ANNUAL REPORT 2019
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, 2019
OR
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ________ to ________
Commission
File
Number
1-8841
2-27612
Exact name of registrants as specified in their
charters, address of principal executive offices and
registrants' telephone number
NEXTERA ENERGY, INC.
FLORIDA POWER & LIGHT COMPANY
700 Universe Boulevard
Juno Beach, Florida 33408
(561) 694-4000
State or other jurisdiction of incorporation or organization: Florida
Securities registered pursuant to Section 12(b) of the Act:
IRS Employer
Identification
Number
59-2449419
59-0247775
Registrants
NextEra Energy, Inc.
Title of each class
Trading Symbol(s)
Common Stock, $0.01 Par Value
4.872% Corporate Units
NEE
NEE.PRO
Name of each exchange
on which registered
New York Stock Exchange
New York Stock Exchange
Florida Power & Light Company
None
Indicate by check mark if the registrants are well-known seasoned issuers, as defined in Rule 405 of the Securities Act of 1933.
NextEra Energy, Inc. Yes ☑ No ☐
Florida Power & Light Company Yes ☑ No ☐
Indicate by check mark if the registrants are not required to file reports pursuant to Section 13 or Section 15(d) of the Securities Exchange Act of 1934.
NextEra Energy, Inc. Yes ☐ No ☑ Florida Power & Light Company Yes ☐ No ☑
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the
preceding 12 months, and (2) have been subject to such filing requirements for the past 90 days.
NextEra Energy, Inc. Yes ☑ No ☐
Florida Power & Light Company Yes ☑ No ☐
Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation
S‑T during the preceding 12 months.
NextEra Energy, Inc. Yes ☑ No ☐
Florida Power & Light Company Yes ☑ No ☐
Indicate by check mark whether the registrants are a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging
growth company.
Large Accelerated Filer ☑ Accelerated Filer ☐ Non-Accelerated Filer ☐ Smaller Reporting Company ☐ Emerging Growth Company ☐
NextEra Energy, Inc.
Florida Power & Light Company Large Accelerated Filer ☐ Accelerated Filer ☐ Non-Accelerated Filer ☑ Smaller Reporting Company ☐ Emerging Growth Company ☐
If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised
financial accounting standards provided pursuant to Section 13(a) of the Securities Exchange Act of 1934. ¨
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 at June 28, 2019 (based on the closing market price
on the Composite Tape on June 28, 2019) was $97,905,404,884.
There was no voting or non-voting common equity of Florida Power & Light Company held by non-affiliates at June 28, 2019.
Number of shares of NextEra Energy, Inc. common stock, $0.01 par value, outstanding at January 31, 2020: 488,965,893
Number of shares of Florida Power & Light Company common stock, without par value, outstanding at January 31, 2020, 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 2020 Annual Meeting of Shareholders are incorporated by reference in Part III hereof.
__________________________________
This combined Form 10-K represents separate filings by NextEra Energy, Inc. and Florida Power & Light Company. Information contained herein relating to an individual
registrant is filed by that registrant on its own behalf. Florida Power & Light Company makes no representations as to the information relating to NextEra Energy, Inc.'s
other operations.
Florida Power & Light Company meets the conditions set forth in General Instruction I.(1)(a) and (b) of Form 10-K and is therefore filing this Form with the reduced
disclosure format.
Acronyms and defined terms used in the text include the following:
Term
Meaning
DEFINITIONS
AFUDC - equity
AOCI
Bcf
CAISO
capacity clause
DOE
Duane Arnold
environmental clause
EPA
ERCOT
FERC
Florida Southeast Connection
FPL
FPSC
fuel clause
GAAP
GHG
Gulf Power
ISO
ISO-NE
ITC
kW
kWh
Management's Discussion
MISO
MMBtu
mortgage
MW
MWh
NEE
NEECH
NEER
NEET
NEP
NEP OpCo
NERC
net capacity
net generating capacity
net generation
Note __
NextEra Energy Resources
NRC
NYISO
O&M expenses
OCI
OEB
OTC
OTTI
PJM
PMI
Point Beach
PTC
PUCT
PV
Recovery Act
regulatory ROE
RPS
RTO
Sabal Trail
Seabrook
SEC
tax reform
U.S.
equity component of allowance for funds used during construction
accumulated other comprehensive income
billion cubic feet
California Independent System Operator
capacity cost recovery clause, as established by the FPSC
U.S. Department of Energy
Duane Arnold Energy Center
environmental cost recovery clause
U.S. Environmental Protection Agency
Electric Reliability Council of Texas
U.S. Federal Energy Regulatory Commission
Florida Southeast Connection, LLC, a wholly owned NextEra Energy Resources subsidiary
Florida Power & Light Company
Florida Public Service Commission
fuel and purchased power cost recovery clause, as established by the FPSC
generally accepted accounting principles in the U.S.
greenhouse gas(es)
Gulf Power Company
independent system operator
ISO New England Inc.
investment tax credit
kilowatt
kilowatt-hour(s)
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations
Midcontinent Independent System Operator
One million British thermal units
mortgage and deed of trust dated as of January 1, 1944, from FPL to Deutsche Bank Trust Company Americas, as
supplemented and amended
megawatt(s)
megawatt-hour(s)
NextEra Energy, Inc.
NextEra Energy Capital Holdings, Inc.
a segment comprised of NextEra Energy Resources and NEET
NextEra Energy Transmission, LLC
NextEra Energy Partners, LP
NextEra Energy Operating Partners, LP
North American Electric Reliability Corporation
net ownership interest in pipeline(s) capacity
net ownership interest in plant(s) capacity
net ownership interest in plant(s) generation
Note __ to consolidated financial statements
NextEra Energy Resources, LLC
U.S. Nuclear Regulatory Commission
New York Independent System Operator
other operations and maintenance expenses in the consolidated statements of income
other comprehensive income
Ontario Energy Board
over-the-counter
other than temporary impairment
PJM Interconnection, L.L.C.
NextEra Energy Marketing, LLC
Point Beach Nuclear Power Plant
production tax credit
Public Utility Commission of Texas
photovoltaic
The American Recovery and Reinvestment Act of 2009, as amended
return on common equity as determined for regulatory purposes
renewable portfolio standards
regional transmission organization
Sabal Trail Transmission, LLC, an entity in which a NextEra Energy Resources subsidiary has a 42.5% ownership interest
Seabrook Station
U.S. Securities and Exchange Commission
Tax Cuts and Jobs Act
United States of America
NEE, FPL, NEECH, NextEra Energy Resources and NEET each has subsidiaries and affiliates with names that may include NextEra Energy, FPL, NextEra Energy
Resources, NextEra Energy Transmission, NextEra, FPL Group, FPL Energy, FPLE, NEP and similar references. For convenience and simplicity, in this report the terms
NEE, FPL, NEECH, NextEra Energy Resources, NEET and NEER are sometimes used as abbreviated references to specific subsidiaries, affiliates or groups of
subsidiaries or affiliates. The precise meaning depends on the context.
2
TABLE OF CONTENTS
Definitions
Forward-Looking Statements
Business
Risk Factors
Unresolved Staff Comments
Properties
Legal Proceedings
Mine Safety Disclosures
PART I
PART II
Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity
Securities
Selected Financial Data
Management's Discussion and Analysis of Financial Condition and Results of Operations
Quantitative and Qualitative Disclosures About Market Risk
Financial Statements and Supplementary Data
Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
Controls and Procedures
Other Information
Item 1.
Item 1A.
Item 1B.
Item 2.
Item 3.
Item 4.
Item 5.
Item 6.
Item 7.
Item 7A.
Item 8.
Item 9.
Item 9A.
Item 9B.
PART III
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
Directors, Executive Officers and Corporate Governance
Executive Compensation
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Certain Relationships and Related Transactions, and Director Independence
Principal Accounting Fees and Services
Item 15.
Item 16.
Exhibits, Financial Statement Schedules
Form 10-K Summary
Signatures
PART IV
Page No.
2
3
4
21
32
32
32
32
33
34
35
55
56
113
113
113
114
114
114
114
115
116
124
125
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, 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.
3
Item 1. Business
OVERVIEW
PART I
NEE is one of the largest electric power and energy infrastructure companies in North America and a leader in the renewable energy
industry. NEE has two principal businesses, FPL and NEER. FPL is the largest electric utility in the state of Florida and one of the
largest electric utilities in the U.S. FPL’s strategic focus is centered on investing in generation, transmission and distribution facilities
to continue to deliver on its value proposition of low bills, high reliability, outstanding customer service and clean energy solutions
for the benefit of its more than five million customers. NEER is the world's largest generator of renewable energy from the wind
and sun. NEER’s strategic focus is centered on the development, construction and operation of long-term contracted assets
throughout the U.S. and Canada, including renewable generation facilities, natural gas pipelines, electric transmission facilities and
battery storage projects. In January 2019, NEE completed the acquisition of Gulf Power, a rate-regulated electric utility engaged
in the generation, transmission, distribution and sale of electric energy in northwest Florida. See Gulf Power section below.
As described in more detail in the following sections, NEE seeks to create value in its two principal businesses by meeting its
customers' needs more economically and more reliably than its competitors. 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 available 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 financial strength in different
ways. FPL and NEER share a common platform with the objective of lowering costs and creating efficiencies for their businesses.
NEE and its subsidiaries continue to develop and implement enterprise-wide initiatives focused on improving productivity, process
effectiveness and quality.
NEE, which employed approximately 14,800 people at December 31, 2019, was incorporated in 1984 under the laws of Florida.
NEE's segments for financial reporting purposes are FPL, Gulf Power and NEER, which is comprised of two wholly owned subsidiaries
of NEE that are combined for segment reporting purposes. NEECH, another wholly owned subsidiary of NEE, owns and provides
funding for NEE's operating subsidiaries, other than FPL and its subsidiaries and Gulf Power. NEP, an affiliate of NextEra Energy
Resources, was formed in 2014. NEP acquires, manages and owns contracted clean energy projects with stable, long-term cash
flows. See NEER section below for further discussion of NEP, including changes to its governance structure, which resulted in the
deconsolidation of NEP in January 2018.
4
FPL
FPL was incorporated under the laws of Florida in 1925 and is a rate-regulated electric utility engaged primarily in the generation,
transmission, distribution and sale of electric energy in Florida. In 2018, FPL acquired a retail gas business (see Note 8 - Other).
FPL is the largest electric utility in the state of Florida and one of the largest electric utilities in the U.S. At December 31, 2019, FPL
had approximately 27,400 MW of net generating capacity, approximately 75,400 circuit miles of transmission and distribution lines
and 661 substations. FPL provides service to its electric customers through an integrated transmission and distribution system that
links its generation facilities to its customers. At December 31, 2019, FPL served more than ten million people through more than
five million customer accounts. FPL's service territory, which covers most of the east and lower west coasts of Florida, and plant
locations at December 31, 2019 were as follows (see FPL Sources of Generation below):
5
CUSTOMERS AND REVENUE
FPL's primary source of operating revenues is from its retail customer base; it also serves a limited number of wholesale customers
within Florida. The percentage of FPL's operating revenues and customer accounts by customer class were as follows:
For both retail and wholesale customers, the prices (or rates) that FPL may charge are 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 a reasonable rate of return on 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, including the implementation of ideas generated from cost savings
initiatives. 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 2019 average bill for 1,000 kWh of monthly residential usage was
well below both the average of reporting electric utilities within Florida and the July 2019 national average (the latest date for which
this data is available) as indicated below:
6
FRANCHISE AGREEMENTS AND COMPETITION
FPL's service to its electric 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 holds 184 franchise agreements with various
municipalities and counties in Florida with varying expiration dates through 2049. These franchise agreements cover approximately
88% of FPL's retail customer base in Florida. FPL also provides service to customers in 11 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 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 low customer bills, high reliability and outstanding 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 2019, 2018 and 2017, operating
revenues from wholesale and industrial electric 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 a request for proposal (RFP) except when the FPSC determines that an exception from the RFP process
is in the public interest. The RFP process allows independent power producers and others to bid to supply the new generating
capacity. If a bidder has the most cost-effective alternative, meets other criteria such as financial viability and demonstrates adequate
expertise and experience in building and/or operating generating capacity of the type proposed, the investor-owned electric utility
would seek to negotiate a 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 SOURCES OF GENERATION
At December 31, 2019, FPL's resources for serving load consisted of approximately 27,554 MW, of which 27,440 MW were from
FPL-owned facilities and 114 MW were available through purchased power agreements. FPL owned and operated 31 units that
used fossil fuels, primarily natural gas, with generating capacity of 22,170 MW and had a joint ownership interest in 1 out-of-state
coal unit, which it does not operate, with net generating capacity of 634 MW. In addition, FPL owned, or had undivided interests in,
and operated, 4 nuclear units with net generating capacity totaling 3,479 MW (see Nuclear Operations below) and owned and
operated 17 solar generation facilities with generating capacity totaling 1,157 MW (excluding 75 MW of non-incremental solar
capability which is provided in conjunction with 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.
FPL is in the process of modernizing two generating units at its Lauderdale facility to a high-efficiency, clean-burning natural gas
unit (Dania Beach Clean Energy Center). The Dania Beach Clean Energy Center is expected to provide approximately 1,200 MW
of generating capacity and to be in service in 2022.
7
Fuel Sources
FPL relies upon a mix of fuel sources for its generation facilities, the ability of some of its generation facilities to operate on both
natural gas and oil, and on purchased power to maintain the flexibility to achieve a more economical fuel mix in order to respond
to market and industry developments.
2019 Net Generating Capacity by Fuel Type
MW
2019 Net Generation by Fuel Type*
MWh
Solar 4%
Coal 4%
Solar 2%
Coal 2%
Nuclear 13%
Nuclear 22%
Natural Gas* 79%
Natural Gas 74%
*approximately 71% has dual fuel capability
*Oil is less than 1%
Significant Fuel and Transportation Contracts. At December 31, 2019, FPL had the following significant fuel and transportation
contracts in place:
•
•
•
FPL has firm transportation contracts with seven different transportation suppliers for natural gas pipeline capacity for an
aggregate maximum quantity of 2,769,000 MMBtu/day currently, of which 1,969,000 MMBtu/day have expiration dates
ranging from 2020 to 2036. The remaining 800,000 MMBtu/day increases to 1,200,000 MMBtu/day starting in mid-2020
through 2042. See Note 15 - Contracts.
FPL has several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel with
expiration dates ranging from March 2020 through 2032.
Additionally, FPL enters into 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.
Nuclear Operations
At December 31, 2019, FPL owned, or had undivided interests in, and operated the four nuclear units in Florida discussed below.
FPL'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 require the unit to be removed from service
for variable lengths of time.
Facility
St. Lucie Unit No. 1
St. Lucie Unit No. 2
Turkey Point Unit No. 3
Turkey Point Unit No. 4
______________________
FPL's Ownership
(MW)
Beginning of Next
Scheduled Refueling Outage
Operating License
Expiration Date
981
840(a)
837
821
April 2021
February 2020
March 2020
October 2020
2036
2043
2052
2053
(a)
Excludes 147 MW operated by FPL but owned by non-affiliates.
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 existing operating licenses, provide for St. Lucie Unit No. 1 to be shut down in 2036
with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 commencing in 2043. Current plans
provide for the dismantlement of Turkey Point Units Nos. 3 and 4 with decommissioning activities commencing in 2052 and 2053,
respectively.
8
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 that is generated at these facilities through license expiration.
FPL ENERGY MARKETING AND TRADING
FPL's Energy Marketing & Trading division (EMT) buys and sells wholesale energy commodities, such as natural gas, oil and
electricity. EMT procures natural gas and oil for FPL's use in power generation and sells excess natural gas, oil and electricity. EMT
also uses derivative instruments (primarily swaps, options and forwards) to manage the physical and financial risks inherent in the
purchase and sale of fuel and electricity. Substantially all of the results of EMT's activities are passed through to customers in the
fuel or capacity clauses. See Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity and Note 4.
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, in
some cases delegating authority to state agencies. 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 Electric 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 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
return on common equity. 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. Existing base rates remain in effect until new base rates are approved by the FPSC.
Base Rates Effective January 2017 through at least 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 beginning April 1, 2019 for a new approximately 1,720 MW natural gas-fired combined-cycle unit in
Okeechobee County, Florida (Okeechobee Clean Energy Center) that achieved commercial operation on
March 31, 2019.
In addition, FPL is eligible to receive base rate increases associated with the addition of up to 300 MW annually of new solar
generation in each of 2017 through 2020 with an installed cost cap of $1,750 per kW. Approximately 900 MW of new solar
generating capacity has become operational, 600 MW in the first quarter of 2018 and 300 MW in the first quarter of 2019. An
additional 300 MW is expected to be operational in the second quarter of 2020.
FPL's allowed regulatory 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 retail base rates.
9
•
•
Subject to certain conditions, FPL may amortize, over the term of the 2016 rate agreement, up to $1.0 billion of depreciation
reserve surplus plus the reserve amount that remained under FPL's previous rate agreement (approximately $250 million),
provided that in any year of the 2016 rate agreement FPL must amortize at least enough reserve to maintain a 9.60% earned
regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 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
amounts above $400 million. See Note 1 - Storm Fund, Storm Reserve and Storm Cost Recovery regarding several hurricanes
that impacted FPL's service territory from 2016 - 2019.
Cost Recovery Clauses. Cost recovery clauses are designed to permit full recovery of certain costs and provide a return on certain
assets allowed to be recovered through various 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 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 - primarily fuel costs, the most significant of the cost recovery clauses in terms of operating revenues (see Note 1 -
Rate Regulation);
Capacity - primarily certain costs associated with the acquisition of several electric generation facilities (see Note 1 - Rate
Regulation);
Energy Conservation - costs associated with implementing energy conservation programs; 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 solar facilities placed in service prior to 2016.
In June 2019, Florida's Governor signed legislation into law which directed the FPSC to propose new rules that would (i) require
state investor-owned utilities to submit a 10-year transmission and distribution storm protection plan (SPP) to the FPSC for approval
at least every three years and (ii) provide for annual clause recovery of storm protection plan costs not already recovered in base
rates or through other clauses, including costs for hardening of overhead transmission and distribution lines, undergrounding of
certain distribution lines and vegetation management. In October 2019, the FPSC issued its proposed SPP and SPP cost recovery
clause rules. Final rules will become effective on February 18, 2020.
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 grants 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 an electric reliability
organization with authority to establish and independently enforce mandatory reliability standards applicable to all users, owners
and operators of the bulk-power system. 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 an 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 approved
by FERC. The NERC's regional entities also enforce reliability standards approved by the FERC. FPL is subject to these reliability
standards 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 as 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.
10
FPL EMPLOYEES
FPL had approximately 8,900 employees at December 31, 2019, with approximately 32% of these employees represented by the
International Brotherhood of Electrical Workers (IBEW), substantially all of which are under a collective bargaining agreement with
FPL that expires October 31, 2020.
NEER
NextEra Energy Resources was formed in 1998 to aggregate NEE's competitive energy businesses. During the fourth quarter of
2019, NEE began reporting NextEra Energy Resources and NEET, a rate-regulated transmission business, on a combined basis
for segment reporting purposes, and the combined segment is referred to as NEER. NEET previously was reported in Corporate
and Other. See Note 16. NEER is a diversified clean energy business with a strategy that emphasizes the development, construction
and operation of long-term contracted assets with a focus on renewable projects. The NEER segment currently owns, develops,
constructs, manages and operates electric generation facilities in wholesale energy markets primarily in the U.S. and Canada.
NEER, with approximately 21,900 MW of total net generating capacity at December 31, 2019, is one of the largest wholesale
generators of electric power in the U.S., including approximately 21,240 MW of net generating capacity across 37 states and 520
MW of net generating capacity in 4 Canadian provinces (see Note 1 - Disposal of Businesses/Assets). At December 31, 2019,
NEER operates facilities with a total generating capacity of 24,700 MW. NEER produces the majority of its electricity from clean
and renewable sources as described more fully below. NEER is the world's largest generator of renewable energy from the wind
and sun based on 2019 MWh produced on a net generation basis. In addition, NEER develops and constructs battery storage
projects, which when combined with its renewable projects, serve to enhance its ability to meet customer needs for a nearly firm
generation source. NEER also owns and operates rate-regulated transmission facilities, primarily in Texas and California, and
transmission lines that connect its electric generation facilities to the electric grid, which are comprised of approximately 190
substations and 1,865 circuit miles of transmission lines at December 31, 2019.
NEER also engages in energy-related commodity marketing and trading activities, including entering into financial and physical
contracts, primarily to hedge the production from its generation assets that is not sold under long-term power supply agreements.
These contracts primarily include power 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 offer customized power and gas and related risk
management services to wholesale customers. In addition, NEER participates in natural gas, natural gas liquids and oil production
through operating and 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. NEER also hedges the expected output from its gas infrastructure production assets to protect against
price movements.
NEP - NEP was formed in 2014 to acquire, manage and own contracted clean energy projects with stable long-term cash flows
through a limited partner interest in NEP OpCo. NEP's projects include energy projects contributed by NextEra Energy Resources
to NEP OpCo in connection with NEP’s initial public offering in July 2014 as well as additional energy projects acquired thereafter.
NextEra Energy Resources' indirect limited partnership interest in NEP OpCo based on the number of outstanding NEP OpCo
common units was approximately 60.8% at December 31, 2019. NEP was deconsolidated from NEE for financial reporting purposes
in January 2018 as a result of changes made to NEP's governance structure that enhanced NEP unitholder governance rights. As
a result, NextEra Energy Resources began reflecting its ownership interest in NEP as an equity method investment with its earnings/
losses from NEP as equity in earnings (losses) of equity method investees and accounting for its asset sales to NEP as third-party
sales in its consolidated financial statements. See Note 1 - NextEra Energy Partners, LP. Prior to the deconsolidation, NEE owned
a controlling general partner interest in NEP and consolidated NEP. At December 31, 2019, NEP owned, or had an interest in, a
portfolio of 36 wind and solar projects with generating capacity totaling approximately 5,331 MW and had membership interests in
contracted natural gas pipelines, all located in the U.S. as further discussed in Generation and Other Operations. NextEra Energy
Resources operates essentially all of the energy projects in NEP's portfolio and its ownership interest in the portfolio's generating
capacity was approximately 3,240 MW at December 31, 2019.
GENERATION AND OTHER OPERATIONS
NEER sells products associated with its own generation facilities (energy, capacity, renewable energy credits (RECs) and ancillary
services) in competitive markets in regions where those facilities are located. Customer transactions may be supplied from NEER
generation facilities or from purchases in the wholesale markets, or from a combination thereof. See Markets and Competition
below.
11
At December 31, 2019, NEER managed or participated in the management of essentially all of the following generation projects,
natural gas pipelines and transmission facilities that it wholly owned or in which it had an ownership interest.
Generation Assets and Other Operations
2019 Net Generating Capacity by Fuel Type
MW
Oil 4%
Natural Gas 7%
Solar 12%
Nuclear 12%
Wind 65%
12
Generation Assets.
NEER's portfolio of generation assets primarily consist of generation facilities with long-term power sales agreements for substantially
all of their capacity and/or energy output. Information related to contracted generation assets at December 31, 2019 was as follows:
•
•
•
represented approximately 19,796 MW of total net generating capacity;
weighted-average remaining contract term of the power sales agreements and the remaining life of the PTCs associated
with repowered wind facilities of approximately 16 years, based on forecasted contributions to earnings and forecasted
amounts of electricity produced by the repowered wind facilities; and
contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel have expiration dates
ranging from March 2020 through 2033 (see Note 15 - Contracts).
NEER's merchant generation assets primarily consist of a nuclear generation facility and oil-fired generation facilities that do not
have long-term power sales agreements to sell their capacity and/or energy output and therefore require active marketing and
hedging. Merchant generation assets at December 31, 2019 represented approximately 2,070 MW of total net generating capacity,
including 1,102 MW from nuclear generation and 805 MW from oil-fired peak generation facilities, and are primarily located in the
Northeast region of the U.S. NEER utilizes swaps, options, futures and forwards to lock in pricing and manage the commodity price
risk inherent in power sales and fuel purchases.
Other Operations.
Gas Infrastructure Business - At December 31, 2019, NextEra Energy Resources had ownership interests in natural gas pipelines,
the most significant of which are discussed below, and in oil and gas shale formations located primarily in the Midwest and South
regions of the U.S.
Operational:
Texas Pipelines(a)
Sabal Trail(c)
Florida Southeast Connection(c)
Central Penn Line(d)
Under Construction:
Mountain Valley Pipeline(e)
______________________
Miles
of
Pipeline
542
517
169
185
Pipeline
Location/Route
Total
Net Capacity
(per day)
Actual/Expected
In-Service
Dates
Ownership
South Texas
Southwestern Alabama to Central Florida
Central Florida to South Florida
58.8%
42.5%
100%
Northeastern Pennsylvania to Southeastern
Pennsylvania
23.7%
(b)
(b)
2.32 Bcf
1950 - 2014
0.35 Bcf -
0.46 Bcf
0.64 Bcf
0.30 Bcf -
0.43 Bcf
June 2017 -
Mid-2021
June 2017
October 2018 -
Mid-2022
303
Northwestern West Virginia to Southern
31%
0.62 Bcf
End of 2020
Virginia
(a)
A NEP 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.
Approximately 1.82 Bcf per day of net capacity is contracted with firm ship-or-pay contracts that have expiration dates ranging from 2020 to 2035.
See Note 15 - Contracts for a discussion of transportation contracts with FPL.
(b) Ownership percentage based on NextEra Energy Resources limited partnership interest in NEP OpCo common units.
(c)
(d) NEP has an indirect equity method investment in the Central Penn Line (CPL) which represents an approximately 39% aggregate ownership interest in the CPL.
(e) Completion of construction of the natural gas pipeline is subject to final permitting. Also, see Note 15 - Contracts for a discussion of a transportation contract with
a NextEra Energy Resources subsidiary.
Rate-Regulated Transmission - At December 31, 2019, certain entities within the NEER segment had ownership interests in rate-
regulated transmission facilities, the most significant of which are discussed below, which facilities are located primarily in ERCOT,
CAISO and Independent Electricity System Operator (IESO) jurisdictions.
Miles
Substations
Kilovolt
Location
Rate
Regulator
Ownership
Actual/Expected
In-Service
Dates
330
53
280
6
2
-
345
Central Texas
200 DC(a) Northern California
PUCT
FERC
100%
100%
2013
2010
230
Ontario, Canada
OEB
50%
Fourth Quarter
of 2021
Operational:
Lone Star
Trans Bay Cable
Under Construction:
NextBridge Infrastructure
______________________
(a) Direct current
13
Customer Supply and Proprietary Power and Gas Trading - 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
NextEra Energy Resources 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 Generation Assets Fuel/Technology Mix
NextEra Energy Resources utilized the following mix of fuel sources for generation facilities in which it has an ownership interest:
2019 Net Generation by Fuel Type*
MWh
Natural Gas 3%
Solar 6%
Nuclear 32%
Wind 59%
Wind Facilities
*Oil is less than 1%
•
•
•
located in 19 states in the U.S. and 4 provinces in Canada;
operated a total generating capacity of 15,955 MW at December 31, 2019;
ownership interests in a total net generating capacity of 14,111 MW at December 31, 2019;
◦
◦
all MW are from contracted wind assets located primarily throughout Texas and the West and Midwest regions
of the U.S. and Canada;
added approximately 1,125 MW of new generating capacity and repowered wind generating capacity totaling
1,091 MW in the U.S. in 2019 (see Note 1 - Disposal of Businesses/Assets for asset sales to NEP).
Solar Facilities
•
•
•
located in 26 states in the U.S.;
operated PV and solar thermal facilities with a total generating capacity of 2,684 MW at December 31, 2019;
ownership interests in PV and solar thermal facilities with a total net generating capacity of 2,662 MW at December 31,
2019;
◦
essentially all MW are from contracted solar facilities located primarily throughout the West and South regions
of the U.S.;
added approximately 512 MW of generating capacity in the U.S. in 2019 (see Note 1 - Disposal of Businesses/
Assets for asset sales to NEP).
◦
14
Fossil Facilities
•
•
•
operated natural gas generation facilities with a total generating capacity of 2,110 MW at December 31, 2019;
ownership interests in natural gas generation facilities with a total net generating capacity of 1,565 MW at December 31,
2019;
◦
◦
approximately 1,407 MW are contracted and 158 MW are merchant;
located in 2 states in the Northeast region of the U.S. and in Florida; and
operated oil-fired peak generation facilities with a total generating capacity of 878 MW with an ownership or undivided
interests in total net generating capacity of 805 MW at December 31, 2019 primarily located in Maine.
Nuclear Facilities
At December 31, 2019, NextEra Energy Resources owned, or had undivided interests in, and operated the four nuclear units
discussed below. 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 require the unit to be
removed from service for variable lengths of time.
Facility
Location
Seabrook
Duane Arnold
Point Beach Unit No. 1
Point Beach Unit No. 2
______________________
New Hampshire
Iowa
Wisconsin
Wisconsin
Ownership
(MW)
1,102(a)
431(b)
595
595
Portfolio
Category
Merchant
Contracted(c)
Contracted(d)
Contracted(d)
Next Scheduled
Refueling Outage
Operating License
Expiration Date
April 2020
None(c)
October 2020
March 2020
2050
2034(c)
2030
2033
Excludes 147 MW operated by NEER but owned by non-affiliates.
Excludes 184 MW operated by NEER but owned by non-affiliates.
(a)
(b)
(c) NEER sells all of its share of the output of Duane Arnold under an amended long-term contract expiring in December 2020. Operations of Duane Arnold are
expected to cease in late 2020. See Note 5 - Nonrecurring Fair Value Measurements.
(d) 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. In the case of Duane Arnold, a
plan for decontamination and decommissioning is required to be submitted to the NRC no later than 2 years following shutdown of
the facility.
