
|
| Less accumulated depreciation and amortization | (10 | ) | | (5,774 | ) | | (10,944 | ) | | (16,728 | ) | | (7 | ) | | (4,800 | ) | | (10,697 | ) | | (15,504 | ) | |
| Accumulated depreciation and amortization | | (18 | ) | | (7,778 | ) | | (12,305 | ) | | (20,101 | ) | | (16 | ) | | (7,067 | ) | | (11,861 | ) | | (18,944 | ) |
| Total property, plant and equipment - net | 21 |
| | 23,737 |
| | 28,962 |
| | 52,720 |
| | 24 |
| | 21,838 |
| | 27,551 |
| | 49,413 |
| 10 |
| | 30,893 |
| | 36,009 |
| | 66,912 |
| | 11 |
| | 27,854 |
| | 33,521 |
| | 61,386 |
|
| CURRENT ASSETS | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | | | | | | | |
| | |
| | |
|
| Cash and cash equivalents | — |
| | 418 |
| | 20 |
| | 438 |
| | 2 |
| | 287 |
| | 40 |
| | 329 |
| 1 |
| | 1,258 |
| | 33 |
| | 1,292 |
| | — |
| | 546 |
| | 25 |
| | 571 |
|
| Receivables | 78 |
| | 1,542 |
| | 669 |
| | 2,289 |
| | 398 |
| | 1,208 |
| | 450 |
| | 2,056 |
| 88 |
| | 1,615 |
| | 736 |
| | 2,439 |
| | 90 |
| | 1,510 |
| | 665 |
| | 2,265 |
|
| Other | 6 |
| | 1,814 |
| | 1,295 |
| | 3,115 |
| | 432 |
| | 1,421 |
| | 999 |
| | 2,852 |
| 2 |
| | 1,877 |
| | 1,799 |
| | 3,678 |
| | 4 |
| | 2,443 |
| | 1,512 |
| | 3,959 |
|
| Total current assets | 84 |
| | 3,774 |
| | 1,984 |
| | 5,842 |
| | 832 |
| | 2,916 |
| | 1,489 |
| | 5,237 |
| 91 |
| | 4,750 |
| | 2,568 |
| | 7,409 |
| | 94 |
| | 4,499 |
| | 2,202 |
| | 6,795 |
|
| OTHER ASSETS | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | | | | | | | |
| | |
| | |
|
| Investment in subsidiaries | 17,910 |
| | — |
| | (17,910 | ) | | — |
| | 16,064 |
| | — |
| | (16,064 | ) | | — |
| 24,323 |
| | — |
| | (24,323 | ) | | — |
| | 22,544 |
| | — |
| | (22,544 | ) | | — |
|
| Other | 694 |
| | 5,129 |
| | 4,921 |
| | 10,744 |
| | 647 |
| | 4,749 |
| | 4,393 |
| | 9,789 |
| 867 |
| | 8,992 |
| | 5,813 |
| | 15,672 |
| | 823 |
| | 7,790 |
| | 5,685 |
| | 14,298 |
|
| Total other assets | 18,604 |
| | 5,129 |
| | (12,989 | ) | | 10,744 |
| | 16,711 |
| | 4,749 |
| | (11,671 | ) | | 9,789 |
| 25,190 |
| | 8,992 |
| | (18,510 | ) | | 15,672 |
| | 23,367 |
| | 7,790 |
| | (16,859 | ) | | 14,298 |
|
| TOTAL ASSETS | $ | 18,709 |
| | $ | 32,640 |
| | $ | 17,957 |
| | $ | 69,306 |
| | $ | 17,567 |
| | $ | 29,503 |
| | $ | 17,369 |
| | $ | 64,439 |
| $ | 25,291 |
| | $ | 44,635 |
| | $ | 20,067 |
| | $ | 89,993 |
| | $ | 23,472 |
| | $ | 40,143 |
| | $ | 18,864 |
| | $ | 82,479 |
|
| CAPITALIZATION | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | | | | | | | |
| | |
| | |
|
| Common shareholders' equity | $ | 18,040 |
| | $ | 4,816 |
| | $ | (4,816 | ) | | $ | 18,040 |
| | $ | 16,068 |
| | $ | 3,533 |
| | $ | (3,533 | ) | | $ | 16,068 |
| $ | 24,341 |
| | $ | 7,699 |
| | $ | (7,699 | ) | | $ | 24,341 |
| | $ | 22,574 |
| | $ | 6,990 |
| | $ | (6,990 | ) | | $ | 22,574 |
|
| Noncontrolling interests | | — |
| | 990 |
| | — |
| | 990 |
| | — |
| | 538 |
| | — |
| | 538 |
|
| Long-term debt | — |
| | 15,496 |
| | 8,473 |
| | 23,969 |
| | — |
| | 14,848 |
| | 8,329 |
| | 23,177 |
| — |
| | 18,112 |
| | 9,706 |
| | 27,818 |
| | — |
| | 16,725 |
| | 9,956 |
| | 26,681 |
|
| Total capitalization | 18,040 |
| | 20,312 |
| | 3,657 |
| | 42,009 |
| | 16,068 |
| | 18,381 |
| | 4,796 |
| | 39,245 |
| 24,341 |
| | 26,801 |
| | 2,007 |
| | 53,149 |
| | 22,574 |
| | 24,253 |
| | 2,966 |
| | 49,793 |
|
| CURRENT LIABILITIES | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | | | | | | | |
| | |
| | |
|
| Debt due within one year | — |
| | 3,896 |
| | 561 |
| | 4,457 |
| | — |
| | 3,624 |
| | 558 |
| | 4,182 |
| — |
| | 2,237 |
| | 785 |
| | 3,022 |
| | — |
| | 2,786 |
| | 220 |
| | 3,006 |
|
| Accounts payable | — |
| | 589 |
| | 611 |
| | 1,200 |
| | 1 |
| | 667 |
| | 613 |
| | 1,281 |
| 1 |
| | 2,668 |
| | 778 |
| | 3,447 |
| | 4 |
| | 1,919 |
| | 606 |
| | 2,529 |
|
| Other | 199 |
| | 2,203 |
| | 1,130 |
| | 3,532 |
| | 440 |
| | 2,317 |
| | 659 |
| | 3,416 |
| 231 |
| | 2,624 |
| | 1,595 |
| | 4,450 |
| | 252 |
| | 3,003 |
| | 1,317 |
| | 4,572 |
|
| Total current liabilities | 199 |
| | 6,688 |
| | 2,302 |
| | 9,189 |
| | 441 |
| | 6,608 |
| | 1,830 |
| | 8,879 |
| 232 |
| | 7,529 |
| | 3,158 |
| | 10,919 |
| | 256 |
| | 7,708 |
| | 2,143 |
| | 10,107 |
|
| OTHER LIABILITIES AND DEFERRED CREDITS | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | | | | | | | |
| | |
| | |
|
| Asset retirement obligations | — |
| | 565 |
| | 1,285 |
| | 1,850 |
| | — |
| | 508 |
| | 1,207 |
| | 1,715 |
| — |
| | 816 |
| | 1,920 |
| | 2,736 |
| | — |
| | 647 |
| | 1,822 |
| | 2,469 |
|
| Deferred income taxes | 166 |
| | 1,963 |
| | 6,015 |
| | 8,144 |
| | 497 |
| | 891 |
| | 5,315 |
| | 6,703 |
| 82 |
| | 3,002 |
| | 8,017 |
| | 11,101 |
| | 157 |
| | 2,396 |
| | 7,274 |
| | 9,827 |
|
| Other | 304 |
| | 3,112 |
| | 4,698 |
| | 8,114 |
| | 561 |
| | 3,115 |
| | 4,221 |
| | 7,897 |
| 636 |
| | 6,487 |
| | 4,965 |
| | 12,088 |
| | 485 |
| | 5,139 |
| | 4,659 |
| | 10,283 |
|
| Total other liabilities and deferred credits | 470 |
| | 5,640 |
| | 11,998 |
| | 18,108 |
| | 1,058 |
| | 4,514 |
| | 10,743 |
| | 16,315 |
| 718 |
| | 10,305 |
| | 14,902 |
| | 25,925 |
| | 642 |
| | 8,182 |
| | 13,755 |
| | 22,579 |
|
| COMMITMENTS AND CONTINGENCIES | | | | | | | | | | | | | | | |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
| TOTAL CAPITALIZATION AND LIABILITIES | $ | 18,709 |
| | $ | 32,640 |
| | $ | 17,957 |
| | $ | 69,306 |
| | $ | 17,567 |
| | $ | 29,503 |
| | $ | 17,369 |
| | $ | 64,439 |
| $ | 25,291 |
| | $ | 44,635 |
| | $ | 20,067 |
| | $ | 89,993 |
| | $ | 23,472 |
| | $ | 40,143 |
| | $ | 18,864 |
| | $ | 82,479 |
|
______________________
| |
| (a) | Represents primarily FPL and consolidating adjustments. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed Consolidating Statements of Cash Flows
| | | | Year Ended
December 31, 2013 | | Year Ended
December 31, 2012 | | Year Ended
December 31, 2011 | Year Ended
December 31, 2016 | | Year Ended
December 31, 2015 | | Year Ended
December 31, 2014 |
| | NEE (Guar- antor) | | NEECH | | Other(a) | | NEE Consoli- dated | | NEE (Guar- antor) | | NEECH | | Other(a) | | NEE Consoli- dated | | NEE (Guar- antor) | | NEECH | | Other(a) | | NEE Consoli- dated | NEE (Guar- antor) | | NEECH | | Other(a) | | NEE Consoli- dated | | NEE (Guar- antor) | | NEECH | | Other(a) | | NEE Consoli- dated | | NEE (Guar- antor) | | NEECH | | Other(a) | | NEE Consoli- dated |
| | (millions) | (millions) |
| NET CASH PROVIDED BY OPERATING ACTIVITIES | $ | 1,147 |
| | $ | 1,466 |
| | $ | 2,489 |
| | $ | 5,102 |
| | $ | 1,166 |
| | $ | 1,091 |
| | $ | 1,735 |
| | $ | 3,992 |
| | $ | 1,681 |
| | $ | 1,446 |
| | $ | 947 |
| | $ | 4,074 |
| $ | 1,897 |
| | $ | 2,171 |
| | $ | 2,268 |
| | $ | 6,336 |
| | $ | 1,659 |
| | $ | 2,488 |
| | $ | 1,969 |
| | $ | 6,116 |
| | $ | 1,615 |
| | $ | 1,976 |
| | $ | 1,909 |
| | $ | 5,500 |
|
| CASH FLOWS FROM INVESTING ACTIVITIES | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Capital expenditures, independent power and other investments and nuclear fuel purchases | — |
| | (3,756 | ) | | (2,926 | ) | | (6,682 | ) | | — |
| | (5,176 | ) | | (4,285 | ) | | (9,461 | ) | | (16 | ) | | (3,109 | ) | | (3,503 | ) | | (6,628 | ) | (1 | ) | | (5,701 | ) | | (3,934 | ) | | (9,636 | ) | | — |
| | (4,744 | ) | | (3,633 | ) | | (8,377 | ) | | (1 | ) | | (3,741 | ) | | (3,275 | ) | | (7,017 | ) |
| Capital contributions from NEE | (777 | ) | | — |
| | 777 |
| | — |
| | (440 | ) | | — |
| | 440 |
| | — |
| | (410 | ) | | — |
| | 410 |
| | — |
| (745 | ) | | — |
| | 745 |
| | — |
| | (1,480 | ) | | — |
| | 1,480 |
| | — |
| | (912 | ) | | — |
| | 912 |
| | — |
|
| Cash grants under the Recovery Act | — |
| | 165 |
| | — |
| | 165 |
| | — |
| | 196 |
| | — |
| | 196 |
| | — |
| | 406 |
| | 218 |
| | 624 |
| — |
| | 335 |
| | — |
| | 335 |
| | — |
| | 8 |
| | — |
| | 8 |
| | — |
| | 343 |
| | — |
| | 343 |
|
| Sale of independent power investments | — |
| | 165 |
| | — |
| | 165 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | 1,204 |
| | — |
| | 1,204 |
| |
| Change in loan proceeds restricted for construction | — |
| | 228 |
| | — |
| | 228 |
| | — |
| | 314 |
| | — |
| | 314 |
| | — |
| | (565 | ) | | — |
| | (565 | ) | |
| Sale of independent power and other investments of NEER | | — |
| | 658 |
| | — |
| | 658 |
| | — |
| | 52 |
| | — |
| | 52 |
| | — |
| | 307 |
| | — |
| | 307 |
|
| Proceeds from sale or maturity of securities in special use funds and other investments | | — |
| | 1,281 |
| | 2,495 |
| | 3,776 |
| | — |
| | 1,120 |
| | 3,731 |
| | 4,851 |
| | — |
| | 1,272 |
| | 3,349 |
| | 4,621 |
|
| Purchases of securities in special use funds and other investments | | — |
| | (1,323 | ) | | (2,506 | ) | | (3,829 | ) | | — |
| | (1,190 | ) | | (3,792 | ) | | (4,982 | ) | | — |
| | (1,321 | ) | | (3,446 | ) | | (4,767 | ) |
| Proceeds from the sale of a noncontrolling interest in subsidiaries | | — |
| | 645 |
| | — |
| | 645 |
| | — |
| | 345 |
| | — |
| | 345 |
| | — |
| | 438 |
| | — |
| | 438 |
|
| Other - net | — |
| | 17 |
| | (16 | ) | | 1 |
| | 1 |
| | 20 |
| | 2 |
| | 23 |
| | 16 |
| | 60 |
| | 10 |
| | 86 |
| — |
| | (40 | ) | | (19 | ) | | (59 | ) | | — |
| | 106 |
| | (8 | ) | | 98 |
| | 10 |
| | (64 | ) | | (232 | ) | | (286 | ) |
| Net cash used in investing activities | (777 | ) | | (3,181 | ) | | (2,165 | ) | | (6,123 | ) | | (439 | ) | | (4,646 | ) | | (3,843 | ) | | (8,928 | ) | | (410 | ) | | (2,004 | ) | | (2,865 | ) | | (5,279 | ) | (746 | ) | | (4,145 | ) | | (3,219 | ) | | (8,110 | ) | | (1,480 | ) | | (4,303 | ) | | (2,222 | ) | | (8,005 | ) | | (903 | ) | | (2,766 | ) | | (2,692 | ) | | (6,361 | ) |
| CASH FLOWS FROM FINANCING ACTIVITIES | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
|
| Issuances of long-term debt | — |
| | 3,874 |
| | 497 |
| | 4,371 |
| | — |
| | 5,334 |
| | 1,296 |
| | 6,630 |
| | — |
| | 3,100 |
| | 840 |
| | 3,940 |
| — |
| | 5,349 |
| | 308 |
| | 5,657 |
| | — |
| | 4,689 |
| | 1,083 |
| | 5,772 |
| | — |
| | 4,057 |
| | 997 |
| | 5,054 |
|
| Retirements of long-term debt | — |
| | (1,943 | ) | | (453 | ) | | (2,396 | ) | | — |
| | (1,562 | ) | | (50 | ) | | (1,612 | ) | | — |
| | (2,076 | ) | | (45 | ) | | (2,121 | ) | — |
| | (3,048 | ) | | (262 | ) | | (3,310 | ) | | — |
| | (3,421 | ) | | (551 | ) | | (3,972 | ) | | — |
| | (4,395 | ) | | (355 | ) | | (4,750 | ) |
| Proceeds from sale of differential membership interests | — |
| | 448 |
| | — |
| | 448 |
| | — |
| | 808 |
| | — |
| | 808 |
| | — |
| | 466 |
| | — |
| | 466 |
| |
| Net change in short-term debt | — |
| | (819 | ) | | 99 |
| | (720 | ) | | — |
| | 286 |
| | (225 | ) | | 61 |
| | — |
| | 231 |
| | 229 |
| | 460 |
| |
| Issuances of common stock | 842 |
| | — |
| | — |
| | 842 |
| | 405 |
| | — |
| | — |
| | 405 |
| | 48 |
| | — |
| | — |
| | 48 |
| |
| Proceeds from differential membership investors | | — |
| | 1,859 |
| | — |
| | 1,859 |
| | — |
| | 761 |
| | — |
| | 761 |
| | — |
| | 978 |
| | — |
| | 978 |
|
| Proceeds from other short-term debt | | — |
| | — |
| | 500 |
| | 500 |
| | — |
| | 1,125 |
| | 100 |
| | 1,225 |
| | — |
| | 500 |
| | — |
| | 500 |
|
| Repayments of other short-term debt | | — |
| | (212 | ) | | (450 | ) | | (662 | ) | | — |
| | (813 | ) | | — |
| | (813 | ) | | — |
| | (500 | ) | | — |
| | (500 | ) |
| Net change in commercial paper | | — |
| | (318 | ) | | 212 |
| | (106 | ) | | — |
| | 318 |
| | (1,086 | ) | | (768 | ) | | — |
| | (487 | ) | | 938 |
| | 451 |
|
| Issuances of common stock - net | | 537 |
| | — |
| | — |
| | 537 |
| | 1,298 |
| | — |
| | — |
| | 1,298 |
| | 633 |
| | — |
| | — |
| | 633 |
|
| Dividends on common stock | (1,122 | ) | | — |
| | — |
| | (1,122 | ) | | (1,004 | ) | | — |
| | — |
| | (1,004 | ) | | (920 | ) | | — |
| | — |
| | (920 | ) | (1,612 | ) | | — |
| | — |
| | (1,612 | ) | | (1,385 | ) | | — |
| | — |
| | (1,385 | ) | | (1,261 | ) | | — |
| | — |
| | (1,261 | ) |
| Dividends to NEE | | — |
| | (650 | ) | | 650 |
| | — |
| | — |
| | (698 | ) | | 698 |
| | — |
| | — |
| | 812 |
| | (812 | ) | | — |
|
| Other - net | (92 | ) | | 286 |
| | (487 | ) | | (293 | ) | | (127 | ) | | (1,363 | ) | | 1,090 |
| | (400 | ) | | (398 | ) | | (1,106 | ) | | 911 |
| | (593 | ) | (75 | ) | | (294 | ) | | 1 |
| | (368 | ) | | (92 | ) | | (162 | ) | | 19 |
| | (235 | ) | | (84 | ) | | (31 | ) | | 10 |
| | (105 | ) |
| Net cash provided by (used in) financing activities | (372 | ) | | 1,846 |
| | (344 | ) | | 1,130 |
| | (726 | ) | | 3,503 |
| | 2,111 |
| | 4,888 |
| | (1,270 | ) | | 615 |
| | 1,935 |
| | 1,280 |
| (1,150 | ) | | 2,686 |
| | 959 |
| | 2,495 |
| | (179 | ) | | 1,799 |
| | 263 |
| | 1,883 |
| | (712 | ) | | 934 |
| | 778 |
| | 1,000 |
|
| Net increase (decrease) in cash and cash equivalents | (2 | ) | | 131 |
| | (20 | ) | | 109 |
| | 1 |
| | (52 | ) | | 3 |
| | (48 | ) | | 1 |
| | 57 |
| | 17 |
| | 75 |
| 1 |
| | 712 |
| | 8 |
| | 721 |
| | — |
| | (16 | ) | | 10 |
| | (6 | ) | | — |
| | 144 |
| | (5 | ) | | 139 |
|
| Cash and cash equivalents at beginning of year | 2 |
| | 287 |
| | 40 |
| | 329 |
| | 1 |
| | 339 |
| | 37 |
| | 377 |
| | — |
| | 282 |
| | 20 |
| | 302 |
| — |
| | 546 |
| | 25 |
| | 571 |
| | — |
| | 562 |
| | 15 |
| | 577 |
| | — |
| | 418 |
| | 20 |
| | 438 |
|
| Cash and cash equivalents at end of year | $ | — |
| | $ | 418 |
| | $ | 20 |
| | $ | 438 |
| | $ | 2 |
| | $ | 287 |
| | $ | 40 |
| | $ | 329 |
| | $ | 1 |
| | $ | 339 |
| | $ | 37 |
| | $ | 377 |
| $ | 1 |
| | $ | 1,258 |
| | $ | 33 |
| | $ | 1,292 |
| | $ | — |
| | $ | 546 |
| | $ | 25 |
| | $ | 571 |
| | $ | — |
| | $ | 562 |
| | $ | 15 |
| | $ | 577 |
|
______________________
| |
| (a) | Represents primarily FPL and consolidating adjustments. |
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Concluded)
16. Quarterly Data (Unaudited)
Condensed consolidated quarterly financial information is as follows:
| | | | March 31(a) | | June 30(a) | | September 30(a) | | December 31(a) | March 31(a) | | June 30(a) | | September 30(a) | | December 31(a) |
| | (millions, except per share amounts) | (millions, except per share amounts) |
| NEE: | | | | | | | | | | | | | | |
| 2013 | | | | | | | | |
Operating revenues(b) | $ | 3,279 |
| | $ | 3,833 |
| | $ | 4,394 |
| | $ | 3,630 |
| |
Operating income(b)(c) | $ | 434 |
| | $ | 981 |
| | $ | 1,185 |
| | $ | 641 |