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 that is generated at these facilities through license
expiration or, in the case of Duane Arnold, through expected shutdown of the facility.
Policy Incentives for Renewable Energy Projects
U.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 RPS programs.
Pursuant to the U.S. federal Modified Accelerated Cost Recovery System, wind and solar projects are fully depreciated for tax
purposes over a five-year period even though the useful life of such projects is generally much longer than five years.
Owners of utility-scale wind facilities are eligible to claim an income tax credit (the PTC, or an ITC in lieu of the PTC) upon initially
achieving commercial operation. The PTC is determined based on the amount of electricity produced by the wind facility during the
first ten years of commercial operation. This incentive was created under the Energy Policy Act of 1992 and has been extended
several times. Alternatively, an ITC equal to 30% of the cost of a wind facility may be claimed in lieu of the PTC. Owners of solar
facilities are eligible to claim a 30% ITC for new solar facilities. Previously, owners of solar facilities could have elected 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
facilities where construction began before the end of 2011 and the facilities were placed in service before 2017. In order to qualify
for the PTC (or an ITC in lieu of the PTC) for wind or ITC for solar, construction of a facility must begin before a specified date and
the taxpayer must maintain a continuous program of construction or continuous efforts to advance the project to completion. The
Internal Revenue Service (IRS) issued guidance stating that the safe harbor for continuous efforts and continuous construction
requirements will generally be satisfied if the facility is placed in service no more than four years after the year in which construction
of the facility began. The IRS also confirmed that retrofitted wind facilities may re-qualify for PTCs or ITCs pursuant to the 5% safe
harbor for the begin construction requirement, as long as the cost basis of the new investment is at least 80% of the facility’s total
fair value. Tax credits for qualifying wind and solar projects are subject to the following schedule.
15
PTC(b)
Wind ITC(c)
Solar ITC(d)
_________________________
Year construction of project begins(a)
2015
2016
2017
2018
2019
2020
2021
2022
100%
30%
30%
100%
30%
30%
80%
24%
30%
60%
18%
30%
40%
12%
30%
60%
18%
26%
-
-
-
-
22%
10%
(a)
(b)
(c)
(d)
Project must be placed in service no more than four years after the year in which construction of the project began to qualify for the PTC or ITC.
Percentage of the full PTC available for wind projects that begin construction during the applicable year.
Percentage of eligible project costs that can be claimed as ITC by wind projects that begin construction during the applicable year.
Percentage of eligible project costs that can be claimed as ITC by solar projects that begin construction during the applicable year. ITC is limited to 10% for solar
projects not placed in service before January 1, 2024.
Other countries, including Canada, 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.
MARKETS AND COMPETITION
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 significant impact on pricing.
The degree and nature of competition is different in wholesale markets than in retail markets. During 2019, 2018 and 2017,
approximately 85% of NEER's revenue was derived from wholesale 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. and Canadian electricity markets encompass three classes of services: 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 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. At December 31, 2019, NEER also had generation facilities
with ownership interests in a total net generating capacity of approximately 4,642 MW that fall within reliability regions that are not
under the jurisdiction of an established RTO or ISO, including 2,365 MW within the Western Electricity Coordinating Council and
1,252 MW within the Florida Reliability 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:
16
NEER competes in different regions to differing degrees, but in general it seeks to enter into long-term bilateral contracts for the
full output of its generation facilities. At December 31, 2019, approximately 90% of NEER's net 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, serve to protect a portion of the revenue that NEER expects to derive from the associated
generation facility. 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 under long-term contracts, or may be sold separately for the wind and solar
generation not sold under long-term contracts. The purchasing party is solely entitled to the reporting rights and ownership of the
environmental 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 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.
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.
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, 2019, essentially all of NEER's operating independent power projects located in the U.S. have received exempt
wholesale generator status as defined under the Public Utility Holding Company Act of 2005. Exempt wholesale generators own
17
or operate a facility exclusively to sell electricity to wholesale customers. They are barred from selling electricity directly to retail
customers. While projects with 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 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. Rates of NEER's rate-regulated transmission businesses are set by regulatory bodies as noted
in Generation and Other Operations - Generation Assets and Other Operations - Other Operations - Rate-Regulated Transmission.
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.
Certain entities within the NEER segment and their affiliates are also subject to federal and provincial or regional regulations in
Canada 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 OEB and may also be required to complete registrations
and maintain market participant status with the IESO, 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 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 had approximately 5,000 employees at December 31, 2019. NEER has collective bargaining agreements with the IBEW,
the Utility Workers Union of America, and the Security Police and Fire Professionals of America, which collectively represent
approximately 15% of NEER's employees. The collective bargaining agreements have two- to five-year terms and expire between
March 2021 and September 2022.
GULF POWER
On January 1, 2019, NEE completed the acquisition of all of the outstanding common shares of Gulf Power under a stock purchase
agreement with The Southern Company dated May 20, 2018, as amended, for approximately $4.44 billion in cash consideration
and the assumption of approximately $1.3 billion of Gulf Power debt. Gulf Power was incorporated under the laws of Maine in 1925
and became a Florida corporation after being domesticated under the laws of Florida in 2005. Gulf Power, a rate-regulated electric
utility under the jurisdiction of the FPSC, is engaged in the generation, transmission, distribution and sale of electric energy in
northwest Florida. Gulf Power is subject to regulations similar to FPL (see FPL - FPL Regulation above). Gulf Power operates under
a base rate settlement agreement, which took effect July 1, 2017, that provides for an allowed regulatory ROE of 10.25%, with a
range of 9.25% to 11.25%. As of December 31, 2019, Gulf Power served approximately 470,000 customers in eight counties
throughout northwest Florida and had approximately 2,300 MW of fossil-fueled electric net generating capacity and 9,500 miles of
transmission and distribution lines located primarily in Florida. See Note 8 - Gulf Power Company for further discussion.
18
NEE ENVIRONMENTAL MATTERS
NEE and its subsidiaries, including FPL, are subject to environmental laws and regulations, including extensive federal, state and
local environmental statutes, rules and regulations, for the siting, construction and ongoing operations of their facilities. The U.S.
government and certain states and regions, as well as the Government of Canada and its provinces, have taken and continue to
take certain actions, such as proposing and finalizing regulations or setting targets or goals, regarding the regulation and reduction
of GHG emissions and the increase of renewable energy generation. Numerous environmental regulations also affecting FPL,
NEER, Gulf Power, and certain other subsidiaries relate to threatened and endangered species and/or their habitats, as well as
other avian and bat species. 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, provide for the protection of numerous species, including endangered
species of birds and bats and/or their habitats, migratory birds and eagles. The environmental laws in Canada, including, among
others, the Species at Risk Act, provide for the recovery of wildlife species that are endangered or threatened and the management
of species of special concern. Complying with these environmental laws and regulations could result in, among other things, changes
in the design and operation of existing facilities and changes or delays in the location, design, construction and operation of new
facilities. Failure to comply could result in fines, penalties, criminal sanctions or injunctions. 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 have, a material adverse effect on the financial statements of NEE and FPL. NEE's rate-regulated subsidiaries expect
to seek recovery for compliance costs associated with any new environmental laws and regulations, which recovery for FPL and
Gulf Power would be through their respective environmental clause.
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' or affiliates' websites) are not incorporated by reference into this
combined Form 10-K.
19
INFORMATION ABOUT OUR EXECUTIVE OFFICERS(a)
Name
Age
Position
Miguel Arechabala
Deborah H. Caplan
Paul I. Cutler
Joseph T. Kelliher
John W. Ketchum
Rebecca J. Kujawa
James M. May
Donald A. Moul
Ronald R. Reagan
James L. Robo
Charles E. Sieving
58
57
60
59
49
44
43
54
51
57
47
Executive Vice President, Power Generation Division of NEE
Executive Vice President, Power Generation Division of FPL
Executive Vice President, Human Resources and Corporate Services of NEE
Executive Vice President, Human Resources and Corporate Services of FPL
Treasurer of NEE
Treasurer of FPL
Assistant Secretary of NEE
Executive Vice President, Federal Regulatory Affairs of NEE
President and Chief Executive Officer of NextEra Energy Resources
Executive Vice President, Finance and Chief Financial Officer of NEE
Executive Vice President, Finance and Chief Financial Officer of FPL
Vice President, Controller and Chief Accounting Officer of NEE
Executive Vice President, Nuclear Division and Chief Nuclear Officer of NEE
Vice President and Chief Nuclear Officer of FPL
Executive Vice President, Engineering, Construction and Integrated Supply Chain of NEE
Vice President, Engineering and Construction of FPL
Chairman, President and Chief Executive Officer of NEE
Chairman of FPL
Executive Vice President & General Counsel of NEE
Executive Vice President of FPL
Eric E. Silagy
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President and Chief Executive Officer of FPL
______________________
Effective Date
January 1, 2014
April 15, 2013
February 19, 2003
February 18, 2003
December 10, 1997
May 18, 2009
March 1, 2019
March 1, 2019
March 1, 2019
January 1, 2020
May 17, 2019
January 1, 2020
March 1, 2019
December 13, 2013
May 2, 2012
December 1, 2008
January 1, 2009
May 30, 2014
(a)
Information is as of February 14, 2020. 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. Ketchum served as Executive
Vice President, Finance and Chief Financial Officer of NEE and FPL from March 2016 to February 2019 and NEE’s Senior Vice President, Finance from February
2015 to March 2016. Ms. Kujawa served as Vice President, Business Management of NextEra Energy Resources from March 2012 to February 2019. Mr. May
served as Controller of NextEra Energy Resources from April 2015 to February 2019 and was Director of Accounting of NextEra Energy Resources from July 2013
to April 2015. Mr. Moul served as Vice President and Chief Nuclear Officer of NEE from May 2019 to December 2019. He previously held various roles at several
subsidiaries of FirstEnergy Corp., which are energy suppliers involved in the generation, transmission and distribution of electricity. Mr. Moul was Executive on
Special Assignment of FirstEnergy Solutions Corp. from March 2019 to May 2019, President and Chief Nuclear Officer of FirstEnergy Generation Companies from
March 2018 to March 2019, President of FirstEnergy Generation LLC from April 2017 to March 2018, Senior Vice President, Fossil Operations and Environmental
of FirstEnergy Solutions from August 2015 to April 2017, and Vice President, Commodity Operations of FirstEnergy Solutions from October 2012 to August 2015.
Mr. Reagan served as Vice President, Engineering and Construction of NEE from November 2018 to December 2019 and Vice President, Integrated Supply Chain
of NEE from October 2012 to November 2018.
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Item 1A. Risk Factors
Risks Relating to NEE's and FPL's Business
The business, financial condition, results of operations and prospects of NEE and FPL are subject to a variety of risks, many of
which are beyond the control of NEE and FPL. These 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.
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 industry, 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, natural 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 a reasonable
return on invested capital through base rates, cost recovery clauses, other regulatory mechanisms or otherwise.
FPL operates as an electric utility and is 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 and fuel for its plant operations, issuances of securities, and aspects of
the siting, construction and operation of its generation 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 earnings. The regulatory process also does not provide any assurance as to achievement of authorized or other earnings
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 a reasonable return on invested capital cannot be recovered through base rates, cost recovery clauses,
other regulatory mechanisms or otherwise. Certain other subsidiaries of NEE are 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 NEE 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 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
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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 state governments in the U.S. and portions of Canada provide
incentives, such as tax incentives, RPS or feed-in tariffs, 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 that 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 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, interpretations or ballot or 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, interpretations or ballot or regulatory initiatives regarding deregulation or
restructuring of the energy industry, regulation of the commodities trading and derivatives markets, and regulation of environmental
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 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 changes that reverse or restrict the competitive restructuring of the energy industry
in those jurisdictions in which such restructuring has occurred. Any of these events could have a material adverse effect on NEE's
business, financial condition, results of operations and prospects.
NEE’s and FPL’s OTC financial derivatives are subject to rules implementing certain provisions of the Dodd-Frank Wall Street
Reform and Consumer Protection Act and similar international regulations. NEE and FPL cannot predict the impact any 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 such rules and regulations could 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 environmental laws, regulations and 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, soil quality,
climate change, emissions of greenhouse gases, including, but not limited to, carbon dioxide, 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 or enjoin 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. Certain subsidiaries of NEE are also subject to foreign environmental laws, regulations and other
standards and, as such, are subject to similar risks.
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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 requirements and stricter or more
expansive application of existing environmental laws and regulations.
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, governmental entities and 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.
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, carbon dioxide and methane, from electric generation units using fossil fuels like coal and natural
gas. The potential effects of greenhouse gas emission limits on NEE's and FPL's electric generation 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 generation 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 laws or regulations 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 generation 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.
NEE's and FPL's operations and businesses are subject to extensive federal regulation, which generally imposes significant and
increasing compliance costs on their operations and 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, they 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, 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. These factors, including the ultimate
resolution of income tax matters, may result in material adjustments to tax-related assets and liabilities, which could materially
adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.
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NEE's and FPL's business, financial condition, results of operations and prospects may be materially adversely affected
due to adverse results of litigation.
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 or FPL is involved or other future legal proceedings may
have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.
Development and 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
be available, and NEE and FPL could become obligated to make delay or termination payments or become obligated for other
damages under contracts, could experience the loss of tax credits or tax incentives, or delayed or diminished returns, and could
be required to write off all or a portion of their investment in the project. Any of these events could have a material adverse effect
on NEE's and FPL's business, financial condition, results of operations and prospects.
NEE and FPL 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-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 or resolving third-party challenges to such
licenses or permits, 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, retail gas distribution system in Florida 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, retail gas distribution system
in Florida 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 or legal claims, liability
to third parties for property and personal injury damage or loss of life, 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 or
distribution systems or pipelines;
availability of replacement equipment;
risks of property damage, human injury or loss of life from energized equipment, hazardous substances or explosions, fires,
leaks or other events, especially where facilities are located near populated areas;
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•
•
•
•
•
•
•
potential environmental impacts of gas infrastructure operations;
availability of adequate water resources and ability to satisfy water intake and discharge requirements;
inability to identify, manage properly or mitigate 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 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, 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 plants 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 and Gulf Power operates in northwest Florida,
areas that historically have 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 generation 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 generation 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, cyberattacks, 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 cyberattacks
and other disruptive activities of individuals or groups. There have been cyberattacks within the energy industry 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 materially adversely affected by, such activities.
Terrorist acts, cyberattacks 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 generation, distribution or transmission facilities or capital
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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 could 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 could result in certain projects becoming 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 the delay or cancellation of oil and gas production and transmission projects,
could cause projects to experience lower returns, and could result in certain projects becoming 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 that are either within, or wholly or partially outside of, NEE's
control, may materially adversely affect NEE's business, financial condition, results of operations and prospects.
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Reductions in the liquidity of energy markets may restrict the ability of NEE to manage its operational risks, which, in
turn, could negatively affect NEE's results of operations.
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. Market liquidity is driven in part by the number of active market participants. 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.
If power transmission or natural gas, nuclear fuel or other commodity transportation facilities are unavailable or disrupted,
the ability for subsidiaries of NEE, including FPL, to sell and deliver power or natural gas may be limited.
Subsidiaries of NEE, including FPL, 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 the control of subsidiaries of NEE, including FPL, (such as severe weather or a generation or transmission facility outage,
pipeline rupture, or sudden and significant increase or decrease in wind generation) may limit or halt their ability 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.
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 industry in which NEE and FPL participate.
27
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, 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, terrorist activities or cyber incidents. 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 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 and 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.
28
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 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 adversely affected if they are
unable to maintain, negotiate or renegotiate franchise agreements on acceptable terms with municipalities and counties
in Florida.
Subsidiaries of NEE, including FPL, may 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 the subsidiary's revenues. If they are unable to maintain, negotiate or renegotiate such franchise
agreements on acceptable terms, it could contribute to lower earnings and they may not fully realize the anticipated benefits from
significant investments and expenditures, which could adversely affect NEE's and FPL's business, financial condition, results of
operations and prospects.
NEE's and FPL's business, financial condition, results of operations and prospects 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 energy industry.
NEE is likely to encounter significant competition for acquisition opportunities that may become available as a result of the
consolidation of the energy industry in general. In addition, NEE may be unable to identify attractive acquisition opportunities at
favorable prices and to complete and integrate them successfully and in a timely manner.
Nuclear Generation Risks
The 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 or cyber incident 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 the maximum amount of private liability insurance obtainable, and participates in a secondary financial
protection system, which provides liability insurance coverage for 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, plus any
applicable taxes, for 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. 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 and/or result in reduced revenues.
29
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, depending upon the 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 NEE's or FPL's nuclear generation units through the end of their respective operating
licenses, or in the case of Duane Arnold through expected shutdown, could have a material adverse effect on NEE's and
FPL's business, financial condition, results of operations and prospects.
If any of NEE's or FPL's nuclear generation facilities are not operated for any reason through the life of their respective operating
licenses, or in the case of Duane Arnold through expected shutdown, 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.
NEE's and FPL's nuclear units are periodically removed from service to accommodate planned 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 planned refueling and maintenance outages,
including, but not limited to, inspections, repairs and certain other modifications as well as to replace 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, among other factors, 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 could increase NEE's and FPL's cost of 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 its subsidiaries, to access the capital and credit markets
to provide project-specific or other financing for electric generation or other 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, as well as actions by third parties or lenders, 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.
30
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 credit 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 liquidity, financial condition and results of 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 condition and results of operations.
NEE holds certain 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.
31
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.
Through an indirect wholly owned subsidiary, NEE owns a limited partner interest in NEP OpCo. NEP's inability to access capital
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 common unitholders, including NEE, and on the value of NEE’s limited partnership interest
in NEP OpCo. In addition, NEP's issuance of additional common units, securities convertible into NEP common units or other
securities in connection with acquisitions could cause significant common unitholder dilution and reduce cash distributions to its
common unitholders, including NEE, if the acquisitions are not sufficiently accretive.
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
See Item 1. Business - FPL and Item 1. Business - NEER for a description of principal properties.
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. Subsidiaries within the NEER segment have ownership interests in entities that own generation
facilities, pipeline facilities and transmission assets and a number of those facilities and assets are encumbered by liens securing
various financings. Additionally, the majority of NEER's generation facilities, pipeline facilities and transmission lines are located on
land under easement or leased from owners of private property. See Note 1 - Electric Plant, Depreciation and Amortization.
Item 3. Legal Proceedings
None
Item 4. Mine Safety Disclosures
Not applicable
32
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." As of the close of business on January 31, 2020, there were 16,776 holders of record of NEE's
common stock. 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. In February 2020, NEE announced that it would increase its quarterly dividend on its common stock from $1.25
per share to $1.40 per share.
Issuer Purchases of Equity Securities. Information regarding purchases made by NEE of its common stock during the three
months ended December 31, 2019 is as follows:
Period
10/1/19 - 10/31/19
11/1/19 - 11/30/19
12/1/19 - 12/31/19
Total
______________________
Total
Number
of Shares
Purchased(a)
Average
Price Paid
Per Share
Total Number of Shares
Purchased as Part of a
Publicly Announced Program
—
990
387
1,377
$
$
$
—
231.42
238.22
233.33
—
—
—
—
Maximum Number of
Shares that May Yet be
Purchased Under the
Program(b)
45,000,000
45,000,000
45,000,000
(a)
(b)
Includes: (1) in November 2019, shares of common stock withheld from employees to pay certain withholding taxes upon the vesting of stock awards granted to
such employees under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan; and (2) in December 2019, 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 NextEra
Energy, Inc. Amended and Restated Long-Term Incentive Plan (former LTIP) to an executive officer of deferred retirement share awards.
In May 2017, NEE's Board of Directors authorized repurchases of up to 45 million shares of common stock over an unspecified period.
33
Item 6. Selected Financial Data
SELECTED DATA OF NEE(a):
Operating revenues
Net income(b)
Net income attributable to NEE(b)(c)
Earnings per share attributable to NEE - basic(b)(c)
$
Earnings per share attributable to NEE - assuming dilution(b)(c) $
$
$
$
Dividends paid per share of common stock
Total assets(d)
Long-term debt, excluding current portion
Capital expenditures, independent power and
other investments and nuclear fuel purchases:
FPL
Gulf Power
NEER(e)
Corporate and Other(e)
Total
______________________
Years Ended December 31,
2019
2018
2017
2016
2015
(millions, except per share amounts)
19,204
3,388
3,769
7.82
7.76
5.00
117,691
37,543
$
$
$
$
$
$
$
$
16,727
5,776
6,638
14.03
13.88
4.44
103,702
26,782
$
$
$
$
$
$
$
$
17,173
5,323
5,380
11.48
11.39
3.93
97,963
31,410
$
$
$
$
$
$
$
$
16,138
2,999
2,906
6.27
6.24
3.48
90,474
27,765
$
$
$
$
$
$
$
$
17,486
2,762
2,752
6.11
6.06
3.08
82,479
26,681
5,755
$
5,135
$
5,291
$
3,934
$
3,633
729
6,505
4,473
—
7,189
680
—
5,415
34
—
5,607
95
—
4,691
53
$
$
$
$
$
17,462
$
13,004
$
10,740
$
9,636
$
8,377
(a)
(b)
(c)
(d)
(e)
See Note 8 for a discussion of 2019 acquisitions and Note 1 - NextEra Energy Partners, LP for a discussion of the deconsolidation of NEP in January 2018.
2018 includes an after-tax gain of approximately $3.0 billion related to the deconsolidation of NEP (see Note 1 - NextEra Energy Partners, LP). 2017 includes
approximately $1.8 billion ($1.9 billion attributable to NEE) of net favorable tax reform impacts (see Note 6). 2017 and 2016 include after-tax gains on the sale of
the fiber-optic telecommunications business of $685 million (see Note 1 - Disposal of Businesses/Assets) and natural gas generation facilities of $219 million.
Also, on an after-tax basis, 2017 includes an impairment charge of $258 million related to Duane Arnold (see Note 5 - Nonrecurring Fair Value Measurements).
2018 reflects approximately $497 million relating to a reduction of differential membership interests as a result of a change in the federal corporate income tax
rate effective January 1, 2018 (see Note 1 - Sales of Differential Membership Interests).
Includes assets held for sale of approximately $440 million in 2019 related to two solar generation facilities and $452 million in 2016 related to a fiber-optic
telecommunications business (see Note 1 - Disposal of Businesses/Assets) and $1,009 million in 2015 related to merchant natural gas generation facilities.
Prior year amounts have been adjusted as discussed in Note 16.
34
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 businesses, FPL, which serves more than
five million customer accounts in Florida and is one of the largest electric utilities in the U.S., and NEER, which together with affiliated
entities is the world's largest generator of renewable energy from the wind and sun based on 2019 MWh produced on a net generation
basis. The table below presents net income (loss) attributable to NEE and earnings (loss) per share attributable to NEE, assuming
dilution, by reportable segment, FPL and NEER, as well as Gulf Power, acquired in January 2019 (see Note 8 - Gulf Power Company)
and Corporate and Other, which is primarily comprised of the operating results of other business activities, as well as other income
and expense items, including interest expense, and eliminating entries. See Note 16 for additional segment information, including
a discussion of a change in segment reporting. The following discussion should be read in conjunction with the Notes to Consolidated
Financial Statements contained herein and all comparisons are with the corresponding items in the prior year. Certain 2018 and
2017 segment amounts have been retrospectively adjusted as discussed in Note 16.
FPL
Gulf Power(a)
NEER(b)(c)(d)
Corporate and Other(d)
NEE(c)
______________________
Net Income (Loss) Attributable
to NEE
Years Ended December 31,
Earnings (Loss) Per Share
Attributable to NEE, Assuming
Dilution
Years Ended December 31,
2019
2018
2017
2019
2018
2017
(millions)
$
2,334
$
2,171
$
1,880
$
4.81
$
4.55
$
3.98
180
1,807
(552)
—
4,704
(237)
—
2,997
503
0.37
3.72
—
9.82
(1.14)
(0.49)
—
6.34
1.07
$
3,769
$
6,638
$
5,380
$
7.76
$
13.88
$
11.39
(a) Gulf Power was acquired in January 2019. See Note 8 - Gulf Power Company.
(b) NEER’s results reflect an allocation of interest expense from NEECH based on a deemed capital structure of 70% debt and differential membership interests sold
by NextEra Energy Resources' subsidiaries.
(c) NEP was deconsolidated from NEER in January 2018. See Note 1 - NextEra Energy Partners, LP.
(d) NEER's and Corporate and Other's results for 2018 and 2017 were retrospectively adjusted to reflect a segment change. See Note 16.
For the five years ended December 31, 2019, NEE delivered a total shareholder return of approximately 161.5%, above the
S&P 500’s 73.9% return, the S&P 500 Utilities' 63.2% return and the Dow Jones U.S. Electricity's 63.0% 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.
35
Adjusted Earnings
NEE prepares its financial statements under GAAP. However, management uses earnings adjusted for certain items (adjusted
earnings), a non-GAAP financial measure, internally for financial planning, analysis of performance, 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 that adjusted earnings provide a more meaningful representation of NEE's fundamental earnings power.
Although these 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.
The following table provides details of the after-tax adjustments to net income considered in computing NEE's adjusted earnings
discussed above.
Net losses associated with non-qualifying hedge activity(a)
Tax reform-related, including the impact of tax rate change on differential membership interests(b)
NEP investment gains, net(c)
Change in unrealized gains (losses) on NEER's nuclear decommissioning funds and OTTI, net(d)
Acquisition-related(e)
Operating results of solar projects in Spain - NEER
Gain on sale of the fiber-optic telecommunications business - Corporate and Other(f)
Duane Arnold impairment charge(g)
______________________
Years Ended December 31,
2019
2018
(millions)
2017
$
$
$
$
$
$
$
$
(404) $
(89) $
96
176
$
$
(70) $
(2) $
— $
— $
(186) $
436
2,863
$
$
(125) $
(14) $
(9) $
— $
— $
(37)
1,881
—
2
(63)
5
685
(258)
(a)
(b)
(c)
(d)
(e)
(f)
(g)
For 2019, 2018 and 2017, approximately $63 million of losses, $41 million of gains, and $46 million of gains, respectively, are included in NEER's net income; the
balance is included in Corporate and Other. The change in non-qualifying hedge activity 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. In 2017, net losses associated with non-qualifying hedge activity were partly offset by approximately $95 million of tax reform
impacts.
For 2019, approximately $89 million related to the impact of tax rate change on differential membership interests relates to NEER. For 2018, approximately $421
million of favorable tax reform-related impacts, including the impact of tax rate change on differential membership interests, relates to NEER and the balance
relates to Corporate and Other. For 2017, approximately $1,929 million of net favorable tax reform impacts and $50 million of net unfavorable tax reform impacts
relate to NEER and FPL, respectively; the balance relates to Corporate and Other. See Note 1 - Storm Fund, Storm Reserve and Storm Cost Recovery and -
Sales of Differential Membership Interests and Note 6.
For 2019 and 2018, approximately $96 million and $2,885 million, respectively, relates to NEER; the 2018 balance relates to Corporate and Other. See Note 1 -
NextEra Energy Partners, LP and - Disposal of Businesses/Assets.
For 2019, 2018 and 2017, approximately $176 million of gains, $127 million of losses, and $2 million of gains, respectively, are included in NEER's net income;
the balance for 2018 is included in Corporate and Other.
For 2019, approximately $44 million, $20 million and $6 million of costs are included in Corporate and Other's, Gulf Power's and NEER's net income, respectively.
For 2018, $9 million of costs are included in Corporate and Other's net income; the balance is included in NEER. For 2017, the costs relate to Corporate and
Other. See Note 1 - Acquisition-Related.
See Note 1 - Disposal of Businesses/Assets for a discussion of the sale of the fiber-optic telecommunications business.
Approximately $246 million of the impairment charge is included in NEER's net income; the balance is included in Corporate and Other. See Note 5 - Nonrecurring
Fair Value Measurements.
NEE segregates into two categories unrealized mark-to-market gains and losses and timing impacts related to derivative
transactions. The first category, referred to as non-qualifying hedges, represents certain energy derivative, 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 impact of the
non-qualifying hedges as a meaningful measure of current period performance. The second category, referred to as trading activities,
which is included in adjusted earnings, represents the net unrealized effect of actively traded positions entered into to take advantage
of expected market price movements and all other commodity hedging activities. At FPL, substantially all changes in the fair value
of energy derivative transactions are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement,
any gains or losses are passed through the fuel clause. See Note 4.
36
2019 Summary
Net income attributable to NEE for 2019 was lower than 2018 by $2,869 million, or $6.12 per share, assuming dilution, due to lower
results at NEER and Corporate and Other, partly offset by higher results at FPL and the addition of results from Gulf Power.
FPL's increase in net income in 2019 was primarily driven by continued investments in plant in service and other property.
NEER's results decreased in 2019 primarily reflecting the absence of the 2018 NEP investment gains upon deconsolidation and
the favorable adjustment to differential membership interests recognized in 2018 related to the decrease in federal corporate income
tax rate effective January 1, 2018. These decreases were partly offset by 2019 net unrealized gains on equity securities held in
NEER's nuclear decommissioning funds compared to net unrealized losses in 2018 and higher contributions from new investments.
In 2019, NEER added approximately 1,125 MW of new wind generating capacity, 1,091 MW of wind repowering generating capacity
and 512 MW of solar generating capacity in the U.S. and increased its backlog of contracted renewable development projects.
During 2019, Gulf Power contributed $180 million of net income attributable to NEE.
Corporate and Other's results in 2019 decreased primarily due to higher interest costs, unfavorable non-qualifying hedge activity,
as well as acquisition and integration costs incurred in 2019.
NEE and its subsidiaries require funds to support and grow their businesses. These funds are primarily provided by cash flows
from operations, borrowings or issuances of short- and long-term debt, proceeds from differential membership investors, sales of
assets to NEP or third parties and, from time to time, issuances of equity securities. See Liquidity and Capital Resources - Liquidity.