| |
Income from continuing operations(b)(c) | $ | 84 |
| | $ | 610 |
| | $ | 698 |
| | $ | 327 |
| |
Net income(b)(c)(d) | $ | 272 |
| | $ | 610 |
| | $ | 698 |
| | $ | 327 |
| |
Earnings per share - basic:(e) | | | | | | | | |
Continuing operations(c) | $ | 0.20 |
| | $ | 1.45 |
| | $ | 1.65 |
| | $ | 0.76 |
| |
Net income(c)(d) | $ | 0.65 |
| | $ | 1.45 |
| | $ | 1.65 |
| | $ | 0.76 |
| |
Earnings per share - assuming dilution:(e) | | | | | | | | |
Continuing operations(c) | $ | 0.20 |
| | $ | 1.44 |
| | $ | 1.64 |
| | $ | 0.75 |
| |
Net income(c)(d) | $ | 0.64 |
| | $ | 1.44 |
| | $ | 1.64 |
| | $ | 0.75 |
| |
| Dividends per share | $ | 0.66 |
| | $ | 0.66 |
| | $ | 0.66 |
| | $ | 0.66 |
| |
| High-low common stock sales prices | $77.79 - 69.81 |
| | $82.65 - 74.78 |
| | $88.39 - 78.81 |
| | $89.75 - 78.97 |
| |
| 2012 | | | | | | | | |
| 2016 | | | | | | | | |
Operating revenues(b) | $ | 3,371 |
| | $ | 3,667 |
| | $ | 3,843 |
| | $ | 3,375 |
| $ | 3,835 |
| | $ | 3,817 |
| | $ | 4,805 |
| | $ | 3,699 |
|
Operating income(b) | $ | 803 |
| | $ | 1,000 |
| | $ | 742 |
| | $ | 732 |
| $ | 1,234 |
| | $ | 1,169 |
| | $ | 1,279 |
| | $ | 926 |
|
Net income(b) | $ | 461 |
| | $ | 607 |
| | $ | 415 |
| | $ | 429 |
| $ | 654 |
| (c) | $ | 544 |
| | $ | 789 |
| | $ | 1,017 |
|
Earnings per share(e) | $ | 1.12 |
| | $ | 1.46 |
| | $ | 0.99 |
| | $ | 1.02 |
| |
Earnings per share - assuming dilution(e) | $ | 1.11 |
| | $ | 1.45 |
| | $ | 0.98 |
| | $ | 1.02 |
| |
Net income attributable to NEE(b) | | $ | 653 |
| (c) | $ | 540 |
| | $ | 753 |
| | $ | 966 |
|
Earnings per share attributable to NEE - basic(d) | | $ | 1.42 |
| (c) | $ | 1.17 |
| | $ | 1.63 |
| | $ | 2.07 |
|
Earnings per share attributable to NEE - assuming dilution(d) | | $ | 1.41 |
| (c) | $ | 1.16 |
| | $ | 1.62 |
| | $ | 2.06 |
|
| Dividends per share | | $ | 0.87 |
| | $ | 0.87 |
| | $ | 0.87 |
| | $ | 0.87 |
|
| High-low common stock sales prices | | $119.37 - $102.20 |
| | $130.43 - $112.44 |
| | $131.98 - $120.22 |
| | $128.46 - $110.49 |
|
| 2015 | | | | | | | | |
Operating revenues(b) | | $ | 4,104 |
| | $ | 4,358 |
| | $ | 4,954 |
| | $ | 4,069 |
|
Operating income(b) | | $ | 1,129 |
| | $ | 1,146 |
| | $ | 1,481 |
| | $ | 876 |
|
Net income(b) | | $ | 650 |
| | $ | 720 |
| | $ | 882 |
| | $ | 510 |
|
Net income attributable to NEE(b) | | $ | 650 |
| | $ | 716 |
| | $ | 879 |
| | $ | 507 |
|
Earnings per share attributable to NEE - basic(d) | | $ | 1.47 |
| | $ | 1.61 |
| | $ | 1.94 |
| | $ | 1.10 |
|
Earnings per share attributable to NEE - assuming dilution(d) | | $ | 1.45 |
| | $ | 1.59 |
| | $ | 1.93 |
| | $ | 1.10 |
|
| Dividends per share | $ | 0.60 |
| | $ | 0.60 |
| | $ | 0.60 |
| | $ | 0.60 |
| $ | 0.77 |
| | $ | 0.77 |
| | $ | 0.77 |
| | $ | 0.77 |
|
| High-low common stock sales prices | $61.21 - 58.57 |
| | $68.96 - 61.20 |
| | $72.22 - 65.95 |
| | $72.21 - 66.05 |
| $112.64 - $97.48 |
| | $106.63 - $97.23 |
| | $109.98 - $93.74 |
| | $105.85 - $95.84 |
|
| | | | | | | | | | | | | | | |
| FPL: | | | | | | | | | | | | | | |
| 2013 | | | | | | | | |
| 2016 | | | | | | | | |
Operating revenues(b) | $ | 2,188 |
| | $ | 2,696 |
| | $ | 3,020 |
| | $ | 2,541 |
| $ | 2,303 |
| | $ | 2,750 |
| | $ | 3,283 |
| | $ | 2,558 |
|
Operating income(b) | $ | 543 |
| | $ | 724 |
| | $ | 778 |
| | $ | 495 |
| $ | 714 |
| | $ | 828 |
| | $ | 921 |
| | $ | 694 |
|
Net income(b) | $ | 288 |
| | $ | 391 |
| | $ | 422 |
| | $ | 248 |
| $ | 393 |
| | $ | 448 |
| | $ | 515 |
| | $ | 371 |
|
| 2012 | | | | | | | | |
| 2015 | | | | | | | | |
Operating revenues(b) | $ | 2,224 |
| | $ | 2,580 |
| | $ | 2,975 |
| | $ | 2,336 |
| $ | 2,541 |
| | $ | 2,996 |
| | $ | 3,274 |
| | $ | 2,839 |
|
Operating income(b) | $ | 481 |
| | $ | 662 |
| | $ | 719 |
| | $ | 496 |
| $ | 667 |
| | $ | 780 |
| | $ | 855 |
| | $ | 674 |
|
Net income(b) | $ | 239 |
| | $ | 353 |
| | $ | 392 |
| | $ | 256 |
| $ | 359 |
| | $ | 435 |
| | $ | 489 |
| | $ | 365 |
|
______________________
| |
| (a) | In the opinion of NEE and FPL management, all adjustments, which consist of normal recurring accruals necessary to present a fair statement of the amounts shown for such periods, have been made. Results of operations for an interim period generally will not give a true indication of results for the year. |
| |
| (b) | The sum of the quarterly amounts may not equal the total for the year due to rounding. |
| |
| (c) | FirstAmounts were restated to reflect the adoption in the second quarter of 2013 includes impairment2016 of an accounting standards update resulting in an increase to net income and other related charges.net income attributable to NEE of $17 million, and an increase to earnings per share attributable to NEE, basic and assuming dilution, of $0.04. See Note 410 - Nonrecurring Fair Value Measurements.Stock-Based Compensation. |
| |
| (d) | First quarter of 2013 includes an after-tax net gain from discontinued operations. See Note 6. |
| |
(e) | The sum of the quarterly amounts may not equal the total for the year due to rounding and changes in weighted-average number of common shares outstanding. |
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
None
Item 9A. Controls and Procedures
Disclosure Controls and Procedures
As of December 31, 20132016, 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 December 31, 20132016.
Internal Control Over Financial Reporting
| |
| (a) | Management's Annual Report on Internal Control Over Financial Reporting |
See Item 8. Financial Statements and Supplementary Data.
| |
| (b) | Attestation Report of the Independent Registered Public Accounting Firm |
See Item 8. Financial Statements and Supplementary Data.
| |
| (c) | Changes in Internal Control Over Financial Reporting |
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.
Item 9B. Other Information
None
PART III
Item 10. Directors, Executive Officers and Corporate Governance
The information required by this item will be included under the headings "Business of the Annual Meeting," "Corporate Governance and Board Matters" and "Information About NextEra Energy and Management" and "Corporate Governance and Board Matters" in NEE's Proxy Statement which will be filed with the SEC in connection with the 20142017 Annual Meeting of Shareholders (NEE's Proxy Statement) and is incorporated herein by reference, or is included in Item 1. Business - Executive Officers of NEE.
NEE has adopted the NextEra Energy, Inc. Code of Ethics for Senior Executive and Financial Officers (the Senior Financial Executive Code), which is applicable to the chief executive officer, the chief financial officer, the chief accounting officer and other senior executive and financial officers. The Senior Financial Executive Code is available under Corporate Governance in the Investor Relations section of NEE’s internet website at www.nexteraenergy.com. Any amendments to, or waivers of any provision of the Senior Financial Executive Code which are required to be disclosed to shareholders under applicable SEC rules will be disclosed on the NEE website at the address listed above within the time period required under SEC rules from time to time.above.