RESULTS OF OPERATIONS
Net income attributable to NEE for 2019 was $3.77 billion compared to $6.64 billion in 2018. In 2019, net income attributable to
NEE declined primarily due to lower results at NEER and Corporate and Other, partly offset by higher results at FPL and the addition
of results from Gulf Power. The comparison of the results of operations for the years ended December 31, 2018 and 2017 are
included in Management's Discussion in NEE's and FPL's Annual Report on Form 10-K for the year ended December 31, 2018.
In June 2019, subsidiaries within the NEER segment sold ownership interests in three wind generation facilities and three solar
generation facilities with a total net generating capacity of approximately 611 MW to a subsidiary of NEP. See Note 1 - Disposal of
Businesses/Assets.
In July 2019, a wholly owned subsidiary of NEET acquired the outstanding membership interests of an entity that indirectly owns
Trans Bay, which owns and operates a 53-mile, high-voltage direct current underwater transmission cable system in California.
See Note 8 - Trans Bay Cable, LLC.
NEE's effective income tax rates for the years ended December 31, 2019 and 2018 were approximately 12% and 21%, respectively.
The decrease in the rate primarily reflects the amortization of deferred regulatory credits, primarily at FPL, the impact of higher tax
credits, an adjustment related to differential membership interests and lower pre-tax income. See Note 6.
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 2019 and 2018 was $2,334 million and $2,171 million,
respectively, representing an increase of $163 million. The increase was primarily driven by higher earnings from investments in
plant in service and other property. Such investments grew FPL's average retail rate base by approximately $3.3 billion in 2019
and reflect, among other things, solar generation additions, ongoing transmission and distribution additions and investments in
FPL's generation infrastructure, including the Okeechobee Clean Energy Center, which achieved commercial operation during the
first quarter of 2019.
In September 2017, Hurricane Irma passed through Florida causing damage throughout much of FPL's service territory. In December
2017, following the enactment of tax reform, FPL used available reserve amortization to offset nearly all of the storm restoration
costs that were expensed, and FPL is partially restoring the reserve amortization through tax savings generated during the term of
the 2016 rate agreement. In September 2019, FPL’s service territory was impacted by Hurricane Dorian. In December 2019, FPL
determined that it would not seek recovery of the costs incurred as a result of Hurricane Dorian through a storm surcharge from
customers and instead recorded such costs as storm restoration costs in NEE’s and FPL’s consolidated statements of income. All
of the Hurricane Dorian storm restoration costs were offset by utilization of available reserve amortization resulting from operational
efficiencies generated at the business. See Note 1 - Storm Fund, Storm Reserve and Storm Cost Recovery.
The use of reserve amortization is permitted by the 2016 rate agreement. See Item 1. Business - FPL - FPL Regulation - FPL
Electric Rate Regulation - Base Rates for additional information on the 2016 rate agreement. In order to earn a targeted regulatory
ROE, subject to limitations associated with the 2016 rate 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
37
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 must be adjusted, in part,
by reserve amortization to earn the targeted regulatory ROE. In certain periods, reserve amortization is 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
revenue and costs not recoverable from retail customers by the FPSC. In 2019 and 2018, FPL recorded the reversal of reserve
amortization of approximately $357 million and $541 million, respectively. FPL's regulatory ROE for both 2019 and 2018 was
approximately 11.60%.
During 2019, FPL's operating revenues increased $330 million primarily related to higher retail base revenues of $323 million,
higher revenues of $60 million as a result of the acquisition of the entity that operates Florida City Gas in July 2018 and other
increases associated with various cost recovery clause revenues, partly offset by $78 million in lower storm-related revenues.
Retail Base
FPL’s retail base revenues for 2019 and 2018 reflect the 2016 rate agreement. In 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 2020,
establishes FPL's allowed regulatory ROE at 10.55%, with a range of 9.60% to 11.60%, and allowed for retail rate base increases
in 2017, 2018, and upon commencement of commercial operations at the Okeechobee Clean Energy Center and certain solar
projects. See Item 1. Business - FPL - FPL Regulation - FPL Electric Rate Regulation - Base Rates for additional information on
the 2016 rate agreement.
The increase in retail base revenues in 2019 primarily reflects additional revenues of approximately $210 million related to retail
base rate increases associated with the Okeechobee Clean Energy Center and the 2019 addition of new solar generation. In 2019,
retail base revenues were also impacted by a decrease of 0.3% in the average usage per retail customer and an increase of 2.0%
in the average number of customer accounts. Although the weather in 2019 was favorable when compared to 2018, usage per
retail customer decreased slightly. See Note 1 - Rate Regulation.
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 certain solar and environmental projects and the unamortized
balance of the regulatory asset associated with FPL's acquisition of certain generation facilities. See Item 1. Business - FPL - FPL
Regulation - FPL Electric 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 2019 net overrecovery impacting NEE and FPL's operating cash flows was approximately $188 million.
Storm-related revenues decreased in 2019 primarily as a result of the conclusion of the storm-recovery bond surcharge in the third
quarter of 2019. See Note 9 - FPL.
In 2019 and 2018, cost recovery clauses contributed approximately $117 million and $113 million, respectively, to FPL’s net income.
Other Items Impacting FPL's Consolidated Statements of Income
Storm Restoration Costs
In December 2019, FPL determined that it would not seek recovery of Hurricane Dorian storm restoration costs through a surcharge
from customers and instead recorded such costs as storm restoration costs in NEE’s and FPL’s consolidated statements of income.
See Note 1 - Storm Fund, Storm Reserve and Storm Cost Recovery.
Depreciation and Amortization Expense
The major components of FPL’s depreciation and amortization expense are as follows:
Reserve reversal recorded under the 2016 rate agreement
Other depreciation and amortization recovered under base rates (excluding reserve amortization) and
other
Depreciation and amortization primarily recovered under cost recovery clauses and securitized storm-
recovery cost amortization
Total
Years Ended December 31,
2019
2018
(millions)
357
$
1,876
291
2,524
$
541
1,739
353
2,633
$
$
38
Depreciation expense decreased $109 million during 2019 primarily reflecting a lower reversal of reserve amortization in 2019
compared to 2018 and lower storm-recovery cost amortization primarily as a result of the final payment of the storm-recovery bonds
in the third quarter 2019 (see Note 9 - FPL). Reserve amortization, or reversal of such amortization, reflects adjustments to accrued
asset removal costs provided under the 2016 rate agreement in order to achieve the targeted regulatory ROE. Reserve amortization
is recorded as a reduction to (or when reversed as an increase to) accrued asset removal costs which is reflected in noncurrent
regulatory liabilities on the consolidated balance sheets. At December 31, 2019, approximately $893 million remains in accrued
asset removal costs related to reserve amortization. The decreases in depreciation and amortization expense during 2019 were
partly offset by increased depreciation related to higher plant in service balances.
NEER: Results of Operations
NEER owns, develops, constructs, manages and operates electric generation facilities in wholesale energy markets primarily in
the U.S., as well as in Canada. NEER also provides full energy and capacity requirements services, engages in power and gas
marketing and trading activities, owns and operates rate-regulated transmission facilities and transmission lines and invests in
natural gas, natural gas liquids and oil production and pipeline infrastructure assets. NEER’s net income less net loss attributable
to noncontrolling interests for 2019 and 2018 was $1,807 million and $4,704 million, respectively, resulting in a decrease in 2019
of $2,897 million. The primary drivers, on an after-tax basis, of the change are in the following table.
New investments(a)
Existing assets(a)
Gas infrastructure(a)
Customer supply and proprietary power and gas trading(b)
NEET(b)
Asset sales/abandonment
Interest and other general and administrative expenses(c)
Other, including other investment income and income taxes
Change in non-qualifying hedge activity(d)
Change in unrealized gains/losses on equity securities held in nuclear decommissioning funds and OTTI,
net(d)
Tax reform-related, including the impact of tax rate change on differential membership interests(d)
NEP investment gains, net(d)
Operating results of the solar projects in Spain(d)
Acquisition-related(d)
Decrease in net income less net loss attributable to noncontrolling interests
$
$
______________________
Increase (Decrease)
From Prior Period
Year Ended December 31, 2019
(millions)
260
(17)
61
24
20
(83)
(172)
104
(104)
303
(510)
(2,789)
7
(1)
(2,897)
(a) Reflects after-tax project contributions, including the net effect of deferred income taxes and other benefits associated with PTCs and ITCs for wind and solar
projects, as applicable (see Note 1 - Income Taxes and - Sales of Differential Membership Interests and Note 6), but excludes allocation of interest expense or
corporate general and administrative expenses. Results from projects and pipelines are included in new investments during the first twelve months of operation
or ownership. Project results are included in existing assets and pipeline results are included in gas infrastructure beginning with the thirteenth month of operation
or ownership.
Excludes allocation of interest expense and corporate general and administrative expenses.
Includes differential membership interest costs. Excludes unrealized mark-to-market gains and losses related to interest rate derivative contracts, which are included
in change in non-qualifying hedge activity.
See Overview - Adjusted Earnings for additional information.
(b)
(c)
(d)
New Investments
In 2019, results from new investments increased primarily due to higher earnings, including the net effect of deferred income taxes
and other benefits associated with PTCs and ITCs, related to the addition of wind and solar generating projects during or after 2018.
Other Factors
Supplemental to the primary drivers of the changes in NEER's net income less net loss 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 2019 increased $655 million primarily due to:
•
•
•
•
favorable unrealized mark-to-market activity of $295 million from non-qualifying hedges,
revenues from new investments of $232 million,
higher revenues of $198 million from the customer supply and proprietary power and gas trading business, and
higher revenues of $122 million from the gas infrastructure business,
39
partly offset by,
•
lower revenues from existing assets of $226 million primarily related to the absence of revenues of certain wind and solar
facilities sold to NEP in December 2018 and June 2019 and lower wind resource as compared to 2018.
Operating Expenses - net
Operating expenses - net for 2019 increased $19 million primarily due to:
•
higher fuel and depreciation expense of $150 million primarily related to the customer supply and proprietary power and gas
trading and gas infrastructure businesses,
higher operating expenses associated with new investments of approximately $137 million, and
an impairment charge of approximately $72 million in 2019 related to the decision to no longer move forward with the
construction of a wind facility (see Note 1 - Construction Activity),
•
•
partly offset by,
•
higher net gains on the disposal of businesses/assets of $320 million, primarily related to the gain recognized on the sale of
ownership interests in wind and solar projects to NEP (see Note 1 - Disposal of Businesses/Assets).
Interest Expense
NEER's interest expense for 2019 increased $278 million primarily reflecting unfavorable impacts of approximately $251 million
related to changes in the fair value of interest rate derivative instruments and higher borrowing costs to support growth in the
business.
Equity in Earnings of Equity Method Investees
Lower earnings from equity method investees in 2019 primarily reflects equity in losses of NEP primarily related to unfavorable
impacts related to changes in the fair value of interest rate derivative instruments and the absence of approximately $150 million
related to a 2018 favorable adjustment at NEP to the differential membership interests due to the decrease in the federal corporate
income tax rate. The decrease was partly offset by increased equity in earnings of other equity method investees.
Gain on NEP Deconsolidation
The NEP deconsolidation resulted in a gain of approximately $3.9 billion ($3.0 billion after tax) in NEE's consolidated statements
of income during 2018. See Note 1 - NextEra Energy Partners, LP.
Change in Unrealized Gains (Losses) on Equity Securities Held in NEER's Nuclear Decommissioning Funds - net
Changes in the fair value of equity securities in NEER's nuclear decommissioning funds, primarily equity securities in NEER's
special use funds, relate to favorable market conditions in 2019 compared to 2018.
Tax Credits, Benefits and Expenses
PTCs from wind projects and 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 $75 million and $88 million in 2019 and 2018, respectively. ITCs totaled approximately $199 million and $131 million
in 2019 and 2018, respectively. A portion of the PTCs and ITCs have been allocated to investors in connection with sales of differential
membership interests. PTCs and ITCs can significantly affect the effective income tax rate depending on the amount of pretax
income. The amount of PTCs recognized can be significantly affected by wind generation and by PTC roll off. See Note 6.
Net Loss Attributable to Noncontrolling Interests
Net loss attributable to noncontrolling interests primarily represents the activity related to the sales of differential membership
interests. The decrease for 2019 primarily reflects the absence of a 2018 adjustment of approximately $497 million ($373 million
after-tax) related to the decrease in federal corporate income tax rate effective January 1, 2018.
Gulf Power: Results of Operations
Following its acquisition in January 2019, Gulf Power contributed approximately $180 million of net income attributable to NEE for
2019. Gulf Power's operating revenues were approximately $1,487 million and operating expenses totaled $1,216 million for 2019.
Corporate and Other: Results of Operations
Corporate and Other is primarily comprised of the operating results of other business activities, as well as corporate interest income
and expenses. Corporate and Other allocates a portion of NEECH's corporate interest expense to NEER. Interest expense is
allocated based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources'
subsidiaries.
Corporate and Other's results decreased $315 million during 2019 primarily reflecting higher interest costs associated with higher
debt balances primarily related to the Gulf Power acquisition financing, higher after-tax losses of approximately $114 million related
to non-qualifying hedge activity, as well as higher acquisition and integration costs incurred in 2019.
40
LIQUIDITY AND CAPITAL RESOURCES
NEE and its subsidiaries 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 of short- and long-
term debt and, from time to time, equity securities, proceeds from differential membership investors and sales of assets to NEP or
third parties, consistent with NEE’s and FPL’s objective of maintaining, on a long-term basis, a capital structure that will support a
strong investment grade credit rating. NEE, FPL and NEECH rely on access to credit and capital markets as significant sources of
liquidity for capital requirements and other operations that are not satisfied by operating cash flows. The inability of NEE, FPL and
NEECH to maintain their current credit ratings could affect their ability to raise short- and long-term capital, their cost of capital and
the execution of their respective financing strategies, and could require the posting of additional collateral under certain agreements.
In October 2015, NEE authorized a program to purchase, from time to time, up to $150 million of common units representing limited
partner interests in NEP. Under the program, 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 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 common units and may be modified or terminated by NEE at any time. 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, 2019, NEE had purchased approximately $36 million of NEP common units under
this program. At December 31, 2019, NEE owned a noncontrolling general partner interest in NEP and beneficially owned
approximately 59.9% of NEP’s voting power.
41
Cash Flows
NEE's sources and uses of cash for 2019, 2018 and 2017 were as follows:
Sources of cash:
Cash flows from operating activities
Issuances of long-term debt
Proceeds from differential membership investors
Proceeds from sale of the fiber-optic telecommunications business
Sale of independent power and other investments of NEER
Issuances of common stock - net
Net increase in commercial paper and other short-term debt(a)
Proceeds from issuance of NEP convertible preferred units - net
Non-operating distributions from equity method investees
Other sources - net
Total sources of cash
Uses of cash:
Capital expenditures, acquisitions, independent power and other investments and nuclear fuel purchases
Retirements of long-term debt
Net decrease in commercial paper and other short-term debt(a)
Payments to related parties under a cash sweep and credit support agreement – net
Dividends
Other uses - net
Total uses of cash
Effects of currency translation on cash, cash equivalents and restricted cash
Net increase (decrease) in cash, cash equivalents and restricted cash(a)
______________________
(a) 2019 and 2018 amounts relate to the acquisition of Gulf Power. See Note 8 - Gulf Power Company.
Years Ended December 31,
2019
2018
(millions)
2017
$
8,155
$
6,593
$
13,919
1,604
—
1,163
1,494
—
—
—
274
26,609
(17,462)
(5,492)
(4,799)
(54)
(2,408)
(543)
4,399
1,841
—
1,617
718
6,272
—
637
123
6,458
8,354
1,414
1,454
178
55
1,867
548
7
220
22,200
20,555
(13,004)
(3,102)
—
(21)
(2,101)
(695)
(10,740)
(6,780)
—
—
(1,845)
(762)
(30,758)
(18,923)
(20,127)
4
(7)
$
(4,145) $
3,270
$
26
454
NEE's primary capital requirements are for expanding and enhancing FPL's and Gulf Power's electric system and generation
facilities to continue to provide reliable service to meet customer electricity demands and for funding NEER's investments in
independent power and other projects. See Note 15 - Commitments for estimated capital expenditures in 2020 through 2024. The
following table provides a summary of the major capital investments for 2019, 2018 and 2017.
Years Ended December 31,
2019
2018
(millions)
2017
FPL:
Generation:
New
Existing
Transmission and distribution
Nuclear fuel
General and other
Other, primarily change in accrued property additions and exclusion of AFUDC - equity
Total
Gulf Power
NEER(a):
Wind
Solar
Nuclear, including nuclear fuel
Natural gas pipelines
Other gas infrastructure
Other (2019 primarily related to acquisitions, see Note 8)
Total
Corporate and Other (2019 primarily related to acquisitions, see Note 8)(a)
Total capital expenditures, independent power and other investments and nuclear fuel purchases
______________________
(a) Amounts for 2018 and 2017 were retrospectively adjusted to reflect a segment change. See Note 16.
42
$
1,242
$
976
$
1,215
2,893
195
550
(340)
5,755
729
1,974
1,741
179
687
969
955
6,505
4,473
1,142
2,456
123
334
104
5,135
—
1,198
1,285
2,151
117
431
109
5,291
—
4,093
2,824
698
233
873
893
399
7,189
680
759
220
785
681
146
5,415
34
$
17,462
$
13,004
$
10,740
Liquidity
At December 31, 2019, NEE's total net available liquidity was approximately $8.5 billion. The table below provides the components
of FPL's, Gulf Power's and NEECH's net available liquidity at December 31, 2019.
Syndicated revolving credit facilities(a)
Issued letters of credit
Bilateral revolving credit facilities
Borrowings
Letter of credit facilities(b)
Issued letters of credit
FPL
Gulf
Power
NEECH
Total
FPL
Maturity Date
Gulf Power
NEECH
(millions)
$
2,943
$
900
$
5,297
$
9,140
2020 - 2024
2024
2021 - 2024
(3)
2,940
—
900
680
—
680
—
—
—
—
—
—
—
—
—
(212)
5,085
1,075
—
1,075
900
(793)
107
(215)
8,925
1,755
2020 - 2022
2020 - 2023
—
1,755
900
(793)
107
2020 - 2021
Subtotal
3,620
900
6,267
10,787
Cash and cash equivalents
77
6
515
598
Commercial paper and other short-term borrowings
outstanding
Net available liquidity
______________________
(1,482)
(392)
(1,042)
(2,916)
$
2,215
$
514
$
5,740
$
8,469
`
(a)
Provide for the funding of loans up to the amount of the credit facility and the issuance of letters of credit up to $2,525 million ($575 million for FPL, $75 million for
Gulf Power and $1,875 million for NEECH). 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
syndicated revolving credit facilities are also available to support the purchase of $948 million of pollution control, solid waste disposal and industrial development
revenue bonds (tax exempt bonds) in the event they are tendered by individual bondholders and not remarketed prior to maturity, as well as, the repayment of
approximately $236 million of floating rate notes in the event an individual noteholder requires repayment prior to maturity. Gulf Power's syndicated revolving credit
facilities are also available to support the purchase of approximately $269 million of its tax exempt bonds in the event they are tendered by individual bondholders
and not remarketed prior to maturity. Approximately $2,314 million of FPL's and $4,109 million of NEECH's syndicated revolving credit facilities expire in 2024.
(b) Only available for the issuance of letters of credit.
At December 31, 2019, 73 banks participate in FPL’s, Gulf Power's and NEECH’s revolving credit facilities, with no one bank
providing more than 6% of the combined revolving credit facilities. European banks provide approximately 25% of the combined
revolving credit facilities. Pursuant to a 1998 guarantee agreement, NEE guarantees the payment of NEECH’s debt obligations
under its revolving credit facilities. In order for FPL, Gulf Power 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, Gulf
Power in the case of Gulf Power, 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, Gulf Power and NEECH revolving credit facilities also
contain default and related acceleration provisions relating to, among other things, failure of FPL, Gulf Power 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, 2019,
each of NEE, Gulf Power and FPL was in compliance with its required ratio.
Capital Support
Guarantees, Letters of Credit, Surety Bonds and Indemnifications (Guarantee Arrangements)
Certain subsidiaries of NEE issue guarantees and obtain letters of credit and surety bonds, as well as provide indemnities, to
facilitate commercial transactions with third parties and financings. Substantially all of the 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, 2019, 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 equity contributions
associated with natural gas pipeline projects under development and construction and a related natural gas transportation agreement.
Commitments associated with these activities are included in the contracts table in Note 15.
In addition, at December 31, 2019, NEE subsidiaries had approximately $3.6 billion in guarantees related to obligations under
purchased power agreements, nuclear-related activities, payment obligations related to PTCs, as well as other types of contractual
obligations.
43
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. At December 31, 2019, these guarantees
totaled approximately $375 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. At December 31, 2019, 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,
2019) plus contract settlement net payables, net of collateral posted for obligations under these guarantees totaled approximately
$733 million.
At December 31, 2019, subsidiaries of NEE also had approximately $1.5 billion of standby letters of credit and approximately $562
million of surety bonds to support certain of the commercial activities discussed above. FPL's and NEECH's credit facilities are
available to support the amount of the standby letters of credit.
In addition, as part of contract negotiations in the normal course of business, certain subsidiaries of NEE have agreed and in the
future may agree to make payments to compensate or indemnify other parties, including those associated with asset divestitures,
for possible 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 triggering of cash grant recapture provisions under the Recovery Act. NEE is unable to estimate 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.
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 subsidiaries within the NEER
segment.
Shelf Registration
In July 2018, 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. Securities that may be issued under the registration statement include, depending on the registrant, senior debt
securities, subordinated debt securities, junior subordinated debentures, first mortgage bonds, common stock, preferred stock,
stock purchase contracts, stock purchase units, warrants and guarantees related to certain of those securities.
44
Contractual Obligations and Estimated Capital Expenditures
NEE’s commitments at December 31, 2019 were as follows:
2020
2021
2022
2023
2024
Thereafter
Total
(millions)
Long-term debt, including interest:(a)
FPL(b)
Gulf Power(b)
NEER
Corporate and Other
Purchase obligations:
FPL(c)
Gulf Power(c)
NEER(d)
Elimination of FPL's purchase obligations to NEER(d)
Asset retirement activities:(e)
FPL(f)
Gulf Power
NEER(g)
Other commitments:(h)
FPL
Gulf Power
NEER(i)
Total
_________________________
$
1,685
$
1,082
$ 1,199
$
20,337
$
25,561
$
$
612
226
382
646
345
423
2,390
4,305
3,169
1,210
2,816
179
383
68
534
35
454
1,741
4,326
19,790
7,320
800
3,355
(108)
34
5
24
13
64
36
7,310
7,105
7,020
7,310
11,625
770
395
(105)
645
255
(102)
650
130
(99)
680
140
(97)
32
15
45
12
64
46
39
1
26
12
64
41
22
1
18
8
27
38
22
1
12
5
—
41
—
1,413
(1,314)
10,650
98
11,332
42
—
704
2,594
6,502
33,680
47,690
3,545
5,688
(1,825)
10,799
121
11,457
92
219
906
$ 15,153
$ 14,303
$ 13,502
$ 10,709
$12,618
$
80,744
$
147,029
(a)
(b)
Includes principal, interest, interest rate contracts and payments by NEE under stock purchase contracts. Variable rate interest was computed using December 31,
2019 rates. See Note 12.
Includes tax exempt bonds at FPL of approximately $9 million in 2020, $46 million in 2021, $96 million in 2022, $15 million in 2023, $146 in 2024 and $636 million
thereafter and at Gulf Power of approximately $41 million in 2022 and $228 million after 2024 that permit individual bondholders 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 and Gulf Power, as the case may be, would be required to purchase the tax exempt bonds. As of
December 31, 2019, all of FPL's and Gulf Power's tax exempt bonds tendered for purchase had been successfully remarketed. Also includes at FPL floating rate
notes of approximately $236 million maturing after 2024 that permit individual noteholders to require repayment prior to maturity. FPL’s syndicated revolving credit
facilities are available to support the purchase of tax exempt bonds and the repayment of floating rate notes. Gulf Power's syndicated revolving credit facilities are
available to support the purchase of Gulf Power's tax exempt bonds.
(c) Represents projected capital expenditures through 2024, as well as, for FPL, required minimum payments primarily under long-term fuel transportation contracts
(see Note 15 - Commitments and - Contracts).
See Note 15 - Contracts.
(d)
(e) Represents expected cash payments adjusted for inflation for estimated costs to perform asset retirement activities.
(f)
At December 31, 2019, FPL had approximately $4,697 million in restricted funds (included in NEE’s and FPL’s special use funds) for the payment of its portion of
future expenditures to decommission the Turkey Point and St. Lucie nuclear units. See Note 13.
At December 31, 2019, NEER had approximately $2,183 million in restricted funds (included in NEE’s special use funds) for the payment of its portion of future
expenditures to decommission Seabrook, Duane Arnold and Point Beach nuclear units. See Note 13.
Includes lease payment obligations. See Note 14.
Includes payments related to the acquisition of certain development rights.
(g)
(h)
(i)
45
Credit Ratings
NEE’s liquidity, ability to access credit and capital markets, cost of borrowings and collateral posting requirements under certain
agreements is dependent on its and its subsidiaries credit ratings. At February 14, 2020, Moody’s Investors Service, Inc. (Moody’s),
S&P Global Ratings (S&P) and Fitch Ratings, Inc. (Fitch) had assigned the following credit ratings to NEE, FPL and NEECH:
NEE:(b)
Corporate credit rating
FPL:(b)
Corporate credit rating
First mortgage bonds
Senior unsecured notes
Pollution control, solid waste disposal and industrial development revenue bonds(c)
Commercial paper
NEECH:(b)
Corporate credit rating
Debentures
Junior subordinated debentures
Commercial paper
_________________________
Moody's(a)
S&P(a)
Fitch(a)
Baa1
A1
Aa2
A1
VMIG-1/P-1
P-1
Baa1
Baa1
Baa2
P-2
A-
A
A+
A
A-1
A-1
A-
BBB+
BBB
A-2
A-
A
AA-
A+
F1
F1
A-
A-
BBB
F2
(a)
(b)
(c)
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.
The outlook indicated by each of Moody's, S&P and Fitch is stable.
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 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 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, Gulf Power'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. At December 31, 2019, 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.
At December 31, 2019, coverage for the 12 months ended December 31, 2019 would have been approximately 8.2 times the annual
interest requirements and approximately 3.7 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. At December 31,
2019, FPL could have issued in excess of $22 billion of additional first mortgage bonds based on the unfunded property additions
and retired first mortgage bonds. At December 31, 2019, no cash was deposited with the mortgage trustee for these purposes.
In September 2006, NEE and NEECH executed a Replacement Capital Covenant (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
46
of long-term indebtedness (covered debt) of NEECH (other than the Series B junior subordinated debentures) or, in certain cases,
of NEE. NEECH's 3.625% Debentures, Series due June 15, 2023 have been 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 365 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 (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. NEECH's 3.625% Debentures,
Series due June 15, 2023 have been 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 365 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.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
NEE’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 believes are both most important to the portrayal of its 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 considers the following policies to be the most critical in understanding the judgments that are involved in preparing its
consolidated financial statements:
Accounting for Derivatives and Hedging Activities
NEE uses derivative instruments (primarily swaps, options, futures and forwards) to manage the physical and financial risks 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 expected future debt 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 may require 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. 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
Derivative instruments, when required to be marked to market, are recorded on the balance sheet at fair value using a combination
of market and income approaches. Fair values for some of the longer-term contracts where liquid markets are not available are
derived through the use of industry-standard valuation techniques, such as 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 an income approach based on a discounted cash flows valuation technique utilizing the net
47
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 4.
In NEE’s non-rate regulated operations, predominantly NextEra Energy Resources, 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 interest rate and foreign currency derivative instruments, essentially all changes in the derivatives' fair value are recognized in
interest 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. NEE estimates the fair value of these derivatives using an income approach based
on a discounted cash flows valuation technique utilizing observable inputs.
Certain derivative 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 reflected in the non-qualifying hedge category in computing adjusted earnings 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 4, Overview and Energy Marketing and
Trading and Market Risk Sensitivity.
Accounting for Pension Benefits
NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries.
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. The qualified pension plan has a fully funded trust
dedicated to providing benefits under the plan. NEE allocates net periodic income associated with the pension plan 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 an estimate of the average remaining life of
employees/survivors as 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. NEE derives pension income from actuarial
calculations based on the plan’s provisions and various management assumptions including discount rate, rate of increase in
compensation levels and expected long-term rate of return on plan assets.
Assumptions and Accounting Approach
Accounting guidance requires recognition of the funded status of the 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 that are estimated to be allocable to FPL as net periodic (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.
48
Net periodic pension income is calculated using a number of actuarial assumptions. Those assumptions for the years ended
December 31, 2019, 2018 and 2017 include:
Discount rate
Salary increase
Expected long-term rate of return, net of investment management fees
2019
2018
2017
4.26%
4.40%
7.35%
3.59%
4.10%
7.35%
4.09%
4.10%
7.35%
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 pension
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 pension fund, as well as its pension fund's historical compounded returns. NEE believes that 7.35%
is a reasonable long-term rate of return, net of investment management fees, on its pension 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 appropriate.
NEE utilizes in its determination of pension 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 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 pension income of changing the critical actuarial assumptions discussed
above, while holding all other assumptions constant:
Expected long-term rate of return
Discount rate
Salary increase
Decrease in 2019
Net Periodic Pension Income
Change in
Assumption
NEE
FPL
(0.5)%
0.5%
0.5%
$
$
$
(millions)
(22) $
(2) $
(2) $
(14)
(1)
(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 did not have a material impact
on the pension plan's obligation.
See Note 3.
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 5 - Nonrecurring Fair Value Measurements.
49
Decommissioning and Dismantlement
NEE accounts 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.
NEE's AROs relate primarily to decommissioning obligations of FPL's and NEER's nuclear units and to obligations for the
dismantlement of certain of NEER's wind and solar facilities.
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
also makes interest rate and rate of return projections on its investments in determining recommended funding requirements for
nuclear decommissioning costs. Periodically, NEE is 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 AROs
at December 31, 2019 by approximately $254 million.
Assumptions and Accounting Approach
FPL - For ratemaking purposes, FPL accrues and funds for nuclear plant decommissioning costs over the expected service life of
each unit based on studies that are approved by the FPSC. The most recent studies, filed in 2015, reflect, among other things, the
expiration dates of the operating licenses for FPL’s nuclear units at the time of the studies. After giving effect to the recent license
extensions for Turkey Point Units Nos. 3 and 4, 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 a spent fuel settlement agreement, is estimated to be
approximately $9.7 billion, or $3.3 billion expressed in 2019 dollars. FPL intends to reflect the operating license extensions for
Turkey Point Units Nos. 3 and 4 in its next nuclear decommissioning studies.
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, 2017. At December 31, 2019, FPL’s portion of the ultimate cost to dismantle its fossil and solar units is approximately
$1.2 billion, or $510 million expressed in 2019 dollars. The majority of the dismantlement costs are not reported as 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 amount of the ARO 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
December 31,
Fossil/Solar
Dismantlement
December 31,
Interim Removal
Costs and Other
December 31,
Total
December 31,
2019
2018
2019
2018
2019
2018
2019
2018
(millions)
AROs
$
2,076
$
2,045
$
186
$
97
$
225
368
316
319
48
144
33
164
$
6
1
6
1
645
489
$
2,268
$
2,148
274
1,157
350
972
2,904
2,358
(72)
(3)
(4)
(3)
2,828
2,352
$
5,123
$
4,406
$
210
$
225
$
646
$
491
$
5,979
$
5,122
Less capitalized ARO asset net of accumulated
depreciation
Accrued asset removal costs(a)
Asset retirement obligation regulatory expense
difference(a)
Accrued decommissioning, dismantlement and
other accrued asset removal costs(b)
______________________
Included in noncurrent regulatory liabilities on NEE’s and FPL’s consolidated balance sheets. See Note 1 - Rate Regulation.
(a)
(b) Represents total amount accrued for ratemaking purposes.
NEER - NEER records liabilities for the present value of its expected nuclear plant decommissioning costs which are 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 liabilities are being accreted using the interest method through the date decommissioning
activities are expected to be complete. At December 31, 2019 and 2018, the AROs for decommissioning of NEER’s nuclear plants
approximated $623 million and $588 million, respectively. 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 $9.5 billion, or $2.0 billion expressed in 2019 dollars.
50
See Note 1 - Asset Retirement Obligations and - Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued
Asset Removal Costs and Note 13.
Regulatory Accounting
Certain of NEE's businesses are subject to rate regulation which results in the recording of regulatory assets and liabilities. See
Note 1 - Rate Regulation for a detail of NEE’s regulatory assets and liabilities.
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 they 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 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 physical and financial risks
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 4.
51
During 2018 and 2019, 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
(millions)
Gulf Power
Cost Recovery
Clauses
NEE Total
Fair value of contracts outstanding at December 31, 2017
$
442
$
728
$
— $
— $
Reclassification to realized at settlement of contracts
Value of contracts acquired
Net option premium purchases (issuances)
Impact of adoption of new revenue standard
Changes in fair value excluding reclassification to realized
Fair value of contracts outstanding at December 31, 2018
Reclassification to realized at settlement of contracts
Value of contracts acquired
Net option premium purchases (issuances)
Changes in fair value excluding reclassification to realized
Fair value of contracts outstanding at December 31, 2019
Net margin cash collateral paid (received)
Total mark-to-market energy contract net assets (liabilities) at
(159)
(3)
47
3
263
593
(215)
28
43
202
651
(28)
(2)
9
(27)
114
794
(154)
9
5
555
1,209
(6)
(15)
—
—
(20)
(41)
30
—
—
1
(10)
—
—
—
—
—
—
7
(6)
—
(2)
(1)
1,170
(193)
(20)
56
(24)
357
1,346
(332)
31
48
756
1,849
(75)
December 31, 2019
$
651
$
1,209
$
(10) $
(1) $
1,774
NEE’s total mark-to-market energy contract net assets (liabilities) at December 31, 2019 shown above are included on the
consolidated balance sheets as follows:
Current derivative assets
Noncurrent derivative assets
Current derivative liabilities
Noncurrent derivative liabilities
NEE's total mark-to-market energy contract net assets
December 31,
2019
(millions)
$
$
742
1,608
(314)
(262)
1,774
52
The sources of fair value estimates and maturity of energy contract derivative instruments at December 31, 2019 were as follows:
2020
2021
2022
2023
2024
Thereafter
Total
Maturity
Trading:
Quoted prices in active markets for identical assets
$ (191) $
Significant other observable inputs
Significant unobservable inputs
Total
Owned Assets - Non-Qualifying:
Quoted prices in active markets for identical assets
Significant other observable inputs
Significant unobservable inputs
Total
Owned Assets - FPL Cost Recovery Clauses:
Quoted prices in active markets for identical assets
Significant other observable inputs
Significant unobservable inputs
Total
Owned Assets - Gulf Power Cost Recovery Clauses:
Quoted prices in active markets for identical assets
Significant other observable inputs
Significant unobservable inputs
Total
Total sources of fair value
(millions)
$
29
$
(2) $
(32)
54
51
6
97
34
1
78
77
—
72
36
137
108
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
1
8
61
70
8
113
40
161
—
—
(1)
(1)
—
—
—
—
4
4
51
59
—
39
36
75
—
—
—
—
—
—
—
—
$
— $ (159)
(65)
335
270
—
200
295
495
—
—
—
—
—
—
—
—
(67)
877
651
23
706
480
1,209
—
(2)
(8)
(10)
—
(1)
—
(1)
17
298
124
9
185
39
233
—
(2)
(7)
(9)
—
(1)
—
(1)
$ 347
$ 230
$ 188
$ 185
$ 134
$
765
$ 1,849
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 loss of market value based on a one-day holding period at a 95% confidence level using historical simulation
methodology. The VaR figures are as follows:
Trading
Non-Qualifying Hedges
and Hedges in FPL Cost
Recovery Clauses(a)
FPL
NEER
NEE
FPL
NEER
NEE
FPL
(millions)
Total
NEER
NEE
December 31, 2018
December 31, 2019
$ — $
$ — $
Average for the year ended December 31, 2019 $ — $
______________________
5
2
3
$
$
$
5
2
3
$ — $
$ — $
$ — $
45
25
34
$
$
$
46
25
34
$ — $
$ — $
$ — $
46
26
34
$
$
$
46
26
34
(a) Non-qualifying hedges are employed to reduce the market risk exposure to physical assets or contracts which are not marked to market. The VaR figures for the
non-qualifying hedges and hedges in FPL cost recovery clauses category do not represent the economic exposure to commodity price movements.
Interest Rate Risk
NEE's and FPL'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.
53
The following are estimates of the fair value of NEE's and FPL's financial instruments that are exposed to interest rate risk:
NEE:
Fixed income securities:
Special use funds
Other investments, primarily debt securities
Long-term debt, including current portion
Interest rate contracts - net unrealized losses
FPL:
Fixed income securities - special use funds
Long-term debt, including current portion
______________________
(a)
See Note 5.
December 31, 2019
Carrying
Amount
Estimated
Fair Value(a)
December 31, 2018
Carrying
Amount
Estimated
Fair Value(a)
(millions)
2,099
181
42,928
(716)
1,574
16,448
$
$
$
$
$
$
$
$
$
$
$
$
2,099
181
39,667
$
$
$
(716) $
1,574
14,161
$
$
1,956
180
29,498
$
$
$
(416) $
1,513
11,783
$
$
1,956
180
30,043
(416)
1,513
12,613
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 - Storm Fund, Storm Reserve and Storm Cost Recovery.
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 regulatory asset or 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.
At December 31, 2019, NEE had interest rate contracts with a net notional amount of approximately $8.9 billion related to expected
future and outstanding debt issuances and borrowings, of which $9.6 billion manages exposure to the variability of cash flows
associated with expected future and outstanding debt issuances at NEECH and NEER. The offsetting $700 million of notional
amount of interest rate contracts effectively convert fixed-rate debt to variable-rate debt instruments at NEECH. See Note 4.
Based upon a hypothetical 10% decrease in interest rates, which is a reasonable near-term market change, the fair value of NEE’s
net liabilities would increase by approximately $1,797 million ($611 million for FPL) at December 31, 2019.
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 carried at their market value of approximately $3,963 million and $3,046 million
($2,491 million and $1,850 million for FPL) at December 31, 2019 and 2018, respectively. NEE's and FPL’s investment strategy for
equity securities in their nuclear decommissioning reserve funds emphasizes marketable securities which are broadly diversified.
At December 31, 2019, a hypothetical 10% decrease in the prices quoted on stock exchanges, which is a reasonable near-term
market change, would result in a $370 million ($236 million for FPL) reduction in fair value. For FPL, a corresponding adjustment
would be made to the related regulatory asset or liability accounts based on current regulatory treatment, and for NEE’s non-rate
regulated operations, a corresponding amount would be recorded in change in unrealized gains (losses) on equity securities held
in NEER's nuclear decommissioning funds - net in NEE's consolidated statements of income.
Credit Risk
NEE and its subsidiaries, including FPL, 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 include 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.
54
•
•
•
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 noncash 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. At December 31, 2019, approximately 87% of NEE’s and 99% of
FPL's energy marketing and trading counterparty credit risk exposure is associated with companies that have investment grade
credit ratings.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
See Management’s Discussion – Energy Marketing and Trading and Market Risk Sensitivity.
55
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, 2019, using the
criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in the Internal Control - Integrated Framework
(2013). Based on this assessment, management believes that NEE's and FPL's internal control over financial reporting was effective as
of December 31, 2019.
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
REBECCA J. KUJAWA
James L. Robo
Chairman, President and Chief Executive Officer of NEE and
Chairman of FPL
Rebecca J. Kujawa
Executive Vice President, Finance and Chief Financial
Officer of NEE and FPL
JAMES M. MAY
James M. May
Vice President, Controller and Chief Accounting Officer
of NEE
ERIC E. SILAGY
Eric E. Silagy
President and Chief Executive Officer of FPL
KEITH FERGUSON
Keith Ferguson
Controller of FPL
56
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the shareholders and the Board of Directors of
NextEra Energy, Inc. and Florida Power & Light Company
Opinion on Internal Control over Financial Reporting
We have audited the internal control over financial reporting of NextEra Energy, Inc. and subsidiaries (NEE) and Florida Power &
Light Company and subsidiaries (FPL) as of December 31, 2019, based on criteria established in Internal Control — Integrated
Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion,
NEE and FPL maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019, based
on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States)
(PCAOB), the consolidated financial statements as of and for the year ended December 31, 2019 of NEE and FPL and our report
dated February 14, 2020, expressed unqualified opinions on those financial statements.
Basis for Opinion
NEE'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 opinions on NEE’s and FPL’s internal control over
financial reporting based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent
with respect to NEE and FPL in accordance with the U.S. federal securities laws and the applicable rules and regulations of the
Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. 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 opinions.
Definition and Limitations of Internal Control over Financial Reporting
A company's internal control over financial reporting is a process designed 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 its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections
of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes
in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
DELOITTE & TOUCHE LLP
Boca Raton, Florida
February 14, 2020
57
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the shareholders and the Board of Directors of
NextEra Energy, Inc. and Florida Power & Light Company
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of NextEra Energy, Inc. and subsidiaries (NEE) and the related
separate consolidated balance sheets of Florida Power & Light Company and subsidiaries (FPL) as of December 31, 2019 and
2018, and NEE's and FPL's related consolidated statements of income and of cash flows, NEE's consolidated statements of
comprehensive income and of equity, and FPL’s consolidated statements of common shareholder’s equity, for each of the three
years in the period ended December 31, 2019, and the related notes (collectively referred to as the "financial statements"). In our
opinion, the financial statements present fairly, in all material respects, the consolidated financial position of NEE and the consolidated
financial position of FPL as of December 31, 2019 and 2018, and the results of their operations and their cash flows for each of the
three years in the period ended December 31, 2019, 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)
(PCAOB), NEE’s and FPL’s internal control over financial reporting as of December 31, 2019, based on criteria established in
Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission
and our report dated February 14, 2020, expressed unqualified opinions on NEE’s and FPL’s internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of NEE’s and FPL’s management. Our responsibility is to express opinions on
NEE’s and FPL’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are
required to be independent with respect to NEE and FPL in accordance with the U.S. federal securities laws and the applicable
rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the
audits to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to
error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements,
whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a
test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the
accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the
financial statements. We believe that our audits provide a reasonable basis for our opinions.
Critical Audit Matter - NEE
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements of NEE
that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that
are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The
communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we
are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts
or disclosures to which it relates.
NEE - Operating Revenue - Unrealized Gains - Refer to Note 5 to the financial statements
Critical Audit Matter Description
NEE enters into complex energy derivatives and transacts in certain markets that are thinly traded, which may result in subjective
estimates of fair value that include unobservable inputs. Changes in the derivatives’ fair value for power purchases and sales, fuel
sales and trading activities are primarily recognized on a net basis in operating revenues. For the year ended December 31, 2019,
unrealized gains associated with Level 3 transactions of $638 million are included in operating revenues in the consolidated statement
of income of NEE.
Given management uses complex proprietary models and unobservable inputs to estimate the fair value of Level 3 derivative assets
and liabilities, performing audit procedures to evaluate the appropriateness of these models and inputs required a high degree of
auditor judgment and an increased extent of effort, including the need to involve our firm specialists who possess significant
quantitative and modeling expertise.
58
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to operating revenue - unrealized gains included the following, among others:
• We tested the effectiveness of controls, including those relating to commodity valuation models, and market data validation.
• We selected a sample of transactions, obtained an understanding of the business rationale of transactions and read the
underlying contractual agreements.
• We used personnel in our firm who specialize in energy transacting to assist in auditing NEE’s energy transactions, including
testing certain inputs in managements fair value models.
• We used personnel in our firm who specialize in the valuation of energy products to independently value Level 3 transactions
to provide us with a benchmark for comparison to NEE valuations.
DELOITTE & TOUCHE LLP
Boca Raton, Florida
February 14, 2020
We have served as NEE’s and FPL’s auditor since 1950.
59
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF INCOME
(millions, except per share amounts)
OPERATING REVENUES
OPERATING EXPENSES (INCOME)
Fuel, purchased power and interchange
Other operations and maintenance
Storm restoration costs
Impairment charges
Acquisition-related
Depreciation and amortization
Gains on disposal of businesses/assets - net
Taxes other than income taxes and other - net
Total operating expenses - net
OPERATING INCOME
OTHER INCOME (DEDUCTIONS)
Interest expense
Benefits associated with differential membership interests - net
Equity in earnings of equity method investees
Allowance for equity funds used during construction
Interest income
Gain on NEP deconsolidation
Gains on disposal of investments and other property - net
Change in unrealized gains (losses) on equity securities held in NEER's nuclear
decommissioning funds - net
Other net periodic benefit income
Other - net
Total other income (deductions) - net
INCOME BEFORE INCOME TAXES
INCOME TAX EXPENSE (BENEFIT)
NET INCOME
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS
NET INCOME ATTRIBUTABLE TO NEE
Earnings per share attributable to NEE:
Basic
Assuming dilution
Years Ended December 31,
2019
2018
2017
$ 19,204 $ 16,727 $ 17,173
4,363
3,640
234
72
35
4,216
(406)
1,697
13,851
5,353
3,732
3,330
3
11
32
3,911
(80)
1,508
12,447
4,280
4,071
3,458
1,255
446
69
2,357
(1,111)
1,455
12,000
5,173
(2,249)
(1,498)
(1,558)
—
66
67
54
—
55
238
185
67
(1,517)
3,836
448
3,388
381
—
358
96
51
3,927
111
(189)
168
48
3,072
7,352
1,576
5,776
862
460
141
92
81
—
112
—
151
11
(510)
4,663
(660)
5,323
57
$
$
$
3,769 $
6,638 $
5,380
7.82 $
14.03 $
7.76 $
13.88 $
11.48
11.39
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
60
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(millions)
NET INCOME
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX
Reclassification of unrealized losses on cash flow hedges from accumulated
other comprehensive income (loss) to net income (net of $8, $8 and $13 tax
expense, respectively)
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains (losses) on securities still held (net of $8 tax expense, $5
tax benefit and $94 tax expense, respectively)
Reclassification from accumulated other comprehensive income (loss) to net
income (net of $1, less than $1 and $25 tax benefit, respectively)
Defined benefit pension and other benefits plans:
Net unrealized gain (loss) and unrecognized prior service benefit (cost) (net of
$14 and $5 tax benefit and $29 tax expense, respectively)
Reclassification from accumulated other comprehensive income (loss) to net
income (net of $1, $1 and $1 tax benefit, respectively)
Net unrealized gains (losses) on foreign currency translation (net of $0, $0 and $1
tax expense, respectively)
Other comprehensive income related to equity method investees (net of $0, $1 and
$1 tax expense, respectively)
Total other comprehensive income (loss), net of tax
IMPACT OF NEP DECONSOLIDATION (NET OF $15 TAX EXPENSE)
COMPREHENSIVE INCOME
COMPREHENSIVE LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS
Years Ended December 31,
2019
2018
2017
$
3,388
$
5,776
$
5,323
29
26
32
20
(2)
(46)
(3)
22
1
21
—
(12)
1
(14)
(3)
(31)
4
(29)
58
3,409
380
5,805
862
127
(36)
46
(2)
23
2
192
—
5,515
46
COMPREHENSIVE INCOME ATTRIBUTABLE TO NEE
$
3,789
$
6,667
$
5,561
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
61
NEXTERA ENERGY, INC.
CONSOLIDATED BALANCE SHEETS
(millions, except par value)
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property
Nuclear fuel
Construction work in progress
Accumulated depreciation and amortization
Total property, plant and equipment - net ($11,893 and $10,553 related to VIEs, respectively)
CURRENT ASSETS
Cash and cash equivalents
Customer receivables, net of allowances of $19 and $10, respectively
Other receivables
Materials, supplies and fossil fuel inventory
Regulatory assets ($41 related to a VIE at December 31, 2018)
Derivatives
Other
Total current assets
OTHER ASSETS
Special use funds
Investment in equity method investees
Prepaid benefit costs
Regulatory assets
Derivatives
Goodwill
Other
Total other assets
TOTAL ASSETS
CAPITALIZATION
Common stock ($0.01 par value, authorized shares - 800; outstanding shares - 489 and 478, respectively)
Additional paid-in capital
Retained earnings
Accumulated other comprehensive loss
Total common shareholders' equity
Noncontrolling interests ($4,350 and $3,265 related to VIEs, respectively)
Total equity
Redeemable noncontrolling interests
Long-term debt ($498 and $1,020 related to VIEs, respectively)
Total capitalization
CURRENT LIABILITIES
Commercial paper
Other short-term debt
Current portion of long-term debt ($27 and $74 related to VIEs, respectively)
Accounts payable
Customer deposits
Accrued interest and taxes
Derivatives
Accrued construction-related expenditures
Regulatory liabilities
Other
Total current liabilities
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations
Deferred income taxes
Regulatory liabilities
Derivatives
Other
Total other liabilities and deferred credits
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES
$
$
$
December 31,
2019
2018
$
96,093
1,755
9,330
(25,168)
82,010
81,986
1,740
8,357
(21,749)
70,334
$
$
600
2,282
525
1,328
335
762
1,576
7,408
6,954
7,453
1,437
3,287
1,624
4,204
3,314
28,273
117,691
5
11,970
25,199
(169)
37,005
4,355
41,360
487
37,543
79,390
2,516
400
2,124
3,631
499
558
344
1,152
320
2,309
13,853
3,457
8,361
9,936
863
1,831
24,448
638
2,302
667
1,223
448
564
551
6,393
5,886
6,748
1,284
3,290
1,355
891
7,521
26,975
103,702
5
10,490
23,837
(188)
34,144
3,269
37,413
468
26,782
64,663
2,749
5,465
2,716
2,386
445
477
675
1,195
325
1,130
17,563
3,135
7,367
9,009
516
1,449
21,476
$
117,691
$
103,702
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
62
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(millions)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
$
3,388
$
5,776
$
5,323
Years Ended December 31,
2019
2018
2017
Depreciation and amortization
Nuclear fuel and other amortization
Impairment charges
Unrealized losses (gains) on marked to market derivative contracts – net
Foreign currency transaction losses (gains)
Deferred income taxes
Cost recovery clauses and franchise fees
Acquisition of purchased power agreement
Benefits associated with differential membership interests - net
Equity in earnings of equity method investees
Distributions of earnings from equity method investees
Gains on disposal of businesses, assets and investments – net
Gain on NEP deconsolidation
Recoverable storm-related costs
Other - net
Changes in operating assets and liabilities:
Current assets
Noncurrent assets
Current liabilities
Noncurrent liabilities
Net cash provided by operating activities
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL
Acquisition and capital expenditures of Gulf Power
Independent power and other investments of NEER
Nuclear fuel purchases
Other capital expenditures, acquisitions and other investments
Proceeds from sale of the fiber-optic telecommunications business
Sale of independent power and other investments of NEER
Proceeds from sale or maturity of securities in special use funds and other investments
Purchases of securities in special use funds and other investments
Distributions from equity method investees
Other - net
Net cash used in investing activities
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt
Retirements of long-term debt
Proceeds from differential membership investors
Net change in commercial paper
Proceeds from other short-term debt
Repayments of other short-term debt
Payments to related parties under a cash sweep and credit support agreement – net
Issuances of common stock - net
Proceeds from issuance of NEP convertible preferred units - net
Dividends on common stock
Other - net
Net cash provided by financing activities
Effects of currency translation on cash, cash equivalents and restricted cash
Net increase (decrease) in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash at beginning of year
Cash, cash equivalents and restricted cash at end of year
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)
Cash paid for income taxes - net
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions
Increase in property, plant and equipment - net as a result of cash grants primarily under the
American Recovery and Reinvestment Act of 2009
Increase in property, plant and equipment - net as a result of a settlement/noncash exchange
$
$
$
$
$
$
4,216
262
72
(108)
17
258
155
—
—
(66)
438
(461)
—
(180)
(213)
123
(93)
116
231
8,155
(5,560)
(5,165)
(6,385)
(315)
(37)
—
1,163
4,008
(4,160)
—
274
(16,177)
13,919
(5,492)
1,604
(234)
200
(4,765)
(54)
1,494
—
(2,408)
(391)
3,873
4
(4,145)
5,253
1,108
1,799
184
3,573
$
$
$
$
3,911
236
11
54
16
1,463
(225)
(52)
—
(358)
328
(191)
(3,927)
—
156
(631)
(220)
163
83
6,593
(5,012)
—
(7,045)
(267)
(680)
—
1,617
3,410
(3,733)
637
123
(10,950)
4,399
(3,102)
1,841
1,062
5,665
(455)
(21)
718
—
(2,101)
(372)
7,634
(7)
3,270
1,983
5,253
1,209
200
2,138
$
$
$
$
— $
(7) $
— $
(5) $
2,357
281
446
436
(25)
(882)
82
(243)
(460)
(141)
160
(1,223)
—
(108)
109
(333)
(60)
758
(19)
6,458
(5,174)
—
(5,335)
(197)
(34)
1,454
178
3,207
(3,244)
7
220
(8,918)
8,354
(6,780)
1,414
1,419
450
(2)
—
55
548
(1,845)
(725)
2,888
26
454
1,529
1,983
1,186
142
3,029
(154)
(108)
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
63
NEXTERA ENERGY, INC.
CONSOLIDATED STATEMENTS OF EQUITY
(millions)
Common Stock
Shares
Aggregate
Par Value
Additional
Paid-In
Capital
Accumulated
Other
Comprehensive
Income (Loss)
Retained
Earnings
Total
Common
Shareholders'
Equity
Non-
controlling
Interests
Total
Equity
Balances, December 31, 2016
Net income (loss)
$
468
—
Issuances of common stock - net
Share-based payment activity
Dividends on common stock(a)
Other comprehensive income
Sale of NEER assets to NEP
Other
Balances, December 31, 2017
Net income (loss)
Issuances of common stock - net
Share-based payment activity
Dividends on common stock(a)
Other comprehensive loss
Impact of NEP deconsolidation(b)
Sales of differential membership interests
to NEP
Adoption of accounting standards
updates
Other differential membership interests
activity
Other
Balances, December 31, 2018
Net income (loss)
Issuances of common stock - net
Share-based payment activity
Dividends on common stock(a)
Other comprehensive income
Premium on equity units
Other differential membership interests
activity
Other
2
1
—
—
—
—
471
—
6
1
—
—
—
—
—
—
—
478
—
10
1
—
—
—
—
—
Balances, December 31, 2019
489
$
___________________________
5
—
—
—
—
—
—
—
5
—
—
—
—
—
—
—
—
—
—
5
—
—
—
—
—
—
—
—
5
$
8,948
$
(70) $
15,484
$
24,367
$
991
$ 25,358
—
33
122
—
—
—
(3)
9,100
—
700
121
—
—
—
—
590
(21)
—
10,490
—
1,470
164
—
—
(120)
(20)
(14)
—
—
—
—
181
—
—
111
—
—
—
—
(29)
58
—
5,380
—
—
(1,845)
—
—
1
19,020
6,638
—
—
5,380
33
122
(1,845)
181
—
(2)
28,236
6,638
700
121
(2,101)
(2,101)
—
—
—
(29)
58
—
(57)
—
—
—
11
460
(110)
1,295
$ 29,531
(862)
—
—
—
—
(2,700)
(941)
(328)
280
542
5,303
—
—
(188)
—
—
—
—
20
—
—
(1)
—
—
23,837
3,769
—
—
(2,408)
—
—
—
1
(21)
—
1,243
(69)
34,144
3,269
$ 37,413
3,769
1,470
164
(2,408)
20
(120)
(371)
—
—
—
1
(20)
(14)
1,270
186
$ 11,970
$
(169) $
25,199
$
37,005
$
4,355
$ 41,360
(a) Dividends per share were $5.00, $4.44 and $3.93 for the years ended December 31, 2019, 2018 and 2017, respectively.
(b)
See Note 1 - NextEra Energy Partners, LP.
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
64
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(millions)
OPERATING REVENUES
OPERATING EXPENSES (INCOME)
Fuel, purchased power and interchange
Other operations and maintenance
Storm restoration costs
Depreciation and amortization
Taxes other than income taxes and other - net
Total operating expenses - net
OPERATING INCOME
OTHER INCOME (DEDUCTIONS)
Interest expense
Allowance for equity funds used during construction
Other - net
Total other deductions - net
INCOME BEFORE INCOME TAXES
INCOME TAXES
NET INCOME(a)
______________________
(a)
FPL's comprehensive income is the same as reported net income.