Item 11. Executive Compensation
The information required by this item will be included in NEE's Proxy Statement under the headings "Executive Compensation" and "Corporate Governance and Board Matters" and is incorporated herein by reference.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The information required by this item relating to security ownership of certain beneficial owners and management will be included in NEE's Proxy Statement under the heading "Information About NextEra Energy and Management" and is incorporated herein by reference.
Securities Authorized For Issuance Under Equity Compensation Plans
NEE's equity compensation plan information as of December 31, 20132016 is as follows:
| | | Plan Category | | Number of securities to be issued upon exercise of outstanding options, warrants and rights (a) | | Weighted-average exercise price of outstanding options, warrants and rights (b) | | Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (c) | | Number of securities to be issued upon exercise of outstanding options, warrants and rights (a) | | Weighted-average exercise price of outstanding options, warrants and rights (b) | | Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (c) |
| Equity compensation plans approved by security holders | | 5,972,593 |
| (a) | $ | 54.70 |
| (b) | 12,250,464 |
| | 4,479,039 |
| (a) | $ | 71.08 |
| (b) | 9,383,195 |
|
Equity compensation plans not approved by security holders(c)
| | 2,523 |
| | $ | 27.11 |
| | — |
| |
| Equity compensation plans not approved by security holders | | | — |
| | — |
| | — |
|
| Total | | 5,975,116 |
| | $ | 54.67 |
| (b) | 12,250,464 |
| | 4,479,039 |
| | $ | 71.08 |
| | 9,383,195 |
|
| |
(a) | Includes an aggregate of 3,191,5472,505,208 outstanding options, 2,342,6851,747,538 unvested performance share awards (at maximum payout), 237,97416,564 deferred fully vested performance shares and 177,377183,989 deferred stock awards (including future reinvested dividends) under the NextEra Energy, Inc. Amended and Restated 2011 LTIPLong Term Incentive Plan and former LTIP, and 23,01025,740 fully vested shares deferred by directors under the NextEra Energy, Inc. 2007 Non-Employee Directors Stock Plan and its predecessor, the FPL Group, Inc. Amended and Restated Non-Employee Directors Stock Plan. |
| |
| (b) | Relates to outstanding options only. |
| |
(c) | Represents options granted by Gexa Corp. under its Amended and Restated 2004 Incentive Plan and pursuant to various individual grants, all of which were made prior to NEE's acquisition of Gexa Corp. All such options were assumed by NEE in connection with the acquisition of Gexa Corp. and are fully vested and exercisable for shares of NEE common stock. No further grants of stock options will be made under this plan. |
Item 13. Certain Relationships and Related Transactions, and Director Independence
The information required by this item, to the extent applicable, will be included in NEE's Proxy Statement under the heading "Corporate Governance and Board Matters" and is incorporated herein by reference.
Item 14. Principal Accounting Fees and Services
NEE - The information required by this item will be included in NEE's Proxy Statement under the heading "Audit-Related Matters" and is incorporated herein by reference.
FPL - The following table presents fees billed for professional services rendered by Deloitte & Touche LLP, the member firms of Deloitte Touche Tohmatsu, and their respective affiliates (collectively, Deloitte & Touche) for the fiscal years ended December 31, 20132016 and 20122015. The amounts presented below reflect allocations from NEE for FPL's portion of the fees, as well as amounts billed directly to FPL.
| | | | 2013 | | 2012 | 2016 | | 2015 |
Audit fees(a) | $ | 3,567,000 |
| | $ | 3,364,000 |
| $ | 3,787,000 |
| | $ | 3,909,000 |
|
Audit-related fees(b) | 160,000 |
| | 190,000 |
| 4,000 |
| | 97,000 |
|
Tax fees(c) | 34,000 |
| | 29,000 |
| 102,000 |
| | 63,000 |
|
All other fees(d) | 15,000 |
| | 10,000 |
| 9,000 |
| | 14,000 |
|
| Total | $ | 3,776,000 |
| | $ | 3,593,000 |
| $ | 3,902,000 |
| | $ | 4,083,000 |
|
______________________
| |
| (a) | Audit fees consist of fees billed for professional services rendered for the audit of FPL's and NEE's annual consolidated financial statements for the fiscal year, the reviews of the financial statements included in FPL's and NEE's Quarterly Reports on Form 10-Q during the fiscal year and the audit of the effectiveness of internal control over financial reporting, comfort letters, consents, and other services related to SEC matters and services in connection with annual and semi-annual filings of NEE's financial statements with the Japanese Ministry of Finance. |
| |
| (b) | Audit-related fees consist of fees billed for assurance and related services that are reasonably related to the performance of the audit or review of FPL's and NEE's consolidated financial statements and are not reported under audit fees. These fees primarily related to agreed-upon procedures and attestation services. |
| |
| (c) | Tax fees consist of fees billed for professional services rendered for tax compliance, tax advice and tax planning.In 20132016 and 2012, all tax fees2015, approximately $66,000 and $28,000, respectively, was paid related to tax advice and planning services. All other tax fees in 2016 and in 2015 related to tax compliance services. |
| |
| (d) | All other fees consist of fees for products and services other than the services reported under the other named categories. In 20132016 and 2012,2015, these fees related to training. |
In accordance with the requirements of the Sarbanes-Oxley Act of 2002, the Audit Committee Charter and the Audit Committee's pre-approval policy for services provided by the independent registered public accounting firm, all services performed by Deloitte & Touche are approved in advance by the Audit Committee, except for audits of certain trust funds where the fees are paid by the trust. Audit and audit-related services specifically identified in an appendix to the pre-approval policy are pre-approved by the Audit Committee each year. This pre-approval allows management to request the specified audit and audit-related services on an as-needed basis during the year, provided any such services are reviewed with the Audit Committee at its next regularly scheduled meeting. Any audit or audit-related service for which the fee is expected to exceed $250,000, or that involves a service not listed on the pre-approval list, must be specifically approved by the Audit Committee prior to commencement of such service. In addition, the Audit Committee approves all services other than audit and audit-related services performed by Deloitte & Touche in advance of the commencement of such work. The Audit Committee has delegated to the Chair of the committee the right to approve audit, audit-related, tax and other services, within certain limitations, between meetings of the Audit Committee, provided any such decision is presented to the Audit Committee at its next regularly scheduled meeting. At each Audit Committee meeting (other than meetings held to review earnings materials), the Audit Committee reviews a schedule of services for which Deloitte & Touche has been engaged since the prior Audit Committee meeting under existing pre-approvals and the estimated fees for those services. In 20132016 and 2012,2015, none of the amounts presented above represent services provided to NEE or FPL by Deloitte & Touche that were approved by the Audit Committee after services were rendered pursuant to Rule 2-01(c)(7)(i)(C) of Regulation S-X (which provides for a waiver of the otherwise applicable pre-approval requirement if certain conditions are met).
PART IV
Item 15. Exhibits, Financial Statement Schedules
|
| | | |
| | | | Page(s) |
| (a) | 1. | Financial Statements | |
| | | Management's Report on Internal Control Over Financial Reporting | |
| | | Attestation Report of Independent Registered Public Accounting Firm | |
| | | Report of Independent Registered Public Accounting Firm | |
| | | NEE: | |
| | | Consolidated Statements of Income | |
| | | Consolidated Statements of Comprehensive Income | |
| | | Consolidated Balance Sheets | |
| | | Consolidated Statements of Cash Flows | |
| | | Consolidated Statements of Common Shareholders' Equity | |
| | | FPL: | |
| | | Consolidated Statements of Income | |
| | | Consolidated Balance Sheets | |
| | | Consolidated Statements of Cash Flows | |
| | | Consolidated Statements of Common Shareholder's Equity | |
| | | Notes to Consolidated Financial Statements | 81 |
| | | | |
| | 2. | Financial Statement Schedules - Schedules are omitted as not applicable or not required. | |
| | | | |
| | 3. | Exhibits (including those incorporated by reference) | |
| | | Certain exhibits listed below refer to "FPL Group" and "FPL Group Capital," and were effective prior to the change of the name FPL Group, Inc. to NextEra Energy, Inc., and of the name FPL Group Capital Inc to NextEra Energy Capital Holdings, Inc., during 2010. | |
|
| | | | | | | |
| | Exhibit Number | | Description | | NEE | | FPL |
| | *2(a) | | Agreement and Plan of Merger, dated as of July 29, 2016, by and among NextEra Energy, Inc., EFH Merger Co., LLC, Energy Future Intermediate Holding Company LLC and Energy Future Holdings Corp. (filed as Exhibit 2.1 to Form 8-K dated July 29, 2016, File No. 1-8841)** | | x | | |
| *2(b) | | Amendment No. 1 to Agreement and Plan of Merger dated as of September 18, 2016 (filed as Exhibit 2 to Form 8-K dated September 18, 2016, File No. 1-8841) | | x | | |