Years Ended December 31,
2019
2018
2017
$
12,192 $
11,862 $
11,972
3,256
1,519
234
2,524
1,357
8,890
3,302
(594)
62
5
(527)
2,775
441
3,250
1,514
3
2,633
1,308
8,708
3,154
(541)
90
7
(444)
2,710
539
$
2,334 $
2,171 $
3,541
1,554
1,255
940
1,292
8,582
3,390
(481)
79
(2)
(404)
2,986
1,106
1,880
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
65
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED BALANCE SHEETS
(millions, except share amount)
ELECTRIC UTILITY PLANT AND OTHER PROPERTY
Plant in service and other property
Nuclear fuel
Construction work in progress
Accumulated depreciation and amortization
Total electric utility plant and other property - net
CURRENT ASSETS
Cash and cash equivalents
Customer receivables, net of allowances of $3 and $3, respectively
Other receivables
Materials, supplies and fossil fuel inventory
Regulatory assets ($41 related to a VIE at December 31, 2018)
Other
Total current assets
OTHER ASSETS
Special use funds
Prepaid benefit costs
Regulatory assets
Goodwill
Other
Total other assets
TOTAL ASSETS
CAPITALIZATION
Common stock (no par value, 1,000 shares authorized, issued and outstanding)
Additional paid-in capital
Retained earnings
Total common shareholder's equity
Long-term debt
Total capitalization
CURRENT LIABILITIES
Commercial paper
Current portion of long-term debt ($74 related to a VIE at December 31, 2018)
Accounts payable
Customer deposits
Accrued interest and taxes
Accrued construction-related expenditures
Regulatory liabilities
Other
Total current liabilities
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations
Deferred income taxes
Regulatory liabilities
Other
Total other liabilities and deferred credits
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES
December 31,
2019
2018
$
54,523
$
1,153
3,351
(13,953)
45,074
77
1,024
333
722
227
136
2,519
4,771
1,477
2,549
300
498
9,595
57,188
1,373
10,851
9,174
21,398
14,131
35,529
$
$
$
$
49,640
1,189
3,888
(13,218)
41,499
112
1,026
284
670
447
239
2,778
4,056
1,407
2,843
302
599
9,207
53,484
1,373
10,601
9,040
21,014
11,688
32,702
1,482
1,256
30
768
459
266
426
284
510
95
731
442
376
323
310
543
4,225
4,076
2,268
5,415
9,296
455
17,434
2,147
5,165
8,886
508
16,706
$
57,188
$
53,484
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
66
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(millions)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income
Adjustments to reconcile net income to net cash provided by (used in) operating
Years Ended December 31,
2019
2018
2017
$
2,334
$
2,171
$
1,880
activities:
Depreciation and amortization
Nuclear fuel and other amortization
Deferred income taxes
Cost recovery clauses and franchise fees
Acquisition of purchased power agreement
Recoverable storm-related costs
Other - net
Changes in operating assets and liabilities:
Current assets
Noncurrent assets
Current liabilities
Noncurrent liabilities
Net cash provided by operating activities
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures
Nuclear fuel purchases
Proceeds from sale or maturity of securities in special use funds
Purchases of securities in special use funds
Other - net
Net cash used in investing activities
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt
Retirements of long-term debt
Net change in commercial paper
Proceeds from other short-term debt
Repayments of other short-term debt
Capital contributions from NEE
Dividends to NEE
Other - net
Net cash provided by financing activities
Net increase (decrease) in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash at beginning of year
Cash, cash equivalents and restricted cash at end of year
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)
Cash paid for income taxes - net
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING
ACTIVITIES
Accrued property additions
Increase in electric utility plant and other property - net as a result of a noncash
exchange
NEE's noncash contribution of a consolidated subsidiary - net
$
$
$
$
$
$
2,524
175
44
177
—
—
6
(48)
(67)
32
4
5,181
(5,560)
(195)
2,729
(2,854)
10
(5,870)
2,498
(95)
226
—
—
250
(2,200)
(49)
630
(59)
254
195
561
544
$
$
$
2,633
144
180
(225)
(52)
—
7
97
(64)
(509)
40
4,422
(5,012)
(123)
2,232
(2,402)
239
(5,066)
1,748
(1,591)
(431)
—
(250)
1,785
(500)
(37)
724
80
174
254
520
415
$
$
$
680
$
549
$
(7) $
— $
(5) $
526
$
940
159
905
82
(243)
(108)
(139)
(190)
(37)
699
(32)
3,916
(5,174)
(117)
1,986
(2,082)
18
(5,369)
1,961
(882)
1,419
450
(2)
—
(1,450)
(22)
1,474
21
153
174
473
2
668
(112)
—
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
67
FLORIDA POWER & LIGHT COMPANY
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY
(millions)
Common
Stock
Additional
Paid-In
Capital
Retained
Earnings
Common
Shareholder's
Equity
Balances, December 31, 2016
$
1,373 $
8,332 $
6,875 $
16,580
Net income
Dividends to NEE
Other
Balances, December 31, 2017
Net income
Capital contributions from NEE
Dividends to NEE
NEE's contribution of a consolidated subsidiary
Other
Balances, December 31, 2018
Net income
Capital contributions from NEE
Dividends to NEE
Balances, December 31, 2019
—
—
—
1,373
—
—
—
—
—
—
—
(41)
8,291
—
1,785
—
526
(1)
1,880
(1,450)
71
7,376 $
17,040
2,171
—
(500)
—
(7)
1,373
10,601
9,040 $
21,014
—
—
—
—
250
—
2,334
—
(2,200)
$
1,373 $
10,851 $
9,174 $
21,398
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
68
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Years Ended December 31, 2019, 2018 and 2017
1. Summary of Significant Accounting and Reporting Policies
Basis of Presentation - The operations of NextEra Energy, Inc. (NEE) are conducted primarily through Florida Power & Light Company
(FPL), a wholly owned subsidiary, and NextEra Energy Resources, LLC (NextEra Energy Resources) and NextEra Energy
Transmission, LLC (NEET) (collectively, NEER), wholly owned indirect subsidiaries that are combined for segment reporting
purposes. FPL's principal business is a rate-regulated electric utility which supplies electric service to more than five 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 noncontrolling ownership interests in joint ventures. NEER participates in natural gas,
natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure
through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission
facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated
entities. See Note 16 for a discussion of the movement of NEET to the NEER segment from Corporate and Other.
The consolidated financial statements of NEE and FPL include the accounts of their respective controlled subsidiaries. They also
include NEE's and FPL's share of the undivided interest in certain assets, liabilities, revenues and expenses. Amounts representing
NEE's interest in entities it does not control, but over which it exercises significant influence, are included in investment in equity
method investees; the net income of these entities is included in equity in earnings of equity method investees. 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 - NEP was formed in 2014 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). NEP owns or has
an interest in a portfolio of wind and solar projects and long-term contracted natural gas pipelines. NEP was deconsolidated from
NEE for financial reporting purposes in January 2018 as a result of changes made to NEP's governance structure during 2017 that,
among other things, enhanced NEP common unitholder governance rights. The new governance structure established a NEP board
of directors whereby NEP unitholders have the ability to nominate and elect board members, subject to certain limitations and
requirements, which elected board members commenced service in January 2018. Subsequent to deconsolidation, NEE owns a
noncontrolling interest in NEP and began reflecting its ownership interest in NEP as an equity method investment with its earnings/
losses from NEP as equity in earnings (losses) of equity method investees and accounting for NextEra Energy Resources' asset
sales to NEP as third-party sales in its consolidated financial statements. NEER continues to operate the projects owned by NEP
and provide services to NEP under various related party operations and maintenance, administrative and management services
agreements.
In connection with the deconsolidation, NEE recorded an initial investment in NEP of approximately $4.4 billion based on the fair
value of NEP OpCo and NEP common units that were held by subsidiaries of NEE on the deconsolidation date, which investment
is included in the investment in equity method investees on NEE's consolidated balance sheets. See Note 10. The fair value was
based on the market price of NEP common units as of January 1, 2018, which resulted in NEE recording a gain of approximately
$3.9 billion ($3.0 billion after tax) for the year ended December 31, 2018.
Prior to the deconsolidation, NEE owned a controlling general partner interest in NEP and consolidated NEP for financial reporting
purposes. NEE presented its limited partner interests in NEP as a noncontrolling interest in NEE's consolidated financial statements.
NEE’s partnership interest in NEP OpCo's operating projects based on the number of outstanding NEP OpCo common units was
approximately 65.1% at December 31, 2017. Certain equity and asset transactions between NEP, NEER and NEP OpCo involve
the exchange of cash, energy projects and ownership interests in NEP OpCo.
Operating Revenues - FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues
from contracts with customers as further discussed in Note 2, as well as, at NEER, derivative and lease transactions. FPL's operating
revenues include amounts resulting from base rates, cost recovery clauses (see Rate Regulation below), franchise fees, gross
receipts taxes and surcharges related to storms (see Storm Fund, Storm Reserve and Storm Cost Recovery below). Franchise fees
and gross receipts taxes are imposed on FPL; however, the Florida Public Service Commission (FPSC) allows FPL to include in
the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise fee for those customers
located in the jurisdiction that imposes the 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 $763 million, $738 million and $767 million in 2019, 2018 and 2017, 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.
Certain NEER 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 4.
69
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Rate Regulation - FPL, the most significant of NEE's rate-regulated subsidiaries, is subject to rate regulation by the FPSC and the
Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing 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.
NEE's and FPL's regulatory assets and liabilities are as follows:
Regulatory assets:
Current:
Acquisition of purchased power agreements
Deferred clause and franchise expenses
Other
Total
Noncurrent:
Acquisition of purchased power agreements
Other
Total
Regulatory liabilities:
Current:
Deferred clause revenues
Other
Total
Noncurrent:
Asset retirement obligation regulatory expense difference
Accrued asset removal costs
Deferred taxes
Other
Total
NEE
December 31,
FPL
December 31,
2019
2018
2019
2018
(millions)
$
$
$
165
146
137
448
798
2,492
165
$
5
57
227
634
1,915
$
$
165
$
5
165
335
634
2,653
$
$
3,287
$
3,290
$
2,549
$
$
$
$
309
11
320
2,826
1,346
4,862
902
$
$
$
265
60
325
2,352
991
4,815
851
$
$
$
284
—
284
2,828
1,157
4,397
914
9,936
$
9,009
$
9,296
$
$
$
$
$
$
$
$
$
165
146
136
447
798
2,045
2,843
265
45
310
2,352
972
4,736
826
8,886
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 various clauses, include substantially all fuel, purchased power and interchange expense, certain costs
associated with the acquisition of several electric generation facilities, certain construction-related costs for certain of FPL's solar
generation 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.
At December 31, 2019 and 2018, FPL had regulatory assets, net of amortization, of approximately $799 million and $963 million,
respectively, (included in current and noncurrent regulatory assets on NEE's and FPL’s consolidated balance sheets) related to
acquisitions during 2015, 2017 and 2018 associated with three coal-fired electric generation facilities located in Florida with which
FPL had long-term purchased power agreements. The majority of these regulatory assets are being amortized over approximately
nine years. Two of the three facilities have been retired and FPL has reduced the third facility’s operations with the intention of
phasing the facility out of service.
In 2018, FPL early retired three of its generation facilities. As a result of the retirements, FPL reclassified the net book value of these
units (approximately $875 million) from plant in service and other property to current and noncurrent regulatory assets. Recovery
of $729 million of these regulatory assets has been deferred until FPL’s base rates are next reset in a general base rate
proceeding. The remainder of these regulatory assets are being amortized over 15 years. At December 31, 2019 and 2018, the
regulatory assets, net of amortization, totaled approximately $851 million and $870 million, respectively, and are included in current
and noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. Additionally, other regulatory assets and
liabilities are discussed within various subsections in Note 1 below.
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
70
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
that it considers excessive or imprudently incurred. The continued applicability of regulatory accounting is assessed at each reporting
period.
FPL Base Rates Effective January 2017 through at least 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 beginning April 1, 2019 for a new approximately 1,720 megawatts (MW) natural gas-fired combined-
cycle unit in Okeechobee County, Florida that achieved commercial operation on March 31, 2019.
In addition, FPL is eligible to receive base rate increases associated with the addition of up to 300 MW annually of new solar
generation in each of 2017 through 2020 with an installed cost cap of $1,750 per kilowatt (kW). Approximately 900 MW of new
solar generating capacity has become operational, 600 MW in the first quarter of 2018 and 300 MW in the first quarter of 2019.
An additional 300 MW is expected to be operational in the second quarter of 2020.
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 retail base rates.
Subject to certain conditions, FPL may amortize, over the term of the 2016 rate agreement, up to $1.0 billion of depreciation
reserve surplus plus the reserve amount that remained under FPL's previous rate agreement (approximately $250 million),
provided that in any year of the 2016 rate agreement FPL must amortize at least enough reserve to maintain a 9.60% earned
regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 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 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 million in any given calendar year, FPL may request an increase to
the $4 surcharge to recover amounts above $400 million. See Storm Fund, Storm Reserve and Storm Cost Recovery below.
Electric Plant, Depreciation and Amortization - The cost of additions to units of property of FPL and NEER is added to electric plant
in service and other property. 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, 2019, the electric generation, transmission, distribution and general facilities of FPL represented
approximately 46%, 12%, 35% and 7%, 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 generation, regulated transmission and pipeline facilities are encumbered by liens securing various financings.
The net book value of NEER's assets serving as collateral was approximately $10.0 billion at December 31, 2019. 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, 2019 and 2018, convertible
ITCs, net of amortization, were approximately $824 million ($128 million at FPL) and $1.2 billion ($134 million at FPL). At December 31,
2019 and 2018, approximately $10 million and $138 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
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 every four years. As part of the 2016 rate agreement, the FPSC approved new depreciation rates which became effective
January 1, 2017. In accordance with the 2016 rate agreement discussed in Rate Regulation above, FPL recorded reserve amortization
(reversal) of approximately $(357) million, $(541) million and $1,250 million in 2019, 2018 and 2017, respectively. Reserve
amortization is recorded as a reduction to (or when 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. In 2017, FPL used available reserve amortization
to offset nearly all of the Hurricane Irma storm restoration costs that were expensed, and FPL is partially restoring the reserve
amortization through tax savings generated during the term of the 2016 rate agreement. See Note 6. In 2019, FPL used available
reserve amortization resulting from operational efficiencies generated at the business to offset all of the Hurricane Dorian storm
restoration costs that were expensed. See Storm Fund, Storm Reserve and Storm Restoration Costs below. The weighted annual
composite depreciation and amortization rate for FPL's electric utility plant in service, including capitalized software, but excluding
71
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
the effects of decommissioning, dismantlement and the depreciation adjustments discussed above, was approximately 3.9%, 3.8%
and 3.7% for 2019, 2018 and 2017, respectively. FPL files a twelve-month forecast 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 2016
rate 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.
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, 2019, wind, solar and nuclear plants represented approximately 54%, 12% and 10%, respectively, of
NEER's depreciable electric plant in service and other property; the respective amounts at December 31, 2018 were 53%, 14%
and 10%. The estimated useful lives of NEER's plants range primarily from 25 to 35 years for wind plants, 25 to 30 years for solar
plants and 23 to 47 years for nuclear plants (see Note 5 - Nonrecurring Fair Value Measurements). NEER reviews the estimated
useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets, representing approximately 15% and
13%, respectively, of NEER's depreciable electric plant in service and other property at December 31, 2019 and 2018, are accounted
for under the successful efforts method. Depletion expenses for the acquisition of reserve rights and development costs are
recognized using the unit of production method.
Nuclear Fuel - FPL and NEER have several contracts for the supply of uranium and the conversion, enrichment and fabrication of
nuclear fuel. See Note 15 - 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 noncash item which represents the allowed cost
of capital, including an ROE, used to finance construction projects. FPL records the portion of AFUDC attributable to borrowed funds
as a reduction of interest expense and the remainder as other income. 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 2019, 2018 and 2017, FPL capitalized
AFUDC at a rate of 6.22%, 5.97% and 6.16%, respectively, which amounted to approximately $80 million, $114 million and $101
million, respectively. See Note 15 - 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.
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, 2019 and 2018, NEER's capitalized development costs totaled
approximately $651 million and $630 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 will be realized.
NEER's construction work in progress includes construction materials, progress payments on major 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 $135 million, $94 million and $89 million during
2019, 2018 and 2017, respectively. Interest expense allocated from NextEra Energy Capital Holdings, Inc. (NEECH) to NEER is
based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources'
subsidiaries. Upon commencement of project operation, costs associated with construction work in progress are transferred to
electric plant in service and other property. In September 2019, NEER determined it was no longer moving forward with the
construction of a 220 MW wind facility due to unresolved permitting issues. NEE recorded charges of approximately $72 million
($54 million after tax), which are included in impairment charges in NEE’s consolidated statements of income for the year ended
December 31, 2019, primarily related to the write-off of capitalized construction costs.
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. NEE's AROs relate primarily to decommissioning obligations of FPL's and
NEER's nuclear units and to obligations for the dismantlement of certain of NEER's wind and solar facilities. See Decommissioning
of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 13.
72
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
For NEE's rate-regulated operations, including FPL, the asset retirement cost is subsequently allocated to a regulatory liability 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 ARO and a decrease in the regulatory liability. 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 ARO and
asset retirement cost.
For NEE's non-rate regulated operations, the asset retirement cost is subsequently allocated to expense using a systematic and
rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as
an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization
expense in NEE's consolidated statements of income. Changes resulting from revisions to the timing or amount of the original
estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement
cost is depleted.
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. 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 Rate Regulation, Electric Plant, Depreciation and Amortization, and Asset Retirement Obligations
above and Note 13.
Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed
updated nuclear decommissioning studies with the FPSC in December 2015. These studies reflect, among other things, the expiration
dates of the operating licenses for FPL's nuclear units at the time of the studies. The 2015 studies provide for the 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 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 United States (U.S.) government facility. After giving effect to the license extensions for Turkey Point
Units Nos. 3 and 4, FPL's portion of the ultimate costs of decommissioning its four nuclear units, including costs associated with
spent fuel storage above what is expected to be refunded by the U.S. Department of Energy (DOE) under a spent fuel settlement
agreement, is estimated to be approximately $9.7 billion, or $3.3 billion expressed in 2019 dollars. FPL intends to reflect the operating
license extensions for Turkey Point Units Nos. 3 and 4 in its next nuclear decommissioning studies.
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 carried at fair value. See Note 5. 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 asset or liability
accounts. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of fund earnings.
During 2019, 2018 and 2017 fund earnings on decommissioning funds were approximately $125 million, $94 million and $114
million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in 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. As part of the 2016 rate agreement, the FPSC approved an annual expense of $26 million based on FPL's 2016 fossil
and solar dismantlement studies, which became effective January 1, 2017, and is recorded in depreciation and amortization expense
in NEE's and FPL's consolidated statements of income. At December 31, 2019, FPL's portion of the ultimate cost to dismantle its
fossil and solar units is approximately $1.2 billion, or $510 million expressed in 2019 dollars.
NEER's AROs include 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. The liabilities
are being accreted using the interest method through the date decommissioning or dismantlement activities are expected to be
complete. See Note 13. At December 31, 2019 and 2018, NEER's ARO was approximately $1,097 million and $988 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 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 $9.5 billion, or $2.0 billion expressed in 2019
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 2019. 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
Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC), and in the case of Seabrook, the NDFC, has
73
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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 carried at fair value. See Note 5. Market adjustments for debt securities result in a corresponding adjustment to
other comprehensive income (OCI), except for unrealized losses associated with marketable debt securities considered to be other
than temporary, including any credit losses, which are recognized in other - net in NEE's consolidated statements of income. Market
adjustments for equity securities are recorded in change in unrealized gains (losses) on equity securities held in NEER's nuclear
decommissioning funds - net in NEE's consolidated statements of income. Fund earnings, consisting of dividends, interest and
realized gains and losses are recognized in income and are reinvested in the funds. The tax effects of amounts not yet recognized
for tax purposes are included in deferred income taxes.
Major Maintenance Costs - FPL expenses costs associated with planned fossil maintenance as incurred. FPL recognizes costs
associated with planned major nuclear maintenance in accordance with regulatory treatment. FPL defers nuclear maintenance
costs for each nuclear unit’s planned outage to a regulatory asset as the costs are incurred and amortizes the costs to O&M expense
over the period from the end of the current outage to the end of the next planned outage.
NEER uses the deferral method to account for certain planned major maintenance costs. NEER's major maintenance costs for its
nuclear generation units and combustion turbines are capitalized (included in noncurrent other assets on NEE's consolidated balance
sheets) and amortized to O&M expenses on a unit of production method over the period from the end of the last outage to the
beginning of the next planned outage.
Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.
Restricted Cash - At December 31, 2019 and 2018, NEE had approximately $508 million ($118 million for FPL) and $4,615 million
($142 million for FPL), respectively, of restricted cash, of which approximately $411 million ($54 million for FPL) and $89 million
($81 million for FPL), respectively, is included in current other assets and the remaining balance is included in noncurrent other
assets on NEE's and FPL's consolidated balance sheets. Restricted cash is primarily related to debt service payments, bond
proceeds held for construction at FPL and margin cash collateral requirements, and, at December 31, 2018, also related to cash
restricted for the acquisition of Gulf Power Company (Gulf Power) (see Note 8 - Gulf Power Company). In addition, where offsetting
positions exist, restricted cash related to margin cash collateral of $139 million is netted against derivative assets and $66 million
is netted against derivative liabilities at December 31, 2019 and $184 million is netted against derivative assets at December 31,
2018. See Note 4.
Allowance for Doubtful Accounts - FPL maintains an accumulated provision for uncollectible customer accounts receivable that is
estimated primarily using a percentage, derived from historical revenue and write-off trends, of the previous four 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 and net realizable value, unless evidence
indicates that the weighted-average cost 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, generation 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 4.
Storm Fund, Storm Reserve and Storm Cost Recovery - The storm and property insurance reserve fund (storm fund) provides
coverage toward FPL's storm damage costs. Marketable securities held in the storm fund are carried at fair value. See Note 5. 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 and property insurance reserve (storm reserve). The tax effects of amounts not yet recognized for tax purposes are
included in deferred income taxes. The storm fund and storm reserve are included in special use funds and noncurrent regulatory
liabilities on NEE's and FPL's consolidated balance sheets.
In March 2017, FPL began recovering from its retail customers, through an interim storm surcharge over a 12-month period, eligible
storm restoration costs associated with Hurricane Matthew, a 2016 hurricane, of approximately $201 million ($294 million of
recoverable costs less $93 million available in FPL's storm reserve prior to the storm), plus approximately $117 million to replenish
the storm reserve to the level authorized in FPL's previous rate agreement. As the portion of the Hurricane Matthew surcharge
74
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
applicable to the replenishment of the storm reserve was billed to customers (which was recorded as operating revenues), the storm
reserve was recognized as a regulatory liability and charged to depreciation and amortization expense in NEE's and FPL's
consolidated statements of income. As part of a settlement agreement between FPL and the OPC regarding the recovery of storm
costs related to Hurricane Matthew, FPL issued a one-time refund to customers in August 2018 totaling approximately $28 million,
of which $20 million was for storm costs that were reclassified to property, plant and equipment.
In September 2017, FPL was impacted by Hurricane Irma, which resulted in damage throughout much of FPL's service territory.
Damage to FPL property from the hurricane was primarily limited to the transmission and distribution systems. In December 2017,
following the enactment of the Tax Cuts and Jobs Act (tax reform) as further discussed in Note 6, FPL determined that it would not
seek recovery of Hurricane Irma storm restoration costs of approximately $1.3 billion through a storm surcharge from customers
and instead recorded such costs as storm restoration costs in NEE's and FPL's consolidated statements of income. As allowed
under the 2016 rate agreement, FPL used available reserve amortization to offset nearly all of the Hurricane Irma storm restoration
costs that were expensed, and FPL is partially restoring the reserve amortization through tax savings generated during the term of
the 2016 rate agreement.
In September 2019, FPL’s service territory was impacted by Hurricane Dorian. FPL incurred approximately $260 million of incremental
storm restoration costs, which primarily included costs for pre-staging resources in advance of the storm to repair damage to FPL’s
distribution system. In December 2019, FPL determined that it would not seek recovery of the Hurricane Dorian storm restoration
costs through a storm surcharge from customers and instead recorded such costs as storm restoration costs in NEE’s and FPL’s
consolidated statements of income. FPL used available reserve amortization resulting from operational efficiencies generated at
the business to offset all of the Hurricane Dorian storm restoration costs that were expensed.
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 5 - Nonrecurring Fair Value
Measurements.
Goodwill and Other Intangible Assets - NEE's goodwill and other intangible assets are as follows:
Goodwill (by reporting unit):
FPL segment:
Florida City Gas
Other
NEER segment:
Rate-regulated transmission (see Note 8 - Trans Bay Cable, LLC)
Gas infrastructure
Customer supply
Generation assets
Corporate and Other - Gulf Power (see Note 8 - Gulf Power Company)
Total goodwill
Other intangible assets not subject to amortization, primarily land easements
Other intangible assets subject to amortization:
Purchased power agreements
Other, primarily transmission and development rights and customer lists
Total
Accumulated amortization
Total other intangible assets subject to amortization - net
Weighted-
Average
Useful Lives
(years)
December 31,
2019
2018
(millions)
$
291
$
9
610
487
93
28
2,686
4,204
135
$
$
401
$
72
473
(56)
417
$
17
22
$
$
$
$
293
11
—
487
72
28
—
891
135
625
34
659
(86)
573
NEE's, including FPL's, goodwill relates to various acquisitions which were accounted for using the purchase method of accounting.
Other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. NEE's other
intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives.
Amortization expense was approximately $18 million, $19 million and $35 million for the years ended December 31, 2019, 2018
and 2017, respectively, and is expected to be approximately $18 million, $14 million, $8 million, $7 million and $4 million for 2020,
2021, 2022, 2023 and 2024, respectively.
75
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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 Plan - NEE records the service cost component of net periodic benefit income to O&M expense and the non-service cost
component to other net periodic benefit income in NEE's consolidated statements of income. NEE allocates net periodic pension
income to its subsidiaries based on the pensionable earnings of the subsidiaries' employees. Accounting guidance requires
recognition of the funded status of the 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 that are estimated to be allocable to FPL as net periodic (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.
Forfeitures of stock-based awards are recognized as they occur. See Note 11 - Stock-Based Compensation.
Retirement of Long-Term Debt - For NEE's rate-regulated subsidiaries, including FPL, gains and losses that result from differences
in reacquisition cost and the net book value of long-term debt which is retired are deferred as a regulatory asset or liability and
amortized to interest expense ratably over the remaining life of the original issue, which is consistent with their treatment in the
ratemaking process. NEE's non-rate regulated subsidiaries recognize such differences in interest expense at the time of retirement.
Income Taxes - Deferred income taxes are recognized on all significant temporary differences between the financial statement and
tax bases of assets and 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 applicable subsidiary that generated the tax benefits. Any remaining
consolidated income tax benefits or expenses are recorded at the corporate level. Included in other regulatory assets and other
regulatory liabilities on NEE's and FPL's consolidated balance sheets is the revenue equivalent of the difference in deferred income
taxes computed under accounting rules, as compared to regulatory accounting rules. The net regulatory liability totaled $4,141
million ($3,745 million for FPL) and $4,074 million ($4,042 million for FPL) at December 31, 2019 and 2018, 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.
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, 2019 and 2018, FPL’s accumulated deferred ITCs were approximately $412 million and
$326 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, 2019 and 2018, the net deferred income tax benefits associated with FPL's convertible
ITCs were approximately $40 million and $42 million, respectively, and are included in noncurrent 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 2016. State and foreign
tax liabilities, which have varied statutes of limitations regarding additional assessments, are generally effectively settled for years
prior to 2015. At December 31, 2019, NEE had unrecognized tax benefits of approximately $79 million that, if recognized, could
impact the annual effective income tax rate. The amounts of unrecognized tax benefits and related interest accruals may change
76
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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 6.
Sales of Differential Membership Interests - Certain subsidiaries of NextEra Energy Resources sold Class B membership interests
in entities that have ownership interests in wind and solar facilities, with generating capacity totaling approximately 7,081 MW and
473 MW, respectively, at December 31, 2019, to third-party investors. NEE retains a controlling interest in the entities and therefore
presents the Class B member interests as noncontrolling interests. Noncontrolling interests represents the portion of net assets in
consolidated entities that are not owned by NEE and are reported as a component of equity in NEE’s consolidated balance sheet.
The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability
company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted return (the
flip date) and thereafter to NEE. NEE has the right to call the third-party interests at specified amounts if and when the flip date
occurs. NEE has determined the allocation of economics between the controlling party and third-party investor should not follow
the respective ownership percentages for each wind and solar project but rather the hypothetical liquidation of book value (HLBV)
method based on the governing provisions in each respective limited liability company agreement. Under the HLBV method, the
amounts of income and loss attributable to the noncontrolling interest reflects changes in the amount the owners would hypothetically
receive at each balance sheet date under the respective liquidation provisions, assuming the net assets of these entities were
liquidated at the recorded amounts, after taking into account any capital transactions, such as contributions and distributions,
between the entities and the owners. At the point in time that the third-party investor, in hypothetical liquidation, would achieve its
targeted return, NEE attributes the additional hypothetical proceeds to the Class B membership interests based on the call price.
A loss attributable to noncontrolling interest on NEE’s consolidated statements of income represents earnings attributable to NEE.
Additionally, net (income) loss attributable to noncontrolling interests in NEE's consolidated statement of income for the year ended
December 31, 2018 includes a benefit to NEE of approximately $497 million ($373 million after tax) related to a reduction of differential
membership interests as a result of a change in the federal corporate income tax rate effective January 1, 2018. Pursuant to previous
accounting guidance, prior to 2018, the proceeds received on the sale of Class B membership interest in entities were deferred and
recorded as a liability recognized in benefits associated with differential membership interests - net in NEE's consolidated statements
of income as the Class B members received their portion of the economic attributes.
Redeemable Noncontrolling Interests - Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in
entities that have ownership interests in wind facilities to third-party investors. As specified in the respective limited liability company
agreements, if, subject to certain contingencies, certain events occur, including, among others, those that would delay construction
or cancel any of the underlying projects, an investor has the option to require NEER to return all or part of its investment. As these
potential redemptions are outside of NEER’s control, these balances were classified as redeemable noncontrolling interests on
NEE's consolidated balance sheet as of December 31, 2019 and 2018. During 2019, certain contingencies were resolved resulting
in $395 million of the December 31, 2018 balance being reclassified to noncontrolling interests. The contingencies associated with
the December 31, 2019 balance are expected to be resolved in 2020.
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 9.
Leases - NEE and FPL determine if an arrangement is a lease at inception. NEE and FPL recognize a right-of-use (ROU) asset
and a lease liability for operating and finance leases by recognizing and measuring leases at the commencement date based on
the present value of lease payments over the lease term. For sales type leases, the book value of the leased asset is removed from
the balance sheet and a net investment in sales-type lease is recognized based on fixed payments under the contract and the
residual value of the asset being leased. NEE and FPL have elected not to apply the recognition requirements to short-term leases
and not to separate nonlease components from associated lease components for all classes of underlying assets except for
purchased power agreements. ROU assets are included primarily in noncurrent other assets, lease liabilities are included in current
and noncurrent other liabilities and net investments in sales-type leases are included in current and noncurrent other assets on
NEE’s and FPL's consolidated balance sheets. Operating lease expense is included in O&M expenses, amortization expense is
included in depreciation and amortization expense and interest income associated with sales-type leases is included in operating
revenues in NEE’s and FPL’s consolidated statements of income. See Note 14.
Acquisition-Related - During 2019, 2018 and 2017, NEE and certain of its affiliates incurred costs related to several proposed or
completed acquisitions, including transaction costs, integration costs and the payment of certain termination fees, which are included
in acquisition-related expenses in NEE's consolidated statements of income. See Note 8.