| *2(c) | | Merger Agreement between NextEra Energy, Inc., WSS Acquisition Company, Texas Transmission Holding Corporation, Cheyne Walk Investment Pte Ltd, Borealis Power Holdings Inc. and BPC Health Corporation dated October 30, 2016 (filed as Exhibit 2 to Form 8-K dated October 29, 2016, File No. 1-8841)** | | x | | |
| *3(i)a | | Restated Articles of Incorporation of NextEra Energy, Inc. (filed as Exhibit 3(i)(b) to Form 10-Q for the quarter ended June 30, 2010,8-K dated May 21, 2015, File No. 1-8841)
| | x | | |
| | *3(i)b | | Restated Articles of Incorporation of Florida Power & Light Company (filed as Exhibit 3(i)b to Form 10-K for the year ended December 31, 2010, File No. 2-27612) | | | | x |
| | *3(ii)a | | Amended and Restated Bylaws of NextEra Energy, Inc., as amended through May 21, 2010effective October 14, 2016 (filed as Exhibit 3(ii)(b) to Form 10-Q for the quarter ended June 30, 2010,8-K dated October 14, 2016, File No. 1-8841)
| | x | | |
| | *3(ii)b | | Amended and Restated Bylaws of Florida Power & Light Company, Inc., as amended through October 17, 2008 (filed as Exhibit 3(ii)b to Form 10-Q for the quarter ended September 30, 2008, File No. 2-27612) | | | | x |
|
| | | | | | | |
| | Exhibit Number | | Description | | NEE | | FPL |
| | *4(a) | | Mortgage and Deed of Trust dated as of January 1, 1944, and One hundred and twenty-onetwenty-four Supplements thereto, between Florida Power & Light Company and Deutsche Bank Trust Company Americas, Trustee (filed as Exhibit B-3, File No. 2-4845; Exhibit 7(a), File No. 2-7126; Exhibit 7(a), File No. 2-7523; Exhibit 7(a), File No. 2-7990; Exhibit 7(a), File No. 2-9217; Exhibit 4(a)-5, File No. 2-10093; Exhibit 4(c), File No. 2-11491; Exhibit 4(b)-1, File No. 2-12900; Exhibit 4(b)-1, File No. 2-13255; Exhibit 4(b)-1, File No. 2-13705; Exhibit 4(b)-1, File No. 2-13925; Exhibit 4(b)-1, File No. 2-15088; Exhibit 4(b)-1, File No. 2-15677; Exhibit 4(b)-1, File No. 2-20501; Exhibit 4(b)-1, File No. 2-22104; Exhibit 2(c), File No. 2-23142; Exhibit 2(c), File No. 2-24195; Exhibit 4(b)-1, File No. 2-25677; Exhibit 2(c), File No. 2-27612; Exhibit 2(c), File No. 2-29001; Exhibit 2(c), File No. 2-30542; Exhibit 2(c), File No. 2-33038; Exhibit 2(c), File No. 2-37679; Exhibit 2(c), File No. 2-39006; Exhibit 2(c), File No. 2-41312; Exhibit 2(c), File No. 2-44234; Exhibit 2(c), File No. 2-46502; Exhibit 2(c), File No. 2-48679; Exhibit 2(c), File No. 2-49726; Exhibit 2(c), File No. 2-50712; Exhibit 2(c), File No. 2-52826; Exhibit 2(c), File No. 2-53272; Exhibit 2(c), File No. 2-54242; Exhibit 2(c), File No. 2-56228; Exhibits 2(c) and 2(d), File No. 2-60413; Exhibits 2(c) and 2(d), File No. 2-65701; Exhibit 2(c), File No. 2-66524; Exhibit 2(c), File No. 2-67239; Exhibit 4(c), File No. 2-69716; Exhibit 4(c), File No. 2-70767; Exhibit 4(b), File No. 2-71542; Exhibit 4(b), File No. 2-73799; Exhibits 4(c), 4(d) and 4(e), File No. 2-75762; Exhibit 4(c), File No. 2-77629; Exhibit 4(c), File No. 2-79557; Exhibit 99(a) to Post-Effective Amendment No. 5 to Form S-8, File No. 33-18669; Exhibit 99(a) to Post-Effective Amendment No. 1 to Form S-3, File No. 33-46076; Exhibit 4(b) to Form 10-K for the year ended December 31, 1993, File No. 1-3545; Exhibit 4(i) to Form 10-Q for the quarter ended June 30, 1994, File No. 1-3545; Exhibit 4(b) to Form 10-Q for the quarter ended June 30, 1995, File No. 1-3545; Exhibit 4(a) to Form 10-Q for the quarter ended March 31,1996, File No. 1-3545; Exhibit 4 to Form 10-Q for the quarter ended June 30, 1998, File No. 1-3545; Exhibit 4 to Form 10-Q for the quarter ended March 31, 1999, File No. 1-3545; Exhibit 4(f) to Form 10-K for the year ended December 31, 2000, File No. 1-3545; Exhibit 4(g) to Form 10-K for the year ended December 31, 2000, File No. 1-3545; Exhibit 4(o), File No. 333-102169; Exhibit 4(k) to Post-Effective Amendment No. 1 to Form S-3, File No. 333-102172; Exhibit 4(l) to Post-Effective Amendment No. 2 to Form S-3, File No. 333-102172; Exhibit 4(m) to Post-Effective Amendment No. 3 to Form S-3, File No. 333-102172; Exhibit 4(a) to Form 10-Q for the quarter ended September 30, 2004, File No. 2-27612; Exhibit 4(f) to Amendment No. 1 to Form S-3, File No. 333-125275; Exhibit 4(y) to Post-Effective Amendment No. 2 to Form S-3, File Nos. 333-116300, 333-116300-01 and 333-116300-02; Exhibit 4(z) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-116300, 333-116300-01 and 333-116300-02; Exhibit 4(b) to Form 10-Q for the quarter ended March 31, 2006, File No. 2-27612; Exhibit 4(a) to Form 8-K dated April 17, 2007, File No. 2-27612; Exhibit 4 to Form 8-K dated October 10, 2007, File No. 2-27612; Exhibit 4 to Form 8-K dated January 16, 2008, File No. 2-27612; Exhibit 4(a) to Form 8-K dated March 17, 2009, File No. 2-27612; Exhibit 4 to Form 8-K dated February 9, 2010, File No. 2-27612; Exhibit 4 to Form 8-K dated December 9, 2010, File No. 2-27612; Exhibit 4(a) to Form 8-K dated June 10, 2011, File No. 2-27612; Exhibit 4 to Form 8-K dated December 13, 2011, File No. 2-27612; Exhibit 4 to Form 8-K dated May 15, 2012, File No. 2-27612; Exhibit 4 to Form 8-K dated December 20, 2012, File No. 2-27612; and Exhibit 4 to Form 8-K dated June 5, 2013, File No. 2-27612; Exhibit 4 to Form 8-K dated May 15, 2014, File No. 2-27612; Exhibit 4 to Form 8-K dated September 10, 2014, File No. 2-27612; and Exhibit 4 to Form 8-K dated November 19, 2015, File No. 2-27612) | | x | | x |
| | *4(b) | | Indenture (For Unsecured Debt Securities), dated as of June 1, 1999, between FPL Group Capital Inc and The Bank of New York Mellon, as Trustee (filed as Exhibit 4(a) to Form 8-K dated July 16, 1999, File No. 1-8841)
| | x | | |
| | *4(c) | | First Supplemental Indenture to Indenture (For Unsecured Debt Securities) dated as of June 1, 1999, dated as of September 21, 2012, between NextEra Energy Capital Holdings, Inc. and The Bank of New York Mellon, as Trustee (filed as Exhibit 4(e) to Form 10-Q for the quarter ended September 30, 2012, File No. 1-8841)
| | x | | |
| | *4(d) | | Guarantee Agreement, dated as of June 1, 1999, between FPL Group, Inc. (as Guarantor) and The Bank of New York Mellon (as Guarantee Trustee) (filed as Exhibit 4(b) to Form 8-K dated July 16, 1999, File No. 1-8841)
| | x | | |
| | *4(e) | | Officer's Certificate of FPL Group Capital Inc, dated December 12, 2008,March 9, 2009, creating the 7 7/8%6.00% Debentures, Series due December 15, 2015March 1, 2019 (filed as Exhibit 4 to Form 8-K dated December 12, 2008,March 9, 2009, File No. 1-8841) | | x | | |
|
| | | | | | | |
| | Exhibit Number | | Description | | NEE | | FPL |
| | *4(f) | | Officer's Certificate of FPL Group Capital Inc, dated March 9, 2009, creating the 6.00% Debentures, Series due March 1, 2019 (filed as Exhibit 4 to Form 8-K dated March 9, 2009, File No. 1-8841)
| | x | | |
| *4(g) | | Officer's Certificate of FPL Group Capital Inc, dated May 26, 2009, creating the Series C Debentures due June 1, 2014 (filed as Exhibit 4(c) to Form 8-K dated May 22, 2009, File No. 1-8841)
| | x | | |
| *4(h) | | Letter, dated May 21, 2012, from NextEra Energy Capital Holdings, Inc. to The Bank of New York Mellon, as trustee, setting forth certain terms of the Series C Debentures due June 1, 2014, effective May 21, 2012 (filed as Exhibit 4(b) to Form 8-K dated May 21, 2012, File No. 1-8841)
| | x | | |
| *4(i) | | Officer's Certificate of FPL Group Capital Inc, dated August 31, 2010, creating the Debentures, 2.60% Series due September 1, 2015 (filed as Exhibit 4 to Form 8-K dated August 31, 2010, File No. 1-8841)
| | x | | |
| *4(j) | | Officer's Certificate of FPL Group Capital 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(k) | | 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 due September 1, 2015, effective August 9, 2013 (filed as Exhibit 4(b) to Form 8-K dated August 9, 2013, File No. 1-8841) | | x | | |
| *4(l) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated June 10, 2011, creating the 4.50% Debentures, Series due June 1, 2021 (filed as Exhibit 4(b) to Form 8-K dated June 10, 2011, File No. 1-8841)
| | x | | |
| | *4(m)4(g) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated May 4, 2012, creating the Series E Debentures due June 1, 2017 (filed as Exhibit 4(c) to Form 8-K dated May 4, 2012, File No. 1-8841)
| | x | | |
| | *4(n)4(h) | | Letter, dated May 7, 2015, from NextEra Energy Capital Holdings, Inc. to The Bank of New York Mellon, as trustee, setting forth certain terms of the Series E Debentures due June 1, 2017, effective May 7, 2015 (filed as Exhibit 4(b) to Form 8-K dated May 7, 2015, File No. 1-8841) | | x | | |
| *4(i) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 11, 2012, creating the Series F Debentures due September 1, 2017 (filed as Exhibit 4(c) to Form 8-K dated September 11, 2012, File No. 1-8841)
| | x | | |
| | *4(o)4(j) | | Officer's Certificate ofLetter, dated August 10, 2015, from NextEra Energy Capital Holdings, Inc., dated to The Bank of New York Mellon, as trustee, setting forth certain terms of the Series F Debentures due September 21, 2012, creating the 1.20% Debentures, Series due June 1, 2017, effective August 10, 2015 (filed as Exhibit 44(b) to Form 8-K dated September 21, 2012,August 10, 2015, File No. 1-8841)
| | x | | |
| | *4(p)4(k) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc. dated June 6, 2013, creating the 3.625% Debentures, Series due June 15, 2023 (filed as Exhibit 4 to Form 8-K dated June 6, 2013, File No. 1-8841)
| | x | | |
| | *4(q)4(l) | | 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 | | |