77
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Disposal of Businesses/Assets - On February 11, 2020, a subsidiary of NextEra Energy Resources completed the sale of its
ownership interest in two solar generation facilities located in Spain with a total generating capacity of 99.8 MW for net cash proceeds
of approximately €117 million (approximately $128 million), subject to working capital and other adjustments. In connection with the
sale, NEE anticipates recording a gain of approximately $260 million (pretax and after tax) in its consolidated statements of income
during the three-months ended March 31, 2020. The carrying amounts of the major classes of assets related to the facilities that
were classified as held for sale, which are included in current other assets on NEE's consolidated balance sheets, were approximately
$440 million at December 31, 2019 and primarily represent property, plant and equipment. Liabilities associated with assets held
for sale, which are included in current other liabilities on NEE's consolidated balance sheets, were approximately $647 million at
December 31, 2019 and primarily represent long-term debt and interest rate derivatives.
In June 2019, subsidiaries of NextEra Energy Resources completed the sale of ownership interests in three wind generation facilities
and three solar generation facilities, including noncontrolling interests in two of the solar facilities, located in the Midwest and West
regions of the U.S. with a total net ownership interest in plant capacity (net generating capacity) of 611 MW to a NEP subsidiary for
cash proceeds of approximately $1.0 billion, plus working capital of $12 million. A NEER affiliate will continue to operate the facilities
included in the sale. In connection with the sale, a gain of approximately $341 million ($259 million after tax) was recorded in NEE's
consolidated statements of income for the year ended December 31, 2019, which is included in gains on disposal of businesses/
assets - net, and noncontrolling interests of approximately $118 million were recorded on NEE's consolidated balance sheet.
In 2018, subsidiaries of NextEra Energy Resources completed the sale of its ownership interests in ten wind generation facilities
and one solar generation facility located in the Midwest, South and West regions of the U.S. with a total net generating capacity of
1,388 MW to a subsidiary of NEP for net cash proceeds of approximately $1.3 billion, after transaction costs and working capital
adjustments and NEP's assumption of approximately $941 million in existing noncontrolling interests related to differential
membership investors. In connection with the sale and the related consolidating state income tax effects, a gain of approximately
$36 million ($32 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2018
and is included in gains on disposal of businesses/assets - net.
In 2017, an indirect wholly owned subsidiary of NEE completed the sale of its membership interests in its fiber-optic
telecommunications business 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
($685 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2017 and is
included in gains on disposal of businesses/assets - net.
2. Revenue from Contracts with Customers
Revenue is recognized when control of the promised goods or services is transferred to customers at an amount that reflects the
consideration to which the entity expects to be entitled in exchange for those goods and services. The promised goods or services
in the majority of NEE’s contracts with customers is, at FPL, for the delivery of electricity based on tariff rates approved by the FPSC
and, at NEER, for the delivery of energy commodities and the availability of electric capacity and electric transmission.
FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with
customers, as well as derivative and lease transactions at NEER. For the vast majority of contracts with customers, NEE believes
that the obligation to deliver energy, capacity or transmission is satisfied over time as the customer simultaneously receives and
consumes benefits as NEE performs. In 2019 and 2018, NEE’s revenue from contracts with customers was approximately $17.5
billion ($12.1 billion at FPL) and approximately $15.4 billion ($11.8 billion at FPL), respectively. NEE's and FPL's receivables are
primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER,
and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and
FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing
of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue
transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the
terms and conditions of payment are similar.
FPL - FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida
with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s operating revenues,
the majority of which are to residential customers. FPL’s retail customers receive a bill monthly based on the amount of monthly
kWh usage with payment due monthly. For these types of sales, FPL recognizes revenue as electricity is delivered and billed to
customers, as well as an estimate for electricity delivered and not yet billed. The billed and unbilled amounts represent the value
of electricity delivered to the customer. At December 31, 2019 and 2018, FPL's unbilled revenues amounted to approximately $389
million and $432 million, respectively, and are included in customer receivables on NEE’s and FPL’s consolidated balance sheets.
NEER - NEER’s revenue from contracts with customers is derived primarily from the sale of energy commodities, electric capacity
and electric transmission. For these types of sales, NEER recognizes revenue as energy commodities are delivered and as electric
capacity and electric transmission are made available, consistent with the amounts billed to customers based on rates stipulated
in the respective contracts as well as an accrual for amounts earned but not yet billed. The amounts billed and accrued represent
78
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
the value of energy or transmission delivered and/or the capacity of energy or transmission available to the customer. Revenues
yet to be earned under these contracts, which have maturity dates ranging from 2020 to 2053, will vary based on the volume of
energy or transmission delivered and/or available. NEER’s customers typically receive bills monthly with payment due within 30
days. Certain contracts with customers contain a fixed price which primarily relate to electric capacity sales associated with
independent system operator annual auctions through 2023 and certain power purchase agreements with maturity dates through
2034. At December 31, 2019, NEER expects to record approximately $945 million of revenues related to the fixed price components
of such contracts over the remaining terms of the related contracts as the capacity is provided.
3. 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 $313 million ($167 million for FPL) and $226 million ($187 million for FPL) at December 31, 2019 and 2018, respectively.
Pension Plan Assets, Benefit Obligations and Funded Status - The changes in assets, benefit obligations and the funded status of
the pension plan are as follows:
Change in pension plan assets:
Fair value of plan assets at January 1
Actual return on plan assets
Benefit payments
Acquisitions(a)
Fair value of plan assets at December 31
Change in pension benefit obligation:
Obligation at January 1
Service cost
Interest cost
Acquisitions(a)
Special termination benefits(b)
Plan amendments
Actuarial losses (gains) - net
Benefit payments
Obligation at December 31(c)
Funded status:
Prepaid pension benefit costs at NEE at December 31
Prepaid pension benefit costs at FPL at December 31(d)
_________________________
2019
2018
(millions)
3,806
$
4,020
736
(235)
493
4,800
2,522
80
114
503
19
3
357
(235)
3,363
1,437
1,477
$
$
$
$
$
(69)
(160)
15
3,806
2,593
70
82
15
35
—
(113)
(160)
2,522
1,284
1,407
$
$
$
$
$
$
(a) Relates to substantially funded pension obligations in connection with the acquisitions of Gulf Power and Florida City Gas, see Note 8.
(b) Reflects enhanced early retirement programs.
(c) NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2019 and 2018 was approximately $3,281
million and $2,479 million, respectively.
(d) Reflects FPL's allocated benefits under NEE's pension plan.
NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of
prepaid pension benefit costs are as follows:
Unrecognized prior service benefit (net of $2 and $2 tax expense, respectively)
Unrecognized losses (net of $37 and $27 tax benefit, respectively)
Total
2019
2018
$
$
(millions)
2
$
(108)
(106) $
2
(71)
(69)
79
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
NEE's unrecognized amounts included in regulatory assets yet to be recognized as components of net prepaid pension benefit
costs are as follows:
Unrecognized prior service benefit
Unrecognized losses
Total
2019
2018
(millions)
(2) $
263
261
$
(3)
376
373
$
$
The following table provides the assumptions used to determine the benefit obligation for the pension plan. These rates are used
in determining net periodic pension income in the following year.
Discount rate(a)
Salary increase
_________________________
2019
2018
3.22%
4.40%
4.26%
4.40%
(a)
The method of estimating the interest cost component of net periodic benefit costs uses a full yield curve approach by applying a specific spot rate along the yield
curve.
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 include a convertible security oriented limited partnership. The pension fund's alternative investments
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.
The fair value measurements of NEE's pension plan assets by fair value hierarchy level are as follows:
December 31, 2019(a)
Quoted Prices
in Active
Markets for
Identical Assets
or Liabilities
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
$
1,593
$
—
95
—
—
47
32
(millions)
9
$
706
7
247
416
143
372
$
1,767
$
1,900
$
3
—
—
—
—
—
—
3
Total
$
1,605
706
102
247
416
190
404
3,670
1,130
4,800
$
Equity securities(b)
Equity commingled vehicles(c)
U.S. Government and municipal bonds
Corporate debt securities(d)
Asset-backed securities
Debt security commingled vehicles(e)
Convertible securities(f)
Total investments in the fair value hierarchy
Total investments measured at net asset value(g)
Total fair value of plan assets
_____________________
(a)
(b)
(c)
(d)
(e)
(f)
(g)
See Note 5 for discussion of fair value measurement techniques and inputs.
Includes foreign investments of $741 million.
Includes foreign investments of $141 million.
Includes foreign investments of $76 million.
Includes foreign investments of $5 million.
Includes foreign investments of $20 million.
Includes foreign investments of $190 million.
80
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2018(a)
Quoted Prices
in Active
Markets for
Identical Assets
or Liabilities
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
$
1,030
$
—
84
—
—
—
17
(millions)
11
$
638
11
252
253
133
303
$
1,131
$
1,601
$
2
—
—
—
—
—
—
2
Total
$
1,043
638
95
252
253
133
320
2,734
1,072
3,806
$
Equity securities(b)
Equity commingled vehicles(c)
U.S. Government and municipal bonds
Corporate debt securities(d)
Asset-backed securities
Debt security commingled vehicles
Convertible securities(e)
Total investments in the fair value hierarchy
Total investments measured at net asset value(f)
Total fair value of plan assets
______________________
(a)
(b)
(c)
(d)
(e)
(f)
See Note 5 for discussion of fair value measurement techniques and inputs.
Includes foreign investments of $459 million.
Includes foreign investments of $193 million.
Includes foreign investments of $77 million.
Includes foreign investments of $30 million.
Includes foreign investments of $214 million.
Expected Cash Flows - The following table provides information about benefit payments expected to be paid by the pension plan
for each of the following calendar years (in millions):
2020
2021
2022
2023
2024
2025 - 2029
$
$
$
$
$
$
211
203
203
206
207
1,044
Net Periodic Income - The components of net periodic income for the plans are as follows:
Service cost
Interest cost
Expected return on plan assets
Amortization of prior service benefit
Special termination benefits
Postretirement benefits settlement
Net periodic income at NEE
Net periodic income allocated to FPL
Pension Benefits
Postretirement Benefits
2019
2018
2017
2019
2018
2017
$
80
$
114
(312)
(1)
19
—
$
70
82
(millions)
$
66
83
(276)
(270)
(1)
35
—
(1)
38
—
$
1
9
—
(15)
—
—
$
1
7
—
(15)
—
—
$
$
(100) $
(71) $
(90) $
(57) $
(84) $
(51) $
(5) $
(4) $
(7) $
(6) $
1
8
—
(10)
—
1
—
—
Other Comprehensive Income - The components of net periodic income recognized in OCI for the pension plan are as follows:
Net gains (losses) (net of $10 tax benefit, $4 tax benefit and $23 tax expense, respectively)
$
(36) $
(13) $
37
2019
2018
2017
(millions)
81
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Regulatory Assets (Liabilities) - The components of net periodic income recognized during the year in regulatory assets (liabilities)
for the pension plan are as follows:
Unrecognized losses (gains)
Amortization of prior service cost
Total
2019
2018
(millions)
(113) $
1
(112) $
216
1
217
$
$
The assumptions used to determine net periodic pension income for the pension plan are as follows:
Discount rate
Salary increase
Expected long-term rate of return, net of investment management fees(a)
______________________
2019
2018
2017
4.26%
4.40%
7.35%
3.59%
4.10%
7.35%
4.09%
4.10%
7.35%
(a)
In developing the expected long-term rate of return on assets assumption for its 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 pension fund. NEE also considered its pension fund's historical compounded returns.
Employee Contribution Plan - NEE offers an employee retirement savings plan which allows eligible participants to contribute a
percentage of qualified compensation through payroll deductions. NEE makes matching contributions to participants' accounts.
Defined contribution expense pursuant to this plan was approximately $58 million, $54 million and $53 million for NEE ($36 million,
$34 million and $33 million for FPL) for the years ended December 31, 2019, 2018 and 2017, respectively.
4. Derivative Instruments
NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the physical and financial risks
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 expected future debt issuances and borrowings, and to optimize the value of NEER's power generation
and gas infrastructure assets. NEE and FPL do not utilize hedge accounting for their cash flow and fair value hedges.
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 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 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.
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
82
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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.
For interest rate and foreign currency derivative instruments, essentially all changes in the derivatives' fair value, as well as the
transaction gain or loss on foreign denominated debt, are recognized in interest 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. At December 31,
2019, NEE's AOCI included amounts related to discontinued interest rate cash flow hedges with expiration dates through March
2035 and foreign currency cash flow hedges with expiration dates through September 2030. Approximately $14 million of net losses
included in AOCI at December 31, 2019 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 scheduled principal payments.
Fair Value of Derivative Instruments - The tables below present NEE's and FPL's gross derivative positions at December 31, 2019
and December 31, 2018, 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 5 - Recurring Fair
Value Measurements for netting information), as well as the location of the net derivative position on the consolidated balance
sheets.
NEE:
Commodity contracts
Interest rate contracts
Foreign currency contracts
Total fair values
FPL:
Commodity contracts
Net fair value by NEE balance sheet line item:
Current derivative assets(a)
Noncurrent derivative assets(b)
Current derivative liabilities(c)
Current other liabilities(d)
Noncurrent derivative liabilities
Total derivatives
Net fair value by FPL balance sheet line item:
Current other assets
Current other liabilities
Noncurrent other liabilities
Total derivatives
______________________
December 31, 2019
Gross Basis
Net Basis
Assets
Liabilities
Assets
Liabilities
(millions)
5,050
$
3,201
$
2,350
$
26
26
742
38
9
27
576
725
39
5,102
$
3,981
$
2,386
$
1,340
4
$
14
$
3
$
13
$
$
$
$
$
$
$
762
1,624
$
344
133
863
2,386
$
1,340
3
3
$
$
12
1
13
(a) Reflects the netting of approximately $2 million in margin cash collateral received from counterparties.
(b) Reflects the netting of approximately $139 million in margin cash collateral received from counterparties.
(c) Reflects the netting of approximately $66 million in margin cash collateral paid to counterparties.
(d)
See Note 1 - Disposal of Businesses/Assets.
83
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
NEE:
Commodity contracts
Interest rate contracts
Foreign currency contracts
Total fair values
FPL:
Commodity contracts
Net fair value by NEE balance sheet line item:
Current derivative assets(a)
Noncurrent derivative assets(b)
Current derivative liabilities
Noncurrent derivative liabilities
Total derivatives
Net fair value by FPL balance sheet line item:
Current other liabilities
Noncurrent other liabilities
Total derivatives
______________________
December 31, 2018
Gross Basis
Net Basis
Assets
Liabilities
Assets
Liabilities
(millions)
4,651
$
3,305
$
1,840
$
56
17
472
30
49
30
683
465
43
4,724
$
3,807
$
1,919
$
1,191
2
$
43
$
— $
41
$
$
$
$
564
1,355
$
1,919
$
$
$
$
— $
675
516
1,191
32
9
41
(a) Reflects the netting of approximately $124 million in margin cash collateral received from counterparties.
(b) Reflects the netting of approximately $65 million in margin cash collateral received from counterparties.
At December 31, 2019 and 2018, NEE had approximately $10 million and $16 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, 2019 and 2018, NEE had
approximately $360 million and $157 million (none at FPL), respectively, in margin cash collateral paid 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) related to NEE's derivatives are recorded in NEE's consolidated
statements of income as follows:
Commodity contracts:(a)
Operating revenues
Fuel, purchased power and interchange
Foreign currency contracts - interest expense
Foreign currency contracts - other - net
Interest rate contracts - interest expense
Losses reclassified from AOCI to interest expense:
Interest rate contracts
Foreign currency contracts
Total
______________________
Years Ended December 31,
2019
2018
(millions)
2017
$
762
$
377
$
—
(7)
—
(699)
(32)
(4)
(2)
19
—
(280)
(30)
(4)
$
20
$
80
$
454
—
55
(4)
(223)
(48)
(81)
153
(a)
For the years ended December 31, 2019, 2018 and 2017, FPL recorded gains (losses) of approximately $9 million, $(31) million and $(169) million, respectively,
related to commodity contracts as regulatory liabilities (assets) on its consolidated balance sheets.
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
84
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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:
Commodity Type
NEE
FPL
NEE
FPL
December 31, 2019
December 31, 2018
Power
Natural gas
Oil
______________________
(a) Megawatt-hours
(b) One million British thermal units
(81) MWh(a)
(1,723) MMBtu(b)
1 MWh(a)
161 MMBtu(b)
(13) barrels
—
(100) MWh(a)
(491) MMBtu(b)
(30) barrels
1 MWh(a)
231 MMBtu(b)
—
(millions)
At December 31, 2019 and 2018, NEE had interest rate contracts with a net notional amount of approximately $8.9 billion and $13.4
billion, respectively, and foreign currency contracts with a net notional amount of approximately $1.0 billion and $656 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, 2019 and 2018, the
aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was
approximately $1.7 billion ($12 million for FPL) and $1.8 billion ($34 million for FPL), respectively.
If the credit-risk-related contingent features underlying these derivative agreements 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 three 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 $215 million (none at FPL) and $270 million (none at FPL)
at December 31, 2019 and 2018, 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
$1.2 billion ($35 million at FPL) and $1.5 billion ($45 million at FPL) at December 31, 2019 and 2018, 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 NEE
subsidiaries could be required to post additional collateral of up to approximately $590 million ($75 million at FPL) and $610 million
($145 million at FPL) at December 31, 2019 and 2018, 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,
2019 and 2018, applicable NEE subsidiaries have posted approximately $2 million (none at FPL) and $2 million (none at FPL),
respectively, in cash and $88 million (none at FPL) and $88 million (none at FPL), respectively, in the form of letters of credit each
of which could be applied toward the collateral requirements described above. FPL and NEECH have capacity under their 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 whereby 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.
5. 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 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.
85
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Cash Equivalents and Restricted Cash Equivalents - NEE and FPL hold investments in money market funds. The fair value of these
funds is estimated 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 OTC markets, or through the use of industry-standard
valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable
valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or
liability through an orderly transaction in the marketplace at the measurement date.
Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded
derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open
interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using
other observable inputs.
NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts
are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from
exchanges, brokers or pricing services for similar contracts.
NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are
measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation
of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant
inputs that are not observable, and are valued using industry-standard option models.
In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is
given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models
for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to,
assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant
Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be
inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other
observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established
using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments
from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of
methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes
to support the market price of the various commodities. In all cases where there are assumptions and models used to generate
inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models
are undertaken by individuals that are independent of those responsible for estimating fair value.
NEE uses interest rate contracts and foreign currency contracts to mitigate and adjust interest rate and foreign currency exchange
exposure related primarily to certain outstanding and expected 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 utilizing the net amount of estimated future cash inflows
and outflows related to the agreements.
86
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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:
Level 1
Level 2
Level 3
Netting(a)
Total
December 31, 2019
(millions)
Assets:
Cash equivalents and restricted cash equivalents:(b)
NEE - equity securities
FPL - equity securities
Special use funds:(c)
NEE:
Equity securities
U.S. Government and municipal bonds
Corporate debt securities
Mortgage-backed securities
Other debt securities
FPL:
Equity securities
U.S. Government and municipal bonds
Corporate debt securities
Mortgage-backed securities
Other debt securities
Other investments:(e)
NEE:
Equity securities
Debt securities
Derivatives:
NEE:
Commodity contracts
Interest rate contracts
Foreign currency contracts
FPL - commodity contracts
Liabilities:
Derivatives:
NEE:
Commodity contracts
Interest rate contracts
Foreign currency contracts
FPL - commodity contracts
______________________
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
363
156
1,875
567
$
$
$
$
— $
— $
— $
596
429
$
$
— $
— $
— $
34
82
$
$
—
—
2,088 (d)
150
748
517
117
1,895 (d)
106
533
395
111
12
69
1,229
$
2,082
— $
— $
— $
24
26
3
1,365
$
— $
— $
— $
1,446
598
38
5
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
—
—
—
—
—
—
—
—
—
—
—
—
—
—
$
$
$
$
$
$
$
$
$
$
$
$
$
$
363
156
3,963
717
748
517
117
2,491
535
533
395
111
46
151
1,739
2
$
$
— $
1
$
(2,700) $
(17) $
1
$
(1) $
2,350 (f)
9 (f)
27 (f)
3 (f)
390
144
$
$
— $
9
$
(2,625) $
(17) $
1
$
(1) $
576 (f)
725 (f)
39 (f)
13 (f)
(a)
(b)
(c)
(d)
(e)
(f)
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.
Includes restricted cash equivalents of approximately $60 million ($54 million for FPL) in current other assets and $64 million ($64 million for FPL) in noncurrent
other assets on the consolidated balance sheets.
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 Other than Fair Value below.
Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.
Included in noncurrent other assets in the consolidated balance sheets.
See Note 4 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's consolidated balance sheets.
87
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Level 1
Level 2
Level 3
Netting(a)
Total
December 31, 2018
(millions)
Assets:
Cash equivalents and restricted cash equivalents:(b)
NEE - equity securities
FPL - equity securities
Special use funds:(c)
NEE:
Equity securities
U.S. Government and municipal bonds
Corporate debt securities
Mortgage-backed securities
Other debt securities
FPL:
Equity securities
U.S. Government and municipal bonds
Corporate debt securities
Mortgage-backed securities
Other debt securities
Other investments:(e)
NEE:
Equity securities
Debt securities
Derivatives:
NEE:
Commodity contracts
Interest rate contracts
Foreign currency contracts
FPL - commodity contracts
Liabilities:
Derivatives:
NEE:
Commodity contracts
Interest rate contracts
Foreign currency contracts
FPL - commodity contracts
______________________
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
486
206
1,445
449
$
$
$
$
— $
— $
— $
398
350
$
$
— $
— $
— $
13
36
$
$
—
—
1,601 (d)
155
728
478
145
1,452 (d)
120
544
367
131
11
90
1,379
$
1,923
— $
— $
— $
56
17
2
1,329
$
— $
— $
— $
1,410
336
30
7
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
—
—
—
—
—
—
1
—
—
—
—
1
—
—
$
$
$
$
$
$
$
$
$
$
$
$
$
$
486
206
3,046
604
728
478
146
1,850
470
544
367
132
24
126
1,349
$
(2,811) $
— $
— $
— $
(7) $
13
$
(2) $
1,840 (f)
49 (f)
30 (f)
— (f)
566
136
$
$
— $
36
$
(2,622) $
(7) $
13
$
(2) $
683 (f)
465 (f)
43 (f)
41 (f)
(a)
(b)
(c)
(d)
(e)
(f)
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.
Includes restricted cash equivalents of approximately $85 million ($81 million for FPL) in current other assets on the consolidated balance sheets.
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 Other than Fair Value below.
Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.
Included in noncurrent other assets in the consolidated balance sheets.
See Note 4 - 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, block-to-hourly price shaping, customer migration rates from full requirements contracts and some implied volatility
curves, are modeled using proprietary models based on historical data and industry standard techniques.
All price (including block-to-hourly price shaping), 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
88
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
separate from the transacting group. For markets where independent third-party data is readily available, validation is conducted
daily by directly reviewing this market data against inputs utilized by the transacting group, and indirectly by 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, 2019 are as follows:
Transaction Type
Fair Value at
December 31, 2019
Assets
Liabilities
(millions)
Valuation
Technique(s)
Significant
Unobservable Inputs
Range
Forward contracts - power
Forward contracts - gas
$
Forward contracts - other commodity related
Options - power
Options - primarily gas
Full requirements and unit contingent contracts
858
195
3
42
152
489
$
52 Discounted cash flow
Forward price (per MWh)
$(14) — $258
22 Discounted cash flow
Forward price (per MMBtu)
$2 — $6
2 Discounted cash flow
Forward price (various)
$— — $70
11 Option models
Implied correlations
Implied volatilities
148 Option models
Implied correlations
Implied volatilities
1% — 88%
6% — 502%
1% — 88%
1% — 218%
155 Discounted cash flow
Forward price (per MWh)
Customer migration rate(a)
$(20) — $949
—% — 14%
Total
$
1,739
$
390
______________________
(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)
Implied correlations
Purchase option
Decrease (increase)
Sell power/gas
Decrease (increase)
Sell option
Increase (decrease)
Implied volatilities
Purchase option
Increase (decrease)
Customer migration rate
Sell option
Sell power(a)
Decrease (increase)
Decrease (increase)
————————————
(a)
Assumes the contract is in a gain position.
In addition, the fair value measurement of interest rate contract net liabilities includes a significant credit valuation adjustment and
is primarily related to the solar projects in Spain of approximately $133 million at December 31, 2019. 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 contracts.
89
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:
Fair value of net derivatives based on significant unobservable inputs at
December 31 of prior year
Realized and unrealized gains (losses):
Included in earnings(a)
Included in other comprehensive income (loss)(b)
Included in regulatory assets and liabilities
Purchases
Settlements
Issuances
Impact of adoption of revenue standard
Transfers in(c)
Transfers out(c)
Years Ended December 31,
2019
2018
2017
NEE
FPL
NEE
FPL
NEE
FPL
(millions)
$
647
$
(36) $
566
$
— $
578
$
923
5
1
141
(356)
(87)
—
(5)
(62)
—
—
1
—
25
—
—
—
2
35
7
(18)
152
28
(115)
(30)
—
22
(1)
—
(18)
(16)
(2)
—
—
—
1
376
(18)
—
126
(317)
(197)
—
17
1
Fair value of net derivatives based on significant unobservable inputs at
December 31
Gains (losses) included in earnings attributable to the change in unrealized
gains (losses) relating to derivatives held at the reporting date(d)
______________________
$
$
1,207
611
$
$
(8) $
647
— $
100
$
$
(36) $
566
(1) $
277
$
$
1
—
—
—
—
(1)
—
—
—
—
—
—
(a)
(b)
(c)
(d)
For the years ended December 31, 2019, 2018 and 2017, approximately $956 million, $48 million and $379 million of realized and unrealized gains are included
in the consolidated statements of income in operating revenues and the balance is included in interest expense.
Included in net unrealized gains (losses) on foreign currency translation in the consolidated statements of comprehensive income.
Transfers into Level 3 were a result of decreased observability of market data. Transfers from Level 3 to Level 2 were a result of increased observability of market
data. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period.
For the years ended December 31, 2019, 2018 and 2017, approximately $638 million, $112 million and $281 million of unrealized gains are included in the
consolidated statements of income in operating revenues and the balance is included in interest expense.
Nonrecurring Fair Value Measurements - NEE tests long-lived assets for recoverability whenever events or changes in
circumstances indicate that the carrying amount may not be recoverable. A wholly owned subsidiary of NextEra Energy Resources
has a power purchase agreement (PPA) with Duane Arnold's primary customer for the energy and capacity related to its 70%
ownership share of Duane Arnold that was set to expire on December 31, 2025. NEER had previously expected Duane Arnold
would operate at least until the end of its NRC operating license in February 2034. In early December 2017, NEER concluded that
it was unlikely that Duane Arnold's primary customer would extend the current PPA after it was set to expire in 2025. Without the
long-term cash flow certainty of a PPA for Duane Arnold's energy and capacity, NEER would likely close Duane Arnold on or about
December 31, 2025, the end of the term of the PPA. As a result of the change in Duane Arnold's useful life, NEER updated
depreciation and ARO estimates to reflect the December 31, 2025 closure. A recoverability analysis performed by NEER determined
that the undiscounted cash flows of Duane Arnold were less than its carrying amount and, accordingly, NEER performed a fair
value analysis to determine the amount of the impairment. Based on the fair value analysis, long-lived assets (primarily property,
plant and equipment) with a carrying amount of approximately $502 million were written down to their fair value of $82 million,
resulting in an impairment of $420 million ($258 million after tax), which is included in impairment charges in NEE's consolidated
statements of income for the year ended December 31, 2017. The estimate of fair value was based on a combination of the income
and market value approaches. The income approach utilized a discounted cash flow valuation technique considering contracted
revenue rates (Level 2), annual generation forecasts, annual projected capital and maintenance expenditures and a discount rate
(all of which are Level 3). The market value approach utilized a transaction involving a comparable nuclear power plant sale in
March 2017 and adjusted for certain entity specific assumptions (Level 3). In January 2019, an amendment to the PPA with Duane
Arnold's primary customer became effective which shortened the term of the PPA by five years and results in the PPA expiring on
December 31, 2020. Operations of Duane Arnold are expected to cease in late 2020.
90
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Fair Value of Financial Instruments Recorded at Other than Fair Value - The carrying amounts of commercial paper and other short-
term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments recorded at
other than fair value are as follows:
NEE:
Special use funds(a)
Other investments(b)
Long-term debt, including current portion(c)
FPL:
Special use funds(a)
Long-term debt, including current portion
______________________
December 31, 2019
December 31, 2018
Carrying
Amount
Estimated
Fair Value
Carrying
Amount
Estimated
Fair Value
$
$
$
$
$
892
30
39,667
706
14,161
$
$
$
$
$
(millions)
891
$
$
30
42,928 (d) $
705
$
16,448 (d) $
884
54
29,498
693
11,783
$
$
$
$
$
883
54
30,043 (d)
692
12,613 (d)
(a)
(b)
(c)
(d)
Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis (Level 2).
Included in noncurrent other assets on NEE's consolidated balance sheets.
Excludes debt totaling approximately $463 million classified as held for sale, which is included in current other liabilities on NEE's consolidated balance sheets,
for which the carrying amount approximates fair value. See Note 1 - Disposal of Businesses/Assets.
At December 31, 2019 and 2018, substantially all is Level 2 for NEE and all is Level 2 for FPL.
Special Use Funds - The special use funds noted above and those carried at fair value (see Recurring Fair Value Measurements
above) consist of NEE's nuclear decommissioning fund assets of approximately $6,880 million and $5,818 million at December 31,
2019 and 2018, respectively, ($4,697 million and $3,987 million, respectively, for FPL) and FPL's storm fund assets of $74 million
and $68 million at December 31, 2019 and 2018, respectively. The investments held in the special use funds consist of equity and
available for sale debt securities which are primarily carried at estimated fair value. The amortized cost of debt securities is
approximately $2,030 million and $1,994 million at December 31, 2019 and 2018, respectively ($1,523 million and $1,542 million,
respectively, for FPL).
For FPL's special use funds, changes in fair value, including any other than temporary impairment losses, result in a corresponding
adjustment to the related regulatory asset or liability accounts, consistent with regulatory treatment. For NEE's non-rate regulated
operations, changes in fair value of debt securities result in a corresponding adjustment to OCI, except for unrealized losses
considered to be other than temporary, including any credit losses, which are recognized in other - net in NEE's consolidated
statements of income. For NEE's non-rate regulated operations, changes in fair value of equity securities are recorded in change
in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds - net in NEE's consolidated
statements of income.
The unrealized gains (losses) recognized during the year ended December 31, 2019 and 2018 on equity securities held at
December 31, 2019 and 2018 were $780 million ($510 million for FPL) and $(259) million ($(131) million for FPL), respectively.
Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2019 of
approximately eight years at both NEE and FPL. FPL's storm fund primarily consists of debt securities with a weighted-average
maturity at December 31, 2019 of approximately one year. 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,
2019
2018
2017
2019
2018
2017
Realized gains
Realized losses
$
$
68
48
Proceeds from sale or maturity of securities $
3,005
$
$
$
51
75
2,551
$
$
$
(millions)
178
83
2,817
$
$
$
44
29
2,539
$
$
$
31
49
2,100
$
$
$
75
50
1,902
91
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The unrealized gains and 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:
Unrealized gains
Unrealized losses(a)
Fair value
______________________
NEE
December 31,
FPL
December 31,
2019
2018
2019
2018
$
$
$
75
7
314
$
$
$
(millions)
14
52
1,273
$
$
$
58
7
240
$
$
$
11
41
961
(a) Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2019 and 2018 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.
6. Income Taxes
On December 22, 2017, tax reform legislation was signed into law which, among other things, reduced the federal corporate income
tax rate from 35% to 21% effective January 1, 2018. As a result, NEE, including FPL, revalued its deferred income taxes as of
December 31, 2017. At December 31, 2017, the revaluation reduced NEE’s net deferred income tax liabilities by approximately
$6.5 billion, of which $4.5 billion related to net deferred income tax liabilities at FPL and the remaining $2 billion related to net
deferred income tax liabilities at NEER. The $2 billion reduction in NEER’s deferred income tax liabilities increased NEER’s 2017
net income. The $4.5 billion reduction in FPL’s deferred income tax liabilities was recorded as a regulatory liability. The U.S.
Department of Treasury has also released proposed regulations related to the business interest expense limitations and foreign tax
credits associated with tax reform. These proposed regulations are not final and are subject to change in the regulatory review
process.
The components of income taxes are as follows:
$
Federal:
Current
Deferred
Total federal
State:
Current
Deferred
Total state
Total income tax expense (benefit)
$
NEE
FPL
Years Ended December 31,
Years Ended December 31,
2019
2018
2017
2019
2018
2017
(millions)
167
115
282
23
143
166
448
$
30
$
100
$
348
$
1,153
1,183
63
330
393
(1,047)
(947)
88
199
287
$
1,576
$
(660) $
(29)
319
49
73
122
441
$
251
134
385
91
63
154
539
$
168
776
944
29
133
162
$
1,106
92
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
A reconciliation between the effective income tax rates and the applicable statutory rate is as follows:
Statutory federal income tax rate
21.0%
21.0%
35.0 %
21.0%
21.0%
35.0%
NEE
FPL
Years Ended December 31,
Years Ended December 31,
2019
2018
2017
2019
2018
2017
Increases (reductions) resulting from:
State income taxes - net of federal income tax
benefit
Taxes attributable to noncontrolling interests
Tax reform rate change
PTCs and ITCs - NEER
Amortization of deferred regulatory credit(a)
Convertible ITCs - NEER
Other - net
Effective income tax rate
_________________________
3.4
2.1
—
(7.2)
(6.2)
—
(1.4)
4.2
2.5
—
(3.0)
(1.8)
—
(1.5)
2.9
—
(41.3)
(8.4)
—
0.6
(3.0)
3.5
—
—
—
(8.1)
—
(0.5)
4.5
—
—
—
(5.0)
—
(0.6)
3.5
—
(0.5)
—
(0.1)
—
(0.9)
11.7%
21.4%
(14.2)%
15.9%
19.9%
37.0%
(a)
2019 reflects an adjustment of approximately $83 million recorded by FPL to reduce income tax expense for the cumulative amortization of excess deferred income
taxes from January 1, 2018 as a result of a FPSC order in connection with its review of impacts associated with tax reform. One of the provisions of the order
requires FPL to amortize approximately $870 million of its excess deferred income taxes over a period not to exceed ten years.
The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows:
Deferred tax liabilities:
Property-related
Pension
Investments in partnerships and joint ventures
Other
Total deferred tax liabilities
Deferred tax assets and valuation allowance:
Decommissioning reserves
Net operating loss carryforwards
Tax credit carryforwards
ARO and accrued asset removal costs
Regulatory liabilities
Other
Valuation allowance(a)
Net deferred tax assets
Net deferred income taxes
______________________
NEE
December 31,
FPL
December 31,
2019
2018
2019
2018
(millions)
$
10,133
$
9,315
$
6,394
$
6,113
417
2,019
1,618
14,187
317
380
3,406
368
1,335
515
(285)
6,036
374
1,925
1,505
13,119
313
350
3,259
310
1,277
751
(273)
5,987
374
—
685
7,453
286
2
—
273
1,219
258
—
2,038
$
8,151
$
7,132
$
5,415
$
357
—
791
7,261
278
3
—
237
1,283
295
—
2,096
5,165
(a) Reflects a valuation allowance related to the solar projects in Spain that completely offsets the related deferred taxes, as well as deferred state tax credits and
state operating loss carryforwards.
93
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Deferred tax assets and liabilities are included on the consolidated balance sheets as follows:
Noncurrent other assets
Deferred income taxes - noncurrent liabilities
Net deferred income taxes
NEE
December 31,
FPL
December 31,
2019
2018
2019
2018
210
$
(millions)
235
$
— $
(8,361)
(7,367)
(5,415)
(8,151) $
(7,132) $
(5,415) $
$
$
—
(5,165)
(5,165)
The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at
December 31, 2019 are as follows:
Net operating loss carryforwards:
State
Foreign
Net operating loss carryforwards
Tax credit carryforwards:
Federal
State
Foreign
Tax credit carryforwards
______________________
Amount
(millions)
$
$
$
$
304
76 (a)
380
3,060
344 (b)
2
3,406
Expiration
Dates
2020-2039
2020-2039
2029-2039
2020-2044
2034-2039
(a)
(b)
Includes $58 million of net operating loss carryforwards with an indefinite expiration period.
Includes $188 million of ITC carryforwards with an indefinite expiration period.
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'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, 2019
Ownership
Interest
Gross
Investment(a)
Accumulated
Depreciation(a)
(millions)
Construction
Work
in Progress
85% $
76% $
50% $
25% $
70% $
88.23% $
91.19% $
65% $
88.23% $
2,226
1,227
715
423
69
1,270
29
137
94
$
$
$
$
$
$
$
$
$
972
473
222
146
41
375
7
7
13
$
$
$
$
$
$
$
$
$
66
55
22
14
—
45
1
—
14
FPL:
St. Lucie Unit No. 2
Scherer Unit No. 4
Gulf Power:
Daniel Units Nos. 1 and 2
Scherer Unit No. 3
NEER:
Duane Arnold
Seabrook
Wyman Station Unit No. 4
Stanton
Transmission substation assets located in Seabrook, New Hampshire
______________________
(a)
Excludes nuclear fuel.
94
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
8. Acquisitions
Gulf Power Company - On January 1, 2019, NEE acquired the outstanding common shares of Gulf Power, a rate-regulated electric
utility under the jurisdiction of the FPSC. Gulf Power serves approximately 470,000 customers in eight counties throughout northwest
Florida, has approximately 9,500 miles of transmission and distribution lines and owns approximately 2,300 MW of net generating
capacity. The purchase price included approximately $4.44 billion in cash consideration and the assumption of approximately $1.3
billion of Gulf Power debt. The cash purchase price was funded through $4.5 billion of borrowings by NEECH in December 2018
under certain short-term bi-lateral term loan agreements; the proceeds of which borrowings were restricted and included in noncurrent
other assets on NEE's consolidated balance sheet at December 31, 2018. Such borrowings were repaid in April 2019.
Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on January 1, 2019
based on their fair value. The approval by the FPSC of Gulf Power's rates, which is intended to allow Gulf Power to collect from
retail customers total revenues equal to Gulf Power's costs of providing service, including a reasonable rate of return on invested
capital, is considered a fundamental input in measuring the fair value of Gulf Power's assets and liabilities and, as such, NEE
concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. As a
result, NEE acquired assets of approximately $5.2 billion, primarily relating to property, plant and equipment of $4.0 billion and
regulatory assets of $494 million, and assumed liabilities of approximately $3.4 billion, including $1.3 billion of long-term debt, $635
million of regulatory liabilities and $562 million of deferred income taxes. The excess of the purchase price over the fair value of
assets acquired and liabilities assumed resulted in approximately $2.7 billion of goodwill which has been recognized on NEE's
consolidated balance sheet at December 31, 2019. Goodwill associated with the Gulf Power acquisition is reflected within Corporate
and Other and, for impairment testing, is included in the Gulf Power reporting unit. The goodwill arising from the transaction represents
expected benefits from continued expansion of NEE's regulated businesses and the indefinite life of Gulf Power's service territory
franchise.
Trans Bay Cable, LLC - On July 16, 2019, a wholly owned subsidiary of NEET acquired the membership interests of Trans Bay
Cable, LLC (Trans Bay), which owns and operates a 53-mile, high-voltage direct current underwater transmission cable system in
California extending from Pittsburg to San Francisco, with utility rates set by the FERC and revenues paid by the California
Independent System Operator. The purchase price included approximately $670 million in cash consideration and the assumption
of debt of approximately $422 million.
Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed based on their fair
value. The approval by the FERC of Trans Bay’s rates, which is intended to allow Trans Bay to collect total revenues equal to Trans
Bay's costs for the development, financing, construction, operation and maintenance of Trans Bay, including a reasonable rate of
return on invested capital, is considered a fundamental input in measuring the fair value of Trans Bay's assets and liabilities and,
as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their
fair values. As a result, NEE acquired assets of approximately $703 million, primarily relating to property, plant and equipment, and
assumed liabilities of approximately $643 million, primarily relating to long-term debt. The excess of the purchase price over the
fair value of assets acquired and liabilities assumed resulted in approximately $610 million of goodwill which has been recognized
on NEE's consolidated balance sheet at December 31, 2019, of which approximately $572 million is expected to be deductible for
tax purposes. Goodwill associated with the Trans Bay acquisition is reflected within NEER and, for impairment testing, is included
in the rate-regulated transmission reporting unit. The goodwill arising from the transaction represents expected benefits from
continued expansion of NEE's regulated businesses. The valuation of the acquired net assets is subject to change as NEE obtains
additional information for its estimates during the measurement period.
Other - In July 2018, NEE acquired the outstanding common shares of the entity that owns Florida City Gas (FCG), which serves
approximately 110,000 residential and commercial natural gas customers in Florida's Miami-Dade, Brevard, St. Lucie and Indian
River counties with 3,700 miles of natural gas pipeline, for approximately $530 million in cash subject to certain adjustments. Upon
closing, NEE transferred FCG to FPL.
In December 2018, NEE acquired a 100% interest in an entity that indirectly owns Oleander Power Project, an approximately 791
MW natural gas-fired, simple-cycle combustion turbine electric generation facility located near Cocoa, Florida, and a 100% interest
in an entity that owns a 65% interest in Stanton Energy Center Unit A, an approximately 660 MW combined-cycle electric generation
facility located near Orlando, Florida for approximately $200 million in cash, subject to certain adjustments.
Santee Cooper - On February 11, 2020, the South Carolina Department of Administration (DOA) announced that it had selected
NEE as the recommended bidder for the sale case in its evaluation process with respect to the South Carolina Public Service
Authority, South Carolina's state-owned electric and water utility (Santee Cooper). NEE’s proposal provides for the payment of
approximately $8.5 billion in cash to repay existing Santee Cooper debt and provide additional proceeds. In addition, NEE's proposal
provides approximately $941 million in refunds to Santee Cooper customers. The proposed purchase, which would be structured
as an asset purchase, is subject to, among other things, the South Carolina General Assembly enacting a joint resolution approving
the proposed purchase, the enactment of comprehensive enabling legislation as South Carolina law, the execution of a definitive
asset purchase agreement and the receipt of required regulatory approvals.
95
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
9. Variable Interest Entities (VIEs)
At December 31, 2019, NEE had 33 VIEs which it consolidated and had interests in certain other VIEs which it did not consolidate.
FPL - FPL is considered the primary beneficiary of, and therefore consolidates, a VIE that is a wholly owned bankruptcy remote
special purpose subsidiary that it formed in 2007 for the sole purpose of issuing storm-recovery bonds pursuant to the securitization
provisions of the Florida Statutes and a financing order of the FPSC. FPL is considered the primary beneficiary because FPL has
the power to direct the significant activities of the VIE, and its equity investment, which was subordinate to the bondholder's interest
in the VIE, was 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 included 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 arose under the financing order issued by the FPSC and certain other
collateral pledged by the VIE that issued the bonds. The storm-recovery bonds were payable only from and were secured by the
storm-recovery property, and the final payment was made in August 2019. The bondholders had no recourse to the general credit
of FPL. The assets and liabilities of the VIE were approximately $77 million and $76 million, respectively, at December 31, 2018,
and consisted primarily of storm-recovery property, which were included in current regulatory assets on NEE's and FPL's consolidated
balance sheet and storm-recovery bonds, which were included in current portion of long-term debt on NEE's and FPL's consolidated
balance sheet.
NEER - NEE consolidates 32 VIEs within the NEER segment. Subsidiaries within the NEER segment are considered the primary
beneficiary of these VIEs since they control the most significant activities of these VIEs, including operations and maintenance, and
they have the obligation to absorb expected losses of these VIEs.
NextEra Energy Resources consolidates two VIEs which own and operate natural gas/oil electric generation facilities with the
capability of producing 1,450 MW. These entities sell their electric output under power sales contracts to third parties, with expiration
dates in 2021 and 2031. The power sales contracts provide the offtaker the ability to dispatch the facilities and require the offtaker
to absorb the cost of fuel. The assets and liabilities of these two VIEs were approximately $216 million and $25 million, respectively,
at December 31, 2019. These two VIEs, together with a third VIE that consolidated two separate NEER entities, collectively had
assets and liabilities that totaled $257 million and $21 million, respectively, at December 31, 2018. At December 31, 2019 and 2018,
the assets of these consolidated VIEs consisted primarily of property, plant and equipment.
Three indirect subsidiaries of NextEra Energy Resources have an approximately 50% ownership interest in five entities which own
and operate solar photovoltaic (PV) facilities with the capability of producing a total of approximately 409 MW. Each of the three
subsidiaries is considered a VIE since the non-managing members have no substantive rights over the managing members, and
is consolidated by NextEra Energy Resources. These five entities sell their electric output to third parties under power sales contracts
with expiration dates ranging from 2035 through 2042. The five 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 NextEra Energy Resources for the repayment of
debt. The assets and liabilities of these VIEs were approximately $776 million and $598 million, respectively, at December 31, 2019.
There were two consolidated VIEs at December 31, 2018 which owned three entities which had assets and liabilities of $529 million
and $557 million, respectively. At December 31, 2019 and 2018, the assets and liabilities of the VIEs consisted primarily of property,
plant and equipment and long-term debt.
Beginning in the first quarter of 2019, NEE consolidates a NEET VIE that is constructing an approximately 275-mile electricity
transmission line. The NEET subsidiary is the primary beneficiary and controls the most significant activities during the construction
period, including controlling the construction budget. Prior to the construction period, the entity was jointly controlled and was
accounted for under the equity method. NEET is entitled to receive 50% of the profits and losses of the entity. At December 31,
2019, the assets and liabilities of the VIE totaled $173 million and $29 million, respectively.
The other 26 NextEra Energy Resources 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 7,081 MW and 473 MW, respectively. These entities sell their electric output either under power sales
contracts to third parties with expiration dates ranging from 2029 through 2053 or in the spot market. These entities are considered
VIEs because the holders of differential membership interests do not have substantive rights over the significant activities of these
entities. Certain entities have third-party debt which is secured by liens against the generation facilities and the other assets of these
entities or by pledges of NextEra Energy Resources' 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 $11.3 billion and
$0.8 billion, respectively, at December 31, 2019. There were 25 consolidated VIEs at December 31, 2018, and the assets and
liabilities of those VIEs totaled approximately $10.2 billion and $1.4 billion, respectively. At December 31, 2019 and 2018, the assets
and liabilities of the VIEs consisted primarily of property, plant and equipment and long-term debt.
96
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Other - At December 31, 2019 and 2018, several NEE subsidiaries had investments totaling approximately $3,247 million ($2,717
million at FPL) and $2,668 million ($2,203 million at FPL), respectively, which are included in special use funds and noncurrent
other assets on NEE's consolidated balance sheets and in special use funds on FPL's consolidated balance sheets. These
investments represented primarily commingled funds and mortgage-backed securities. NEE subsidiaries, including FPL, are not
the primary beneficiaries 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, including NEE's
noncontrolling interest in NEP OpCo. These entities are limited partnerships or similar entity structures in which the limited partners
or non-managing members do not have substantive rights over the significant activities of these entities, 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 $4,254 million and $4,680
million at December 31, 2019 and 2018, respectively. At December 31, 2019, subsidiaries of NEE had commitments to invest
additional amounts in five of the entities. Such commitments are included in the NEER amounts in the table in Note 15 - Contracts.
10. Investments in Partnerships and Joint Ventures
Certain subsidiaries of NEE have noncontrolling interests in various partnerships and joint ventures, essentially all of which own or
are in the process of developing natural gas pipelines or own electric generation facilities. At December 31, 2019 and 2018, NEE's
investments in partnerships and joint ventures totaled approximately $7,453 million and $6,748 million, respectively, which are
included in investment in equity method investees on NEE's consolidated balance sheets. NEE's interest in these partnerships and
joint ventures primarily range from approximately 31% to 61%. At December 31, 2019 and 2018, the principal entities included in
NEE's investments in partnerships and joint ventures were NEP OpCo, Sabal Trail Transmission, LLC (Sabal Trail) and Mountain
Valley Pipeline, LLC, and in 2019 also included Silver State South Solar, LLC.
Summarized combined information for these principal entities is as follows:
Net income
Total assets
Total liabilities
Partners'/members' equity(a)
NEE's share of underlying equity in the principal entities
Difference between investment carrying amount and underlying equity in net assets(b)
NEE's investment carrying amount for the principal entities
______________________
2019
2018
(millions)
$
$
$
$
$
$
$
$
$
$
$
128
20,659
6,956
13,703
3,723
3,153
6,876
$
632
16,334
5,990
10,344
2,958
3,193
6,151
(a) Reflects NEE's interest, as well as third-party interests, in NEP OpCo.
(b)
Primarily associated with NEP OpCo; approximately 70% of the difference between the investment carrying amount and the underlying equity in net assets relates
to goodwill and is not being amortized; the remaining balance is being amortized primarily over a period of 20 to 28 years.
NextEra Energy Resources provides management, administrative and transportation and fuel management services to NEP and
its subsidiaries under various agreements (service agreements). NextEra Energy Resources is also party to a cash sweep and
credit support (CSCS) agreement with a subsidiary of NEP. At December 31, 2019 and 2018, the cash sweep amount (due to NEP
and its subsidiaries) held in accounts belonging to NextEra Energy Resources or its subsidiaries was approximately $12 million
and $66 million, respectively, and is included in accounts payable. Fee income totaling approximately $101 million and $94 million,
respectively, related to the CSCS agreement and the service agreements is included in operating revenues in NEE's consolidated
statements of income for the years ended December 31, 2019 and 2018. Amounts due from NEP of approximately $53 million and
$45 million are included in other receivables and $33 million and $34 million are included in noncurrent other assets at December
31, 2019 and 2018, respectively. Under the CSCS agreement, NEECH or NEER guaranteed or provided indemnifications, letters
of credit or bonds totaling approximately $669 million at December 31, 2019 primarily related to obligations on behalf of NEP's
subsidiaries with maturity dates ranging from 2020 to 2059 and included certain project performance obligations, obligations under
financing and interconnection agreements and obligations related to the sale of differential membership interests. Payment
guarantees and related contracts with respect to unconsolidated entities for which NEE or one of its subsidiaries are the guarantor
are recorded on NEE’s consolidated balance sheet at fair value. As a result of deconsolidation, approximately $31 million related
to the fair value of the credit support provided under the CSCS agreement is recorded as noncurrent other liabilities on NEE's
consolidated balance sheet at December 31, 2019.
97
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
11. Equity
Earnings Per Share - The reconciliation of NEE's basic and diluted earnings per share attributable to NEE is as follows:
Numerator:
Net income attributable to NEE - basic
Adjustment for the impact of dilutive securities at NEP(a)
Net income attributable to NEE - assuming dilution
Denominator:
Weighted-average number of common shares outstanding - basic
Equity units, stock options, performance share awards, forward sale agreements
and restricted stock(b)
Weighted-average number of common shares outstanding - assuming dilution
Earnings per share attributable to NEE:
Basic
Assuming dilution
______________________
Years Ended December 31,
2019
2018
2017
(millions, except per share amounts)
$
$
$
$
3,769
$
—
3,769
$
6,638
$
(19)
6,619
$
482.0
3.5
485.5
473.2
3.8
477.0
7.82
7.76
$
$
14.03
13.88
$
$
5,380
—
5,380
468.8
3.7
472.5
11.48
11.39
(a)
The 2018 adjustment is related to both the NEP Series A convertible preferred units and the NEP senior unsecured convertible notes (see Potentially Dilutive
Securities at NEP below).
(b) 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.
Common shares issuable pursuant to stock options, performance share awards and/or equity units, as well as restricted stock which
were not included in the denominator above due to their antidilutive effect were approximately 0.7 million, 0.1 million and 3.1 million
for the years ended December 31, 2019, 2018 and 2017, respectively.
Potentially Dilutive Securities at NEP - In November 2017, NEP issued approximately $550 million of Series A convertible preferred
units representing limited partner interests in NEP (NEP preferred units). Holders of NEP preferred units may elect to convert all or
any portion of their NEP preferred units into common units of NEP at any time after June 20, 2019 subject to certain conditions.
NEP may elect to convert all or any portion of the NEP preferred units that remain outstanding into NEP common units on or after
November 15, 2020 if certain conditions are met. At December 31, 2019, the value of the NEP preferred units outstanding was
approximately $183 million. In addition, NEP has senior unsecured convertible notes outstanding of $300 million at December 31,
2019. Holders of these notes may convert all or any portion of the notes into NEP common units. The NEP preferred units and NEP
senior unsecured convertible notes are potentially dilutive securities to NEE.
98
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 for
12 million shares of its common stock to be settled on a date or dates to be specified at NEE’s direction, no later than
November 1, 2017. During 2017, NEE issued 1,711,345 shares of its common stock to net share settle the forward sale agreements.
The forward sale price used to determine the net share settlement amount was calculated based on the initial forward sale price of
$124.00 per share, less certain adjustments as specified in the forward sale agreements.
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.
Stock-Based Compensation - Net income for the years ended December 31, 2019, 2018 and 2017 includes approximately $100
million, $82 million and $76 million, respectively, of compensation costs and $17 million, $21 million and $29 million, respectively,
of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended
December 31, 2019, 2018 and 2017 was not material. At December 31, 2019, there were approximately $112 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 1.8 years.
At December 31, 2019, approximately 15 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)
2017 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 for the majority of performance
share awards is estimated 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, 2019 was as follows:
Restricted Stock:
Nonvested balance, January 1, 2019
Granted
Vested
Forfeited
Nonvested balance, December 31, 2019
Performance Share Awards:
Nonvested balance, January 1, 2019
Granted
Vested
Forfeited
Nonvested balance, December 31, 2019
Weighted-
Average
Grant Date
Fair Value
Per Share
Shares
479,936
235,280
$
$
(212,815) $
(7,253) $
495,148
$
782,664
426,777
$
$
(522,446) $
(16,849) $
670,146
$
134.69
186.54
132.15
155.20
159.74
123.47
138.99
110.68
157.07
142.42
The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 2018 and 2017
was $155.66 and $130.16 respectively. The weighted-average grant date fair value per share of performance share awards granted
for the years ended December 31, 2018 and 2017 was $124.22 and $107.39, respectively.
The total fair value of restricted stock and performance share awards vested was $125 million, $115 million and $96 million for the
years ended December 31, 2019, 2018 and 2017, respectively.
99
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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:
Expected volatility(a)
Expected dividends
Expected term (years)(b)
Risk-free rate
______________________
2019
14.20 - 14.31%
2.85 - 2.93%
7.0
2.24 - 2.54%
2018
14.41%
3.05%
7.0
2.83%
2017
14.91%
3.16%
7.0
2.23%
(a)
(b)
Based on historical experience.
Based on historical exercise and post-vesting cancellation experience adjusted for outstanding awards.
Option activity for the year ended December 31, 2019 was as follows:
Balance, January 1, 2019
Granted
Exercised
Forfeited
Balance, December 31, 2019
Exercisable, December 31, 2019
Weighted-
Average
Exercise
Price
Per Share
Weighted-
Average
Remaining
Contractual
Term
(years)
Aggregate
Intrinsic
Value
(millions)
96.33
182.95
59.24
182.61
123.09
99.22
6.2
4.9
$
$
288
223
Shares
Underlying
Options
2,495,630
500,135
$
$
(578,093) $
(984) $
2,416,688
1,561,752
$
$
The weighted-average grant date fair value of options granted was $20.03, $18.05 and $13.25 per share for the years ended
December 31, 2019, 2018 and 2017, respectively. The total intrinsic value of stock options exercised was approximately $81 million,
$35 million and $41 million for the years ended December 31, 2019, 2018 and 2017, respectively.
Cash received from option exercises was approximately $34 million, $18 million and $23 million for the years ended December 31,
2019, 2018 and 2017, respectively. The tax benefits realized from options exercised were approximately $19 million, $9 million and
$16 million for the years ended December 31, 2019, 2018 and 2017, respectively.
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, 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.
100
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
Investees
Total
Balances, December 31, 2016
$
(100)
$
225
$
(millions)
(83)
$
(90) $
(22) $
(70)
Other comprehensive income before
reclassifications
Amounts reclassified from AOCI
Net other comprehensive income
Less other comprehensive income
attributable to noncontrolling interests
Balances, December 31, 2017
Other comprehensive income (loss) before
reclassifications
Amounts reclassified from AOCI
Net other comprehensive income (loss)
Impact of NEP deconsolidation(d)
Adoption of accounting standards updates
Balances, December 31, 2018
Other comprehensive income (loss) before
reclassifications
Amounts reclassified from AOCI
Net other comprehensive income (loss)
Less other comprehensive income
attributable to noncontrolling interests
Acquisition of Gulf Power (see Note 8)
—
32 (a)
32
9
(77)
—
26 (a)
26
3
(7)
(55)
—
29 (a)
29
—
(1)
Balances, December 31, 2019
$
(27)
$
127
(36) (b)
91
—
316
(12)
1 (b)
(11)
—
(312)
(7)
20
(2) (b)
18
—
—
11
46
(2) (c)
44
—
(39)
(14)
(3) (c)
(17)
—
(9)
(65)
(46)
(3) (c)
(49)
—
—
23
—
23
2
(69)
(31)
—
(31)
37
—
(63)
22
—
22
1
—
$
(114)
$
(42) $
2
—
2
—
(20)
4
—
4
18
—
2
1
—
1
—
—
3
198
(6)
192
11
111
(53)
24
(29)
58
(328)
(188)
(3)
24
21
1
(1)
$ (169)
————————————
(a) Reclassified to interest expense in NEE's consolidated statements of income. See Note 4 - Income Statement Impact of Derivative Instruments.
(b) Reclassified to gains on disposal of investments and other property - net in NEE's consolidated statements of income.
(c) Reclassified to other net periodic benefit income in NEE's consolidated statements of income.
(d) Reclassified and included in gain on NEP deconsolidation. See Note 1 - NextEra Energy Partners, LP.