| *4(m) | | Letter, dated September 1, 2016, from NextEra Energy Capital Holdings, Inc. to The Bank of New York Mellon, as trustee, setting forth certain terms of the Series G Debentures due September 1, 2018, effective September 1, 2016 (filed as Exhibit 4(b) to Form 8-K dated September 1, 2016, File No. 1-8841) | | x | | |
| *4(n) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated March 11, 2014, creating the 2.700% Debentures, Series due September 15, 2019 (filed as Exhibit 4 to Form 8-K dated March 11, 2014, File No. 1-8841) | | x | | |
| *4(o) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated June 6, 2014, creating the 2.40% Debentures, Series due September 15, 2019 (filed as Exhibit 4 to Form 8-K dated June 6, 2014, File No. 1-8841) | | x | | |
| *4(p) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated August 27, 2015, creating the 2.80% Debentures, Series due August 27, 2020 (filed as Exhibit 4(c) to Form 10-Q for the quarter ended September 30, 2015, File No. 1-8841) | | x | | |
| *4(q) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 16, 2015, creating the Series H Debentures due September 1, 2020 (filed as Exhibit 4(c) to Form 8-K dated September 16, 2015, File No. 1-8841) | | x | | |
| | *4(r) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated March 31, 2016, creating the 2.30% Debentures, Series due April 1, 2019 (filed as Exhibit 4 to Form 8-K dated March 31, 2016, File No. 1-8841) | | x | | |
| *4(s) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated August 8, 2016, creating the Series I Debentures due September 1, 2021 (filed as Exhibit 4(c) to Form 8-K dated August 8, 2016, File No. 1-8841) | | x | | |
| *4(t) | | Indenture (For Unsecured Subordinated Debt Securities relating to Trust Securities), dated as of March 1, 2004, among FPL Group Capital Inc, FPL Group, Inc. (as Guarantor) and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(au) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03) | | x | | |
| | *4(s)4(u) | | Preferred Trust Securities Guarantee Agreement, dated as of March 15, 2004, between FPL Group, Inc. (as Guarantor) and The Bank of New York Mellon (as Guarantee Trustee) relating to FPL Group Capital Trust I (filed as Exhibit 4(aw) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03) | | x | | |
| | *4(t)4(v) | | Amended and Restated Trust Agreement relating to FPL Group Capital Trust I, dated as of March 15, 2004 (filed as Exhibit 4(at) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03) | | x | | |
|
| | | | | | | |
| Exhibit Number | | Description | | NEE | | FPL |
| | *4(u)4(w) | | Agreement as to Expenses and Liabilities of FPL Group Capital Trust I, dated as of March 15, 2004 (filed as Exhibit 4(ax) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03) | | x | | |
|
| | | | | | | |
| Exhibit
Number
| | Description | | NEE | | FPL |
| | *4(v)4(x) | | Officer's Certificate of FPL Group Capital Inc and FPL Group, Inc., dated March 15, 2004, creating the 5 7/8% Junior Subordinated Debentures, Series due March 15, 2044 (filed as Exhibit 4(av) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03) | | x | | |
| | *4(w)4(y) | | Indenture (For Unsecured Subordinated Debt Securities), dated as of September 1, 2006, among FPL Group Capital Inc, FPL Group, Inc. (as Guarantor) and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(a) to Form 8-K dated September 19, 2006, File No. 1-8841) | | x | | |
| | *4(x)4(z) | | First Supplemental Indenture to Indenture (For Unsecured Subordinated Debt Securities) dated as of September 1, 2006, dated as of November 19, 2012, between NextEra Energy Capital Holdings, Inc., NextEra Energy, Inc. as Guarantor, and The Bank of New York Mellon, as Trustee (filed as Exhibit 2 to Form 8-A dated January 16, 2013, File No. 1-33028)
| | x | | |
| | *4(y)4(aa) | | Officer's Certificate of FPL Group Capital Inc and FPL Group, Inc., dated September 19, 2006, creating the Series B Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(c) to Form 8-K dated September 19, 2006, File No. 1-8841) | | x | | |
| | *4(z)4(bb) | | Replacement Capital Covenant, dated September 19, 2006, by FPL Group Capital Inc and FPL Group, Inc. relating to FPL Group Capital Inc's Series B Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(d) to Form 8-K dated September 19, 2006, File No. 1-8841) | | x | | |
| 4(cc) | | Amendment, dated November 9, 2016, to the Replacement Capital Covenant, dated September 19, 2006, by NextEra Energy Capital Holdings, Inc. (formerly known as FPL Group Capital Holdings Inc) and NextEra Energy, Inc. (formerly known as FPL Group, Inc.), relating to FPL Group Capital Inc's Series B Enhanced Junior Subordinated Debentures due 2066 | | x | | |
| | *4(aa)4(dd) | | Officer's Certificate of FPL Group Capital Inc and FPL Group, Inc., dated June 12, 2007, creating the Series C Junior Subordinated Debentures due 2067 (filed as Exhibit 4(a) to Form 8-K dated June 12, 2007, File No. 1-8841) | | x | | |
| | *4(bb)4(ee) | | Replacement Capital Covenant, dated June 12, 2007, by FPL Group Capital Inc and FPL Group, Inc. relating to FPL Group Capital Inc's Series C Junior Subordinated Debentures due 2067 (filed as Exhibit 4(b) to Form 8-K dated June 12, 2007, File No. 1-8841) | | x | | |
| | *4(cc)4(ff) | | Officer's Certificate of FPL Group Capital Inc and FPL Group, Inc., dated September 17, 2007, creating the Series D Junior Subordinated Debentures due 2067 (filed as Exhibit 4(a) to Form 8-K dated September 17, 2007, File No. 1-8841) | | x | | |
| | *4(dd)4(gg) | | Replacement Capital Covenant, dated September 18, 2007, by FPL Group Capital Inc and FPL Group, Inc. relating to FPL Group Capital Inc's Series D Junior Subordinated Debentures due 2067 (filed as Exhibit 4(c) to Form 8-K dated September 17, 2007, File No. 1-8841) | | x | | |
| 4(hh) | | Amendment, dated November 9, 2016, to the Replacement Capital Covenant, dated June 12, 2007 and to the Replacement Capital Covenant, dated September 18, 2007, by NextEra Energy Capital Holdings, Inc. (formerly known as FPL Group Capital Holdings Inc) and NextEra Energy, Inc. (formerly known as FPL Group, Inc.), relating to FPL Group Capital Inc's Series C Junior Subordinated Debentures due 2067 and Series D Junior Subordinated Debentures due 2067 | | x | | |
| | *4(ee)4(ii) | | Officer's Certificate of FPL Group Capital Inc and FPL Group, Inc., dated March 19, 2009, creating the Series F Junior Subordinated Debentures due 2069 (filed as Exhibit 4(b) to Form 8-K dated March 17, 2009, File No. 1-8841)
| | x | | |
| *4(ff) | | Replacement Capital Covenant, dated March 19, 2009, by FPL Group Capital Inc and FPL Group, Inc. relating to FPL Group Capital Inc's Series F Junior Subordinated Debentures due 2069 (filed as Exhibit 4(c) to Form 8-K dated March 17, 2009, File No. 1-8841)
| | x | | |
| *4(gg) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated March 27, 2012, creating the Series G Junior Subordinated Debentures due March 1, 2072 (filed as Exhibit 4 to Form 8-K dated March 27, 2012, File No. 1-8841)
| | x | | |
| | *4(hh)4(jj) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated June 15, 2012, creating the Series H Junior Subordinated Debentures due June 15, 2072 (filed as Exhibit 4 to Form 8-K dated June 15, 2012, File No. 1-8841)
| | x | | |
| | *4(ii)4(kk) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated November 19, 2012, creating the Series I Junior Subordinated Debentures due November 15, 2072 (filed as Exhibit 4 to Form 8-K dated November 19, 2012, File No. 1-8841)
| | x | | |
|
| | | | | | | |
| Exhibit Number | | Description | | NEE | | FPL |
| | *4(jj)4(ll) | | Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated January 18, 2013, creating the Series J Junior Subordinated Debentures due January 15, 2073 (filed as Exhibit 4 to Form 8-K dated January 18, 2013, File No. 1-8841)
| | x | | |
|
| | | | | | | |
| | Exhibit
Number
*4(mm) | | DescriptionOfficer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated June 7, 2016, creating the Series K Junior Subordinated Debentures due June 1, 2076 (filed as Exhibit 4 to Form 8-K dated June 7, 2016, File No. 1-8841) | | NEEx | | FPL |
| | *4(kk)4(nn) | | Indenture (For Securing Senior Secured Bonds, Series A), dated May 22, 2007, between FPL Recovery Funding LLC (as Issuer) and The Bank of New York Mellon (as Trustee and Securities Intermediary) (filed as Exhibit 4.1 to Form 8-K dated May 22, 2007 and filed June 1, 2007, File No. 333-141357) | | | | x |
| | *4(ll)4(oo) | | Purchase Contract Agreement, dated as of September 1, 2010,2015, 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 15, 2010,16, 2015, File No. 1-8841)
| | x | | |
| *4(mm) | | Pledge Agreement, dated as of September 1, 2010, among 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 15, 2010, File No. 1-8841)
| | x | | |
| *4(nn) | | Purchase Contract Agreement dated as of May 1, 2012, between NextEra Energy, Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(a) to Form 8-K dated May 4, 2012, File No. 1-8841)
| | x | | |
| *4(oo) | | Pledge Agreement, dated as of May 1, 2012, between NextEra Energy, Inc., Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(b) to Form 8-K dated May 4, 2012, File No. 1-8841)
| | x | | |
| | *4(pp) | | Purchase Contract Agreement dated as of September 1, 2012, between NextEra Energy, Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(a) to Form 8-K dated September 11, 2012, File No. 1-8841)
| | x | | |
| *4(qq) | | Pledge Agreement, dated as of September 1, 2012,2015, between NextEra Energy, Inc., Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(b) to Form 8-K dated September 11, 2012,16, 2015, File No. 1-8841)
| | x | | |
| | *4(rr)4(qq) | | Purchase Contract Agreement, dated as of SeptemberAugust 1, 2013,2016, 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,August 8, 2016, File No. 1-8841)
| | x | | |
| | *4(ss)4(rr) | | Pledge Agreement, dated as of SeptemberAugust 1, 2013,2016, 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,August 8, 2016, File No. 1-8841)
| | x | | |
| | *10(a) | | FPL Group, Inc. Supplemental Executive Retirement Plan, amended and restated effective April 1, 1997 (SERP) (filed as Exhibit 10(a) to Form 10-K for the year ended December 31, 1999, File No. 1-8841) | | x | | x |
| | *10(b) | | FPL Group, Inc. Supplemental Executive Retirement Plan, amended and restated effective January 1, 2005 (Restated SERP) (filed as Exhibit 10(b) to Form 8-K dated December 12, 2008, File No. 1-8841) | | x | | x |
| | *10(c) | | Amendment Number 1 to the Restated SERP changing name to NextEra Energy, Inc. Supplemental Executive Retirement Plan (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2010, File No. 1-8841) | | x | | x |
| | *10(d) | | Appendix A1 (revised as of December 1, 2012)11, 2014) to the Restated SERPNextEra Energy, Inc. Supplemental Executive Retirement Plan (filed as Exhibit 10(f)10(d) to Form 10-K for the year ended December 31, 2012,2015, File No. 1-8841)
| | x | | x |
| | *10(e) | | Appendix A2 (revised as of December 12, 2013)September 19, 2016) to the Restated SERPNextEra Energy, Inc. Supplemental Executive Retirement Plan (filed as Exhibit 10(d) to Form 10-Q for the quarter ended September 30, 2016, File No. 1-8841) | | x | | x |
| | *10(f) | | Amended and Restated Supplement to the Restated SERP as it applies to Lewis Hay, III effective January 1, 2005 (filed as Exhibit 10(c) to Form 8-K dated December 12, 2008, File No. 1-8841)
| | x | | x |
| *10(g) | | Supplement to the SERP as it applies to Lewis Hay, III effective March 22, 2002 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 2001, File No. 1-8841)
| | x | | x |
| *10(h) | | Supplement to the Restated SERP relating to a special credit to certain executive officers and other officers effective February 15, 2008 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 2007, File No. 1-8841) | | x | | x |
|
| | | | | | | |
| Exhibit
Number
| | Description | | NEE | | FPL |
| | *10(i)10(g) | | Supplement to the Restated SERP effective February 15, 2008 as it applies to Armando Pimentel, Jr. (filed as Exhibit 10(i) to Form 10-K for the year ended December 31, 2007, File No. 1-8841) | | x | | x |
| | *10(j)10(h) | | Supplement to the SERP effective December 14, 2007 as it applies to Manoochehr K. Nazar (filed as Exhibit 10(j) to Form 10-K for the year ended December 31, 2009, File No. 1-8841) | | x | | x |
| | *10(k)10(i) | | FPL Group, Inc. Long-Term Incentive Plan of 1985, as amended (filed as Exhibit 99(h) to Post-Effective Amendment No. 5 to Form S-8, File No. 33-18669)
| | x | | x |
| *10(l) | | NextEra Energy, Inc. (formerly known as FPL Group, Inc.) Amended and Restated Long-Term Incentive Plan, most recently amended and restated on May 22, 2009 (filed as Exhibit 10(a) to Form 10-Q for the quarter ended June 30, 2009, File No. 1-8841)
| | x | | x |
| | *10(m)10(j) | | NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan (filed as Exhibit 10(c) to Form 8-K dated March 16, 2012, File No. 1-8841)
| | x | | x |
| | *10(n)10(k) | | Form of NextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan Performance Share Award Agreement effective February 18, 2011 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended March 31, 2011, File No. 1-8841)
| | x | | x |
| *10(o) | | Form of Performance Share Award Agreement under the NextEra Energy, Inc. 2011 Long Term Incentive Plan (filed as Exhibit 10(a) to Form 8-K dated October 13, 2011, File No. 1-8841)
| | x | | x |
|
| | | | | | | |
| Exhibit Number | | Description | | NEE | | FPL |
| | *10(p)10(l) | | Form of Performance Share Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan, as revised March 16, 2012 (filed as Exhibit 10(c) to Form 10-Q for the quarter ended March 31, 2012)
| | x | | x |
| | *10(q)10(m) | | Form of Performance Share Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(a) to Form 8-K dated October 11, 2012)
| | x | | x |
| | *10(r)10(n) | | Form of FPL Group,Performance Share Award Agreement under the Next Era Energy, Inc. Amended and Restated Long-Term2011 Long Term Incentive Plan Restricted Stock Award Agreement effective February 13, 2009for certain executive officers (filed as Exhibit 10(q)10(o) to Form 10-K for the year ended December 31, 2008,2015, File No. 1-8841) | | x | | x |
| | *10(s)10(o) | | Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan Restricted StockPerformance Share Award Agreement effective February 12, 2010 (filed as Exhibit 10(w) to Form 10-K forunder the year ended December 31, 2009, File No. 1-8841) | | x | | x |
| *10(t) | | Form of NextEra Energy, Inc. Amended and Restated Long-Term2011 Long Term Incentive Plan Restricted Stock Award Agreement effective February 18, 2011for certain executive officers (filed as Exhibit 10(c) to Form 10-Q for the quarter ended March 31, 2011,2016, File No. 1-8841)
| | x | | x |
| | *10(u)10(p) | | Form of Performance Share Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(d) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841) | | x | | x |
| *10(q) | | Form of Restricted Stock Award Agreement under the NextEra Energy, Inc. 2011 Long Term Incentive Plan (filed as Exhibit 10(c) to Form 8-K dated October 13, 2011, File No. 1-8841)
| | x | | x |
| | *10(v)10(r) | | Form of Restricted Stock Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(b) to Form 8-K dated October 11, 2012)
| | x | | x |
| | *10(w)10(s) | | Form of Restricted Stock Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(e) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841) | | x | | x |
| *10(t) | | Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement (filed as Exhibit 10(c) to Form 8-K dated December 29, 2004, File No. 1-8841) | | x | | x |
| | *10(x)10(u) | | Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement (filed as Exhibit 10(d) to Form 8-K dated December 29, 2004, File No. 1-8841) | | x | | x |
| | *10(y)10(v) | | Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement effective February 15, 2008 (filed as Exhibit 10(b) to Form 8-K dated February 15, 2008, File No. 1-8841) | | x | | x |
| | *10(z)10(w) | | Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement effective February 13, 2009 (filed as Exhibit 10(u) to Form 10-K for the year ended December 31, 2008, File No. 1-8841) | | x | | x |
|
| | | | | | | |
| Exhibit
Number
| | Description | | NEE | | FPL |
| | *10(aa)10(x) | | Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan - Non-Qualified Stock Option Agreement effective February 12, 2010 (filed as Exhibit 10(bb) to Form 10-K for the year December 31, 2009, File No. 1-8841) | | x | | x |
| | *10(bb)10(y) | | Form of NextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan - Non-Qualified Stock Option Agreement effective February 18, 2011 (filed as Exhibit 10(d) to Form 10-Q for the quarter ended March 31, 2011, File No. 1-8841)
| | x | | x |
| | *10(cc)10(z) | | Form of Non-Qualified Stock Option Award Agreement under the NextEra Energy, Inc. 2011 Long Term Incentive Plan (filed as Exhibit 10(b) to Form 8-K dated October 13, 2011, File No. 1-8841)
| | x | | x |
| | *10(dd)10(aa) | | Form of Non-Qualified Stock Option Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(f) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841) | | x | | x |
| *10(bb) | | Form of Non-Qualified Stock Option Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(g) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841) | | x | | x |
| *10(cc) | | Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan Amended and Restated Deferred Stock Award Agreement effective February 12, 2010 between FPL Group, Inc. and each of Moray P. Dewhurst and James L. Robo (filed as Exhibit 10(dd) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)
| | x | | x |
| | *10(ee)10(dd) | | Form of Deferred Stock Award Agreement under NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan (filed as Exhibit 10(a) to Form 8-K dated March 16, 2012, File No. 1-8841)
| | x | | x |
|
| | | | | | | |
| Exhibit Number | | Description | | NEE | | FPL |
| | *10(ff)10(ee) | | NextEra Energy, Inc. 2013 Executive Annual Incentive Plan (filed as Exhibit 10(c) to Form 8-K dated October 11, 2012, File No. 1-8841)
| | x | | x |
| | *10(gg)10(ff) | | NextEra Energy, Inc. Deferred Compensation Plan effective January 1, 2005 as amended and restated through October 15, 2010February 11, 2016 (filed as Exhibit 10(dd)10(h) to Form 10-K10-Q for the yearquarter ended DecemberMarch 31, 2010,2016, File No. 1-8841)
| | x | | x |
| | *10(hh)10(gg) | | Amendment 1 (effective May 25, 2011) to the NextEra Energy, Inc. Deferred Compensation Plan effective January 1, 2005, as amended and restated through October 15, 2010 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2011, File No. 1-8841)
| | x | | x |
| *10(ii) | | Amendment 2 (effective November 16, 2011) to the NextEra Energy, Inc. Deferred Compensation Plan effective January 1, 2005, as amended and restated through October 15, 2010 (filed as Exhibit 10(ll) to Form 10-K for the year ended December 31, 2011, File No. 1-8841)
| | x | | x |
| *10(jj) | | FPL Group, Inc. Deferred Compensation Plan, amended and restated effective January 1, 2003 (filed as Exhibit 10(k) to Form 10-K for the year ended December 31, 2002, File No. 1-8841)
| | x | | x |
| | *10(kk)10(hh) | | FPL Group, Inc. Executive Long-Term Disability Plan effective January 1, 1995 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 1995, File No. 1-8841)
| | x | | x |
| | *10(ll)10(ii) | | FPL Group, Inc. Amended and Restated Non-Employee Directors Stock Plan, as amended and restated October 13, 2006 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended September 30, 2006, File No. 1-8841) | | x | | |
| | *10(mm)10(jj) | | FPL Group, Inc. 2007 Non-Employee Directors Stock Plan (filed as Exhibit 99 to Form S-8, File No. 333-143739) | | x | | |
| | *10(nn) | | NextEra Energy, Inc. Non-Employee Director Compensation Summary effective January 1, 2013 (filed as Exhibit 10(ss) to Form 10-K for the year ended December 31, 2012, File No. 1-8841)
| | x | | |
| 10(oo)10(kk) | | NextEra Energy, Inc. Non-Employee Director Compensation Summary effective January 1, 20142016 (filed as Exhibit 10(jj) to Form 10-K for the year ended December 31, 2015, File No. 1-8841) | | x | | |
| 10(ll) | | NextEra Energy, Inc. Non-Employee Director Compensation Summary effective January 1, 2017 | | x | | |
| | *10(pp)10(mm) | | Form of Amended and Restated Executive Retention Employment Agreement effective December 10, 2009 between FPL Group, Inc. and each of Lewis Hay, III, Moray P. Dewhurst, James L. Robo, Armando Pimentel, Jr., and Charles E. Sieving (filed as Exhibit 10(nn) to Form 10-K for the year ended December 31, 2009, File No. 1-8841) | | x | | x |
| | *10(qq)10(nn) | | Amended and Restated Employment Letter with Lewis Hay, III dated December 10, 2009 (filed as Exhibit 10(pp) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)
| | x | | x |
| *10(rr) | | 409A Amendment dated October 12, 2012 to Amended and Restated Employment Letter between Lewis Hay, III and NextEra Energy, Inc. (filed as Exhibit 10(ww) to Form 10-K for the year ended December 31, 2012, File No. 1-8841) | | x | | x |
|
| | | | | | | |
| Exhibit
Number
| | Description | | NEE | | FPL |
| *10(ss) | | Waiver Letter dated March 16, 2012 between Lewis Hay, III and NextEra Energy, Inc. (filed as Exhibit 10(b) to Form 8-K dated March 16, 2012, File No. 1-8841)
| | x | | x |
| *10(tt) | | April 15, 2013 Consent Under Waiver Letter Dated March 16, 2012 between Lewis Hay, III and NextEra Energy, Inc. (filed as Exhibit 10(c) to Form 10-Q for the quarter ended June 30, 2013, File No. 1-8841)
| | x | | x |
| *10(uu) | | May 24, 2013 Second Consent Under Waiver Letter Dated March 16, 2012 between Lewis Hay, III and NextEra Energy, Inc. (filed as Exhibit 10(d) to Form 10-Q for the quarter ended June 30, 2013, File No. 1-8841)
| | x | | x |
| *10(vv) | | Executive Retention Employment Agreement between FPL Group, Inc. and Joseph T. Kelliher dated as of May 21, 2009 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2009, File No. 1-8841) | | x | | x |
| | *10(ww)10(oo) | | Executive Retention Employment Agreement between FPL Group, Inc. and Manoochehr K. Nazar dated as of January 1, 2010 (filed as Exhibit 10(rr) to Form 10-K 10‑K for the year ended December 31, 2009, File No. 1-8841)
| | x | | x |
| | *10(xx)10(pp) | | Executive Retention Employment Agreement between NextEra Energy, Inc. and Eric E. Silagy dated as of May 2, 2012 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2012, File No. 1-8841)
| | x | | x |
| | *10(yy)10(qq) | | Executive Retention Employment Agreement between NextEra Energy, Inc. and William L. Yeager dated as of January 1, 2013 (filed as Exhibit 10(ccc) to Form 10-K for the year ended December 31, 2012, File No. 1-8841)
| | x | | x |
| | *10(zz)10(rr) | | Form of 2012 409A Amendment to NextEra Energy, Inc. Executive Retention Employment Agreement effective October 11, 2012 between NextEra Energy, Inc. and each of Lewis Hay, III, James L. Robo, Moray P. Dewhurst, Armando Pimentel, Jr., Eric E. Silagy, Joseph T. Kelliher, Manoochehr K. Nazar and Charles E. Sieving (filed as Exhibit 10(ddd) to Form 10-K for the year ended December 31, 2012, File No. 1-8841)
| | x | | x |
| | *10(aaa)10(ss) | | Executive Retention Employment Agreement between NextEra Energy, Inc. and Deborah H. Caplan dated as of April 23, 2013 (filed as Exhibit 10(e) to Form 10-Q for the quarter ended June 30, 2013, File No. 1-8841)
| | x | | x |
| | 10(bbb)*10(tt) | | Executive Retention Employment Agreement between NextEra Energy, Inc. and Miguel Arechabala dated as of January 1, 2014 (filed as Exhibit 10(bbb) to Form 10‑K for the year ended December 31, 2013, File No. 1-8841) | | x | | x |
| | *10(ccc)10(uu) | | Executive Retention Employment Agreement between NextEra Energy, Inc. and John W. Ketchum dated as of March 4, 2016 (filed as Exhibit 10(i) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841) | | x | | x |
| *10(vv) | | NextEra Energy, Inc. Executive Severance Benefit Plan effective February 26, 2013 (filed as Exhibit 10(eee) to Form 10-K for the year ended December 31, 2012, File No. 1-8841)
| | x | | x |
| | *10(ddd)10(ww) | | Guarantee Agreement between FPL Group, Inc. and FPL Group Capital Inc, dated as of October 14, 1998 (filed as Exhibit 10(y) to Form 10-K for the year ended December 31, 2001, File No. 1-8841)
| | x | | |
| | 12(a)*10(xx) | | ComputationAmended and Restated Plan Support Agreement dated as of Ratios
September 19, 2016 (filed as Exhibit 10 to Form 8-K dated September 18, 2016, File No. 1-8841) | | x | | |
| 12(b) | | Computation of Ratios
| | | | x |
| 21 | | Subsidiaries of NextEra Energy, Inc.
| | x | | |
| 23 | | Consent of Independent Registered Public Accounting Firm
| | x | | x |
| 31(a) | | Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy, 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 |
|
| | | | | | | |
| | Exhibit Number | | Description | | NEE | | FPL |
| | 10(yy) | | Limited Forbearance Agreement, dated as of December 1, 2016 | | x | | |
| *10(zz) | | Form of Oncor Letter Agreement (filed as Exhibit 10.2 to Form 8-K dated July 29, 2016, File No. 1-8841) | | x | | |
| *10(aaa) | | Form of Bi-lateral Term Loan Agreement between NextEra Energy Capital Holdings, Inc. and the Lender dated February 7, 2017 (filed as Exhibit 10 to Form 8-K dated February 10, 2017, File No. 1-8841) | | x | | |
| 12(a) | | Computation of Ratios | | x | | |
| 12(b) | | Computation of Ratios | | | | x |
| 21 | | Subsidiaries of NextEra Energy, Inc. | | x | | |
| 23 | | Consent of Independent Registered Public Accounting Firm | | x | | x |
| 31(a) | | Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy, 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 |
| 99 | | Eighth Amended Joint Plan of Reorganization of Energy Future Holdings Corp., et al., Pursuant to Chapter 11 of the Bankruptcy Code | | 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
** Schedules have been omitted pursuant to Item 601(b)(2) of Regulation S-K. NEE will furnish the omitted schedules to the SEC upon request.
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.
Item 16. Form 10-K Summary
Not applicable
NEXTERA ENERGY, INC. SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized and in the capacities and on the date indicated.
NextEra Energy, Inc.
|
|
| JAMES L. ROBO |
James L. Robo Chairman, President and Chief Executive Officer and Director (Principal Executive Officer) |
Date: February 21, 2014
23, 2017
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.
Signature and Title as of February 21, 201423, 2017:
|
| | |
MORAY P. DEWHURSTJOHN W. KETCHUM | | CHRIS N. FROGGATTTERRELL KIRK CREWS, II |
Moray P. DewhurstJohn W. Ketchum
Executive Vice Chairman President, Finance and Chief Financial Officer and Executive Vice President - Finance
(Principal Financial Officer) | | Chris N. FroggattTerrell Kirk Crews, II
Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer) |
Directors:
|
| | |
| SHERRY S. BARRAT | | RUDY E. SCHUPPAMY B. LANE |
Sherry S. Barrat
| | Rudy E. Schupp
|
ROBERT M. BEALL, II | | JOHN L. SKOLDS |
Robert M. Beall, II
| | John L. Skolds
Amy B. Lane |
| JAMES L. CAMAREN | | WILLIAM H. SWANSONRUDY E. SCHUPP |
James L. Camaren
| | William H. SwansonRudy E. Schupp |
KENNETH B. DUNN | | MICHAEL H. THAMANJOHN L. SKOLDS |
Kenneth B. Dunn
| | MichaelJohn L. Skolds
|
| NAREN K. GURSAHANEY | | WILLIAM H. ThamanSWANSON |
Naren K. Gursahaney
| | William H. Swanson |
| KIRK S. HACHIGIAN | | HANSEL E. TOOKES, II |
Kirk S. Hachigian
| | Hansel E. Tookes, II
|
| TONI JENNINGS | | |
Toni Jennings
| | |
FLORIDA POWER & LIGHT COMPANY SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized and in the capacities and on the date indicated.
Florida Power & Light Company
|
|
JAMES L. ROBOERIC E. SILAGY |
James L. RoboEric E. Silagy
ChairmanPresident and Chief Executive Officer and Director
(Principal Executive Officer) |
Date: February 21, 201423, 2017
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.
Signature and Title as of February 21, 201423, 2017:
|
| | |
MORAY P. DEWHURSTJOHN W. KETCHUM | | KIMBERLY OUSDAHL |
Moray P. DewhurstJohn W. Ketchum
Executive Vice President, Finance and Chief Financial Officer and Director (Principal Financial Officer) | | Kimberly Ousdahl Vice President Controller and Chief Accounting Officer (Principal Accounting Officer) |
Director:
|
|
ERIC E. SILAGYJAMES L. ROBO |
Eric E. SilagyJames L. Robo |
Supplemental Information to be Furnished With Reports Filed Pursuant to Section 15(d) of the Securities Exchange Act of 1934 by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Securities Exchange Act of 1934
No annual report, proxy statement, form of proxy or other proxy soliciting material has been sent to security holders of FPL during the period covered by this Annual Report on Form 10-K for the fiscal year ended December 31, 20132016.