101
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
12. Debt
Long-term debt consists of the following:
Maturity
Date
2019
Balance
(millions)
December 31,
Weighted-
Average
Interest Rate
2018
Weighted-
Average
Interest Rate
Balance
(millions)
2020-2049
$
12,005
4.46% $
10,626
FPL:
First mortgage bonds - fixed
Storm-recovery bonds - fixed
Pollution control, solid waste disposal and industrial development
revenue bonds - primarily variable(a)
Senior unsecured notes - variable(b)(c)
Unamortized debt issuance costs and discount
Total long-term debt of FPL
Less current portion of long-term debt
Long-term debt of FPL, excluding current portion
GULF POWER:
Senior unsecured notes - fixed
Other long-term debt - primarily variable(a)
Unamortized debt issuance costs and discount
Total long-term debt of Gulf Power
Less current portion of long-term debt
Long-term debt of Gulf Power, excluding current portion
NEER:
NextEra Energy Resources:
Senior secured limited-recourse long-term debt - primarily variable(c)(d)
Other long-term debt - primarily variable(c)(d)
NEET - long-term debt - primarily fixed(d)
Unamortized debt issuance costs and premium - net
Total long-term debt of NEER
Less current portion of long-term debt
Long-term debt of NEER, excluding current portion
NEECH:
Debentures - fixed(d)
Debentures - variable(c)
Debentures, related to NEE's equity units - fixed
Junior subordinated debentures - primarily fixed(d)
Japanese yen denominated long-term debt - primarily variable(c)(d)(f)
Australian dollar denominated long-term debt - fixed(f)
Other long-term debt - fixed
Other long-term debt - variable(c)
Unamortized debt issuance costs and discount
Total long-term debt of NEECH
Less current portion of long-term debt
Long-term debt of NEECH, excluding current portion
2020-2049
2022-2069
2020-2044
2021-2049
2023-2049
2024-2040
2021-2049
2020-2029
2020-2022
2024
2057-2079
2020-2030
2026
2020-2021
2021
4.60%
5.26%
2.04%
2.40%
4.38%
2.57%
3.73%
3.21%
3.11%
1.65%
4.99%
3.10%
1.95%
—
1,076
1,236
(156)
14,161
30
14,131
990
709
(14)
1,685
175
1,510
3,419
440 (e)
837
(74)
4,622
215
4,407
9,550
1,375
1,500
4,643
645
351
524
750
(139)
19,199
1,704
17,495
37,543
74
1,022
193
(132)
11,783
95
11,688
—
—
—
—
—
—
4,193
601
325
(95)
5,024
602
4,422
4,300
2,341
1,500
3,456
637
—
543
—
(86)
12,691
2,019
10,672
26,782
1.67%
2.18%
4.17%
1.93%
3.79%
3.78%
3.50%
3.05%
3.00%
2.10%
5.13%
3.10%
2.59%
2.00%
2.60%
$
Total long-term debt
______________________
$
(a)
(b)
(c)
(d)
(e)
(f)
Includes variable rate tax exempt bonds that permit individual bondholders to tender the bonds for purchase at any time prior to maturity. In the event these variable
rate tax exempt 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 or Gulf Power, as the case may be, would be required to purchase the variable rate tax exempt bonds. At December 31, 2019,
variable rate tax exempt bonds totaled approximately $948 million at FPL and $269 million at Gulf Power. All variable rate tax exempt bonds tendered for purchase
have been successfully remarketed. FPL's and Gulf Power's syndicated revolving credit facilities, as the case may be, are available to support the purchase of the
variable rate tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent. Gulf Power's remaining debt is primarily variable
which is based on an underlying index plus a margin.
Includes approximately $236 million of floating rate notes that permit individual noteholders to require repayment prior to maturity. FPL’s syndicated revolving credit
facilities are available to support the purchase of the senior unsecured notes.
Variable rate is based on an underlying index plus a specified margin.
Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 4.
Excludes approximately $463 million classified as held for sale, which is included in current other liabilities on NEE's consolidated balance sheets. See Note 1 -
Disposal of Businesses/Assets.
Foreign currency contracts have been entered into with respect to these debt issuances. See Note 4.
102
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 $2,124 million, $4,323 million, $4,134 million, $1,700 million
and $3,380 million for 2020, 2021, 2022, 2023 and 2024, respectively. The respective amounts for FPL are approximately $30
million, $68 million, $1,120 million, $537 million and $672 million.
At December 31, 2019 and 2018, short-term borrowings had a weighted-average interest rate of 1.95% (1.80% for FPL) and 2.95%
(2.87% for FPL), respectively. Subsidiaries of NEE, including FPL, had credit facilities with available capacity at December 31, 2019
of approximately $10.8 billion ($3.6 billion for FPL), of which approximately $10.7 billion ($3.6 billion for FPL) relate to revolving line
of credit facilities and $0.1 billion (none for FPL) relate to letter of credit facilities. Certain of the revolving line of credit facilities
provide for the issuance of letters of credit at December 31, 2019 of up to approximately $2.3 billion ($0.6 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. In January 2020, FPL repaid commercial paper of approximately $1.2
billion with proceeds from a capital contribution from NEE.
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 subsidiaries within the NEER segment.
In August 2018, NEECH completed a remarketing of approximately $700 million aggregate principal amount of its Series H
Debentures due September 1, 2020 (Series H Debentures) that were issued in September 2015 as components of equity units
issued concurrently by NEE (September 2015 equity units). The Series H Debentures are fully and unconditionally guaranteed by
NEE. In connection with the remarketing of the Series H Debentures, the interest rate on the Series H Debentures was reset to
3.342% per year, and interest is payable on March 1 and September 1 of each year, commencing September 1, 2018. In connection
with the settlement of the contracts to purchase NEE common stock that were issued as components of the September 2015 equity
units, in the third quarter of 2018, NEE issued 6,215,998 shares of common stock in exchange for $700 million.
In August 2019, NEECH completed a remarketing of $1.5 billion aggregate principal amount of its Series I Debentures due
September 1, 2021 (Series I Debentures) that were issued in August 2016 as components of equity units issued concurrently by
NEE (August 2016 equity units). The Series I Debentures are fully and unconditionally guaranteed by NEE. In connection with the
remarketing of the Series I Debentures, the interest rate on the Series I Debentures was reset to 2.403% per year, and interest is
payable on March 1 and September 1 of each year, commencing September 1, 2019. In connection with the settlement of the
contracts to purchase NEE common stock that were issued as components of the August 2016 equity units, in the third quarter of
2019, NEE issued 9,543,000 shares of common stock in exchange for $1.5 billion.
In September 2019, 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 J Debenture due September 1, 2024, 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, 2022 (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 $224.12 to $280.15. If purchased on the final settlement date, as of December 31, 2019, the number of shares issued would
(subject to antidilution adjustments) range from 0.2231 shares if the applicable market value of a share of common stock is less
than or equal to $224.12 to 0.1785 shares if the applicable market value of a share is equal to or greater than $280.15, with applicable
market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August
29, 2022. Total annual distributions on the equity units are at the rate of 4.872%, consisting of interest on the debentures (2.10%
per year) and payments under the stock purchase contracts (2.772% per year). The interest rate on the debentures is expected to
be reset on or after March 1, 2022. 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.
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.
103
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
13. Asset Retirement Obligations
NEE's AROs relate primarily to decommissioning obligations of FPL's and NEER's nuclear units and to obligations for the
dismantlement of certain of NEER's wind and solar facilities. For NEE's rate-regulated operations, including FPL, the accounting
provisions result in timing differences in the recognition of legal asset retirement costs for financial reporting purposes and the
method the regulator allows for recovery in rates. See Note 1 - Rate Regulation and - Decommissioning of Nuclear Plants,
Dismantlement of Plants and Other Accrued Asset Removal Costs.
A rollforward of NEE's and FPL's AROs is as follows:
Balances, December 31, 2017
Liabilities incurred
Accretion expense
Liabilities settled
Revision in estimated cash flows - net
Impact of NEP deconsolidation
Balances, December 31, 2018
Liabilities incurred
Accretion expense
Liabilities settled
Revision in estimated cash flows - net
Additions from acquisitions
Balances, December 31, 2019
______________________
NEE
FPL
(millions)
$
3,031
$
49
158
(26) (a)
4
(81) (b)
3,135
100
172
(65) (a)
32 (c)
132 (d)
3,506 (e) $
$
2,047
—
101
(1)
—
—
2,147
1
107
(1)
14 (c)
—
2,268
(a)
(b)
(c)
(d)
(e)
Primarily reflects sales of ownership interests to subsidiaries of NEP. See Note 1 - Disposal of Businesses/Assets.
See Note 1 - NextEra Energy Partners, LP.
Includes an increase of approximately $75 million for additional estimated ash pond closure costs at Scherer, partly offset by a decrease of approximately $71
million due to the approval of Turkey Point Units Nos. 3 and 4 license renewals for an additional 20 years.
See Note 8 for 2019 acquisitions.
Includes the current portion of AROs of approximately $49 million, which is included in other current liabilities on NEE's consolidated balance sheets.
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 5 - Special Use Funds):
Balances, December 31, 2019
Balances, December 31, 2018
NEE
FPL
(millions)
$
$
6,880
5,818
$
$
4,697
3,987
NEE and FPL have identified but not recognized ARO liabilities related to the majority of their electric transmission and distribution
assets and pipelines 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
related 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.
14. Leases
NEE has operating and finance leases primarily related to purchased power agreements, land use agreements that convey exclusive
use of the land during the arrangement for certain of its renewable energy projects and substations, buildings and equipment.
Operating and finance leases primarily have fixed payments with expected expiration dates ranging from 2020 to 2052, with the
exception of operating leases related to three land use agreements with an expiration date of 2106, some of which include options
to extend the leases up to 27 years and some have options to terminate at NEE's discretion. At December 31, 2019, NEE’s ROU
assets and lease liabilities for operating leases totaled approximately $499 million and $498 million, respectively; the respective
amounts at December 31, 2018 were $133 million and $141 million. At December 31, 2019, NEE’s ROU assets and lease liabilities
for finance leases totaled approximately $62 million and $56 million, respectively; the respective amounts at December 31, 2018
were $68 million and $63 million. NEE’s lease liabilities at December 31, 2019 and 2018 were calculated using a weighted-average
incremental borrowing rate at the lease inception of 3.73% and 4.31%, respectively, for operating leases and 3.15% and 2.72%,
respectively, for finance leases, and a weighted-average remaining lease term of 31 years and 19 years, respectively, for operating
leases and 14 years and 10 years, respectively, for finance leases. At December 31, 2019, expected lease payments over the
remaining terms of the leases were approximately $981 million with no one year being material. NEE's operating lease cost for the
104
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
year ended December 31, 2019 totaled approximately $91 million. During the year ended December 31, 2019, NEE's ROU assets
obtained in exchange for operating lease obligations totaled approximately $450 million and primarily relate to leases acquired with
the Gulf Power and Trans Bay acquisitions (see Note 8). Other operating and finance lease-related amounts were not material to
NEE's consolidated statements of income or cash flows for the periods presented.
NEE has sales-type leases primarily related to a natural gas and oil electric generation facility and certain battery storage facilities
that sell their electric output under power sales agreements to third parties which provide the customers the ability to dispatch the
facilities. At December 31, 2019 and 2018, NEE recorded a net investment in sales-type leases of approximately $50 million and
$69 million, respectively, and losses at commencement of sales-type leases due to the variable nature of the lease payments of
approximately $20 million for the year ended December 31, 2018, which are recorded in gains on disposal of businesses/assets -
net in NEE's consolidated statements of income. At December 31, 2019, the power sales agreements have expiration dates from
2021 to 2043 and NEE expects to receive approximately $150 million of lease payments over the remaining terms of the power
sales agreements with no one year being material.
15. 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 and Gulf Power include, among other things, the cost for construction of additional facilities and
equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities. At NEER, capital
expenditures include, among other things, the cost, including capitalized interest, for construction and development of wind and
solar projects, the procurement of nuclear fuel and the cost to maintain existing rate-regulated transmission facilities, as well as
equity contributions to joint ventures for the development and construction of natural gas pipeline assets and a rate-regulated
transmission facility.
At December 31, 2019, estimated capital expenditures for 2020 through 2024 for which applicable internal approvals (and also, if
required, regulatory approvals such as FPSC approvals for FPL and Gulf Power) have been received were as follows:
2020
2021
2022
2023
2024
Total
FPL:
Generation:(a)
New(b)
Existing
Transmission and distribution(c)
Nuclear fuel
General and other
Total
Gulf Power
NEER:
Wind(d)
Solar(e)
Nuclear, including nuclear fuel
Natural gas pipelines(f)
Rate-regulated transmission
Other
Total
______________________
$
1,345
$
$
$
$
$
$
$
855
3,150
205
730
6,285
800
3,265
945
170
600
300
580
$
$
$
$
730
970
3,905
220
480
6,305
770
20
230
180
195
110
50
(millions)
$
$
$
$
555
930
4,030
165
440
6,120
645
10
5
170
20
5
70
$
$
$
$
500
925
4,120
120
380
6,045
650
10
5
130
—
—
60
— $
$
$
$
840
4,885
145
470
6,340
680
10
—
150
—
—
60
3,130
4,520
20,090
855
2,500
31,095
3,545
3,315
1,185
800
815
415
820
$
5,860
$
785
$
280
$
205
$
220
$
7,350
Includes AFUDC of approximately $45 million, $70 million, $40 million, and $20 million for 2020 through 2023, respectively.
Includes land, generation structures, transmission interconnection and integration and licensing.
Includes AFUDC of approximately $40 million, $50 million, $40 million, $25 million and $20 million for 2020 through 2024, respectively.
(a)
(b)
(c)
(d) Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 4,400 MW.
(e)
(f)
Includes capital expenditures for new solar projects and related transmission totaling approximately 1,180 MW.
Construction of two natural gas pipelines are subject to certain conditions, including applicable regulatory approvals. In addition, completion of another natural gas
pipeline is subject to final permitting.
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 firm commitments under long-term contracts primarily for the transportation of natural gas and coal
with expiration dates through 2042.
105
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
At December 31, 2019, NEER has entered into contracts with expiration dates ranging from late February 2020 through 2033
primarily for the purchase of wind turbines, wind 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, and has made commitments for
the construction of natural gas pipelines and a rate-regulated transmission facility. Approximately $3.8 billion of related commitments
are included in the estimated capital expenditures table in Commitments above. In addition, NEER has contracts primarily for the
transportation and storage of natural gas with expiration dates ranging from March 2020 through 2040.
The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2019, were
estimated as follows:
FPL(a)
NEER(b)(c)(d)
_______________________
2020
2021
2022
2023
2024
Thereafter
$
$
1,035
3,355
$
$
1,005
395
$
$
(millions)
985
255
$
$
975
130
$
$
970
140
$
$
11,625
1,415
(a)
(b)
(c)
(d)
Includes approximately $385 million, $415 million, $415 million, $410 million, $410 million and $6,765 million in 2020 through 2024 and thereafter, respectively, of
firm commitments related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection, LLC. The charges associated with these
agreements are recoverable through the fuel clause and totaled approximately $316 million and $303 million for the years ended December 31, 2019 and 2018,
respectively, of which $108 million and $95 million, respectively, were eliminated in consolidation at NEE.
Includes approximately $70 million, $70 million, $70 million, $70 million and $1,110 million for 2021 through 2024 and thereafter, respectively, of firm commitments
related to a natural gas transportation agreement with a joint venture, in which NEER has a 31% equity investment, that is constructing a natural gas pipeline.
These firm commitments are subject to the completion of construction of the pipeline which is expected in 2020.
Includes an approximately $110 million commitment to invest in technology investments through 2029.
Includes approximately $60 million, $20 million, $20 million, $20 million, $10 million and $15 million for 2020 through 2024 and thereafter, respectively, of joint
obligations of NEECH and NEER.
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 $450 million of private liability insurance per site, which is the maximum obtainable, and
participates in a secondary financial protection system, which provides up to $13.5 billion of liability insurance coverage per incident
at any nuclear reactor in the U.S. Under the secondary financial protection system, NEE is subject to retrospective assessments
of up to $1.1 billion ($550 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the U.S., payable at a
rate not to exceed $164 million ($82 million for FPL) per incident per year. NEE and FPL are contractually entitled to recover a
proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2,
which approximates $16 million, $41 million and $20 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, except for Duane Arnold which has a sublimit of $500 million. NEE participates in co-insurance of 10%
of the first $400 million of losses per site per occurrence. 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 $174 million ($106 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, $4 million and $4 million, plus any applicable taxes,
respectively.
Due to the high cost and limited coverage available from third-party insurers, NEE does not have property insurance coverage for
a substantial portion of either its transmission and distribution property or natural gas pipeline assets. If either FPL's or Gulf Power's
future storm restoration costs exceed their respective storm reserve, FPL and Gulf Power may recover their storm restoration costs,
subject to prudence review by the FPSC, through surcharges approved by the FPSC or through securitization provisions pursuant
to Florida law. See Note 1 - Storm Fund, Storm Reserve and Storm Cost Recovery.
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 Gulf Power, would
be borne by NEE and either FPL or Gulf Power, and could have a material adverse effect on NEE's and FPL's financial condition,
results of operations and liquidity.
106
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
16. Segment Information
The table below presents information for NEE's reportable segments, FPL, a rate-regulated utility business, and NEER, which is
comprised of competitive energy and rate-regulated transmission businesses, as well as for Gulf Power, a rate-regulated utility
business acquired in January 2019. Corporate and Other represents other business activities and includes eliminating entries.
During the fourth quarter of 2019, NEET, which was previously reported in Corporate and Other, was moved to the NEER segment.
Prior year amounts for NEER and Corporate and Other were adjusted to reflect this segment change. See Note 2 for information
regarding NEE's and FPL's operating revenues.
NEE's segment information is as follows:
Operating revenues
Operating expenses - net
Interest expense
Interest income
Depreciation and amortization
Equity in earnings (losses) of equity method investees
Income tax expense (benefit)(c)
Net income (loss)
Net income (loss) attributable to NEE
Capital expenditures, independent power and other investments and
nuclear fuel purchases
Property, plant and equipment
Accumulated depreciation and amortization
Total assets
Investment in equity method investees
FPL
Gulf Power(a)
2019
NEER(b)
(millions)
Corp. and
Other
NEE
Consolidated
$
$
$
$
$
$
$
$
$
$
$
$
$
$
12,192
8,890
594
5
2,524
$
$
$
$
$
1,487
1,216
55
3
247
$
$
$
$
$
— $
— $
441
2,334
2,334
5,755
59,027
13,953
57,188
$
$
$
$
$
$
$
42
180
180
729
6,393
1,630
5,855
$
$
$
$
$
$
$
— $
— $
5,639
3,635
873
38
1,387
67
162
1,426
1,807
6,505
41,499
9,457
51,516
7,453
$
$
$
$
$
$
$
$
$
$
$
$
$
$
(114) $
110
727
8
58
$
$
$
$
(1) $
(197) $
(552) $
(552) $
4,473
259
128
3,132
$
$
$
$
— $
19,204
13,851
2,249
54
4,216
66
448
3,388
3,769
17,462
107,178
25,168
117,691
7,453
Operating revenues
Operating expenses - net
Interest expense
Interest income
Depreciation and amortization
Equity in earnings of equity method investees
Income tax expense (benefit)(c)
Net income (loss)
Net income (loss) attributable to NEE
Capital expenditures, independent power and other investments and nuclear fuel
purchases
Property, plant and equipment
Accumulated depreciation and amortization
Total assets
Investment in equity method investees
FPL
NEER(b)(d)
2018
(millions)
Corp. and
Other
NEE
Consolidated
$
$
$
$
$
$
$
$
$
$
$
$
$
$
11,862
8,708
541
4
2,633
$
$
$
$
$
— $
539
2,171
2,171
5,135
54,717
13,218
53,484
$
$
$
$
$
$
$
— $
4,984
3,616
595
40
1,230
321
1,196
3,842
4,704
7,189
37,063
8,461
44,509
6,521
$
$
$
$
$
$
$
$
$
$
$
$
$
$
(119) $
123
362
7
48
37
$
$
$
$
$
(159) $
(237) $
(237) $
680
303
70
5,709
227
$
$
$
$
$
16,727
12,447
1,498
51
3,911
358
1,576
5,776
6,638
13,004
92,083
21,749
103,702
6,748
107
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Operating revenues
Operating expenses - net
Interest expense
Interest income
Depreciation and amortization
Equity in earnings of equity method investees
Income tax expense (benefit)(c)
Net income
Net income attributable to NEE
Capital expenditures, independent power and other investments and nuclear fuel
purchases
Property, plant and equipment
Accumulated depreciation and amortization
Total assets
Investment in equity method investees
_________________________
2017
FPL
NEER(b)
Corp. and
Other
NEE
Consolidated
$
$
$
$
$
$
$
$
$
$
$
$
$
$
11,972
8,582
481
2
940
$
$
$
$
$
— $
1,106
1,880
1,880
5,291
51,915
12,791
50,254
$
$
$
$
$
$
$
— $
(millions)
5,275
4,345
815
72
1,414
136
$
$
$
$
$
$
(2,013) $
2,940
2,997
5,415
41,567
8,460
46,611
2,173
$
$
$
$
$
$
$
(74) $
(927) $
262
7
3
5
247
503
503
34
83
25
1,098
148
$
$
$
$
$
$
$
$
$
$
$
$
17,173
12,000
1,558
81
2,357
141
(660)
5,323
5,380
10,740
93,565
21,276
97,963
2,321
(a)
(b)
See Note 8 - Gulf Power Company.
Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy
Resources' subsidiaries. Residual NEECH corporate interest expense is included in Corporate and Other.
(c) NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes.
(d) NEP was deconsolidated from NEER in January 2018. See Note 1 - NextEra Energy Partners, LP.
108
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
17. 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 and Gulf Power. NEECH’s debentures and junior 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, 2019
Year Ended December 31, 2018
Year Ended December 31, 2017
NEE
(Guaran-
tor)
NEECH
Other(a)
NEE
Consoli-
dated
NEE
(Guaran-
tor)
NEECH
Other(a)
(millions)
NEE
Consoli-
dated
NEE
(Guaran-
tor)
NEECH
Other(a)
NEE
Consoli-
dated
Operating revenues
$
— $ 5,671
$13,533
$ 19,204
$
— $ 5,007
$ 11,720
$ 16,727
$
— $ 5,301
$ 11,872
$ 17,173
Operating expenses -
net
Interest expense
Equity in earnings of
subsidiaries
Equity in earnings of
equity method
investees
Gain on NEP
deconsolidation
Other income - net
Income (loss) before
income taxes
Income tax expense
(benefit)
Net income (loss)
Net loss attributable to
noncontrolling
interests
Net income (loss)
(209)
(3,669)
(9,973)
(13,851)
(196)
(3,652)
(8,599)
(12,447)
(175)
(3,273)
(8,552)
(12,000)
(3)
(1,596)
(650)
(2,249)
(17)
(940)
(541)
(1,498)
(3)
(1,074)
(481)
(1,558)
3,785
—
(3,785)
—
6,548
—
(6,548)
—
5,393
—
(5,393)
—
—
66
—
185
—
407
—
—
74
66
—
666
—
358
—
169
3,927
21
—
—
95
358
—
141
3,927
285
—
151
—
702
—
—
54
141
—
907
3,758
879
(801)
3,836
6,504
4,721
(3,873)
7,352
5,366
1,797
(2,500)
4,663
(11)
3,769
(21)
900
480
448
(134)
(1,281)
3,388
6,638
1,195
3,526
515
(4,388)
1,576
5,776
(14)
(1,719)
1,073
(660)
5,380
3,516
(3,573)
5,323
—
381
—
381
—
862
—
862
—
57
—
57
attributable to NEE
$ 3,769
$ 1,281
$ (1,281) $ 3,769
$ 6,638
$ 4,388
$ (4,388) $ 6,638
$ 5,380
$ 3,573
$ (3,573) $ 5,380
______________________
(a) Represents primarily FPL and consolidating adjustments.
Condensed Consolidating Statements of Comprehensive Income
Year Ended December 31, 2019
Year Ended December 31, 2018
Year Ended December 31, 2017
NEE
(Guaran-
tor)
NEECH
Other(a)
NEE
Consoli-
dated
NEE
(Guaran-
tor)
NEE
Consoli-
dated
NEE
(Guaran-
tor)
NEECH
Other(a)
NEE
Consoli-
dated
NEECH
Other(a)
(millions)
Comprehensive
income (loss)
attributable to
NEE
$
3,789
$ 1,340
$ (1,340) $ 3,789
$
6,667
$ 4,434
$ (4,434)
$ 6,667
$
5,561
$ 3,710
$ (3,710)
$ 5,561
______________________
(a) Represents primarily FPL and consolidating adjustments.
109
638
2,969
2,786
6,393
—
6,748
891
19,336
26,975
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed Consolidating Balance Sheets
December 31, 2019
December 31, 2018
NEE
(Guaran-
tor)
NEECH
Other(a)
NEE
Consoli-
dated
NEE
(Guaran-
tor)
(millions)
NEECH
Other(a)
NEE
Consoli-
dated
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property
$
170
$ 41,585
$ 65,423
$ 107,178
$
220
$ 37,145
$ 54,718
$
92,083
Accumulated depreciation and amortization
(111)
(9,473)
(15,584)
(25,168)
Total property, plant and equipment - net
CURRENT ASSETS
Cash and cash equivalents
Receivables
Other
Total current assets
OTHER ASSETS
59
1
81
16
98
32,112
49,839
82,010
515
1,489
2,633
4,637
84
1,237
1,352
2,673
600
2,807
4,001
7,408
(58)
162
(1)
292
5
296
(8,473)
(13,218)
(21,749)
28,672
41,500
70,334
525
1,771
1,425
3,721
114
906
1,356
2,376
Investment in subsidiaries
36,783
—
(36,783)
—
33,397
—
(33,397)
Investment in equity method investees
Goodwill
Other
—
1
404
7,453
1,217
6,899
—
2,986
9,313
Total other assets
37,188
15,569
(24,484)
7,453
4,204
16,616
28,273
—
1
937
6,748
587
5,890
—
303
12,509
34,335
13,225
(20,585)
TOTAL ASSETS
CAPITALIZATION
Common shareholders' equity
Noncontrolling interests
Redeemable noncontrolling interests
$
$
Long-term debt
Total capitalization
CURRENT LIABILITIES
Debt due within one year
Accounts payable
Other
Total current liabilities
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations
Deferred income taxes
Other
Total other liabilities and deferred credits
COMMITMENTS AND CONTINGENCIES
37,345
$ 52,318
$ 28,028
$ 117,691
$
34,793
$ 45,618
$ 23,291
$ 103,702
37,005
$ 11,050
$ (11,050) $
37,005
$
34,144
$
7,917
$
(7,917) $
34,144
—
—
—
37,005
—
3
167
170
—
(410)
580
170
4,355
487
21,901
37,793
2,961
2,755
2,817
8,533
1,072
2,956
1,964
5,992
—
—
15,642
4,592
2,079
873
2,198
5,150
2,385
5,815
10,086
18,286
4,355
487
37,543
79,390
5,040
3,631
5,182
13,853
3,457
8,361
12,630
24,448
—
—
—
34,144
—
32
168
200
—
(157)
606
449
3,269
468
15,094
26,748
9,579
1,730
2,364
13,673
988
2,778
1,431
5,197
—
—
11,688
3,771
1,351
624
1,715
3,690
2,147
4,746
8,937
15,830
3,269
468
26,782
64,663
10,930
2,386
4,247
17,563
3,135
7,367
10,974
21,476
TOTAL CAPITALIZATION AND LIABILITIES
$
37,345
$ 52,318
$ 28,028
$ 117,691
$
34,793
$ 45,618
$ 23,291
$ 103,702
______________________
(a) Represents primarily FPL and consolidating adjustments.
110
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed Consolidating Statements of Cash Flows
Year Ended December 31, 2019
Year Ended December 31, 2018
Year Ended December 31, 2017
NEE
(Guar-
antor)
NEECH
Other(a)
NEE
Consoli-
dated
NEE
(Guar-
antor)
NEE
Consoli-
dated
NEE
(Guar-
antor)
NEECH
Other(a)
NEE
Consoli-
dated
NEECH
Other(a)
(millions)
$ 2,769
$ 2,562
$ 2,824
$ 8,155
$3,401
$ 2,094
$ 1,098
$ 6,593
$1,968
$ 2,749
$ 1,741
$ 6,458
(7)
(6,509)
(10,946)
(17,462)
(132)
(7,735)
(5,137)
(13,004)
— (5,449)
(5,291)
(10,740)
NET CASH PROVIDED BY
OPERATING ACTIVITIES
CASH FLOWS FROM INVESTING
ACTIVITIES
Capital expenditures,
acquisitions, independent
power and other investments
and nuclear fuel purchases
Capital contributions from NEE
(1,876)
—
1,876
— (6,270)
—
6,270
—
(92)
—
92
—
Proceeds from sale of the fiber-
optic telecommunications
business
Sale of independent power and
other investments of NEER
Proceeds from sale or maturity
of securities in special use
funds and other investments
Purchases of securities in
special use funds and other
investments
Distributions from subsidiaries
and equity method investees
Other - net
Net cash used in investing
activities
CASH FLOWS FROM
FINANCING ACTIVITIES
—
—
—
1,163
—
—
—
1,163
—
—
—
1,617
—
—
—
1,617
—
—
1,454
178
—
—
1,454
178
—
1,279
2,729
4,008
—
1,178
2,232
3,410
9
1,221
1,977
3,207
—
(1,306)
(2,854)
(4,160)
— (1,330)
(2,403)
(3,733)
— (1,163)
(2,081)
(3,244)
—
103
—
150
—
21
— 4,466
637
(4,466)
274
12
(130)
241
637
123
—
7
7
195
—
18
7
220
(1,780)
(5,223)
(9,174)
(16,177)
(1,924)
(5,763)
(3,263)
(10,950)
(76)
(3,557)
(5,285)
(8,918)
Issuances of long-term debt
— 10,916
3,003
13,919
—
2,651
1,748
4,399
—
6,393
1,961
8,354
(5,292)
(200)
(5,492)
— (1,512)
(1,590)
(3,102)
— (5,907)
(873)
(6,780)
Retirements of long-term debt
Proceeds from differential
membership investors
Net change in commercial paper
Proceeds from other short-term
debt
Repayments of other short-term
debt
Payments to related parties
under CSCS agreement – net
Issuances of common stock - net
Proceeds from issuance of NEP
convertible preferred units -
net
—
—
—
—
—
—
1,494
—
Dividends on common stock
(2,408)
Contributions from (dividends to)
Net cash provided by (used in)
financing activities
Effects of currency translation on
cash, cash equivalents and
restricted cash
Net increase (decrease) in cash,
cash equivalents and
restricted cash
Cash, cash equivalents and
restricted cash at beginning of
year
Cash, cash equivalents and
1,604
(651)
—
(4,765)
(54)
—
—
—
—
417
200
—
—
—
—
—
1,604
(234)
200
(4,765)
(54)
—
—
—
—
—
1,494
718
—
—
(2,408)
(2,101)
1,841
1,493
—
(431)
1,841
1,062
5,665
—
5,665
(205)
(250)
(455)
(21)
—
—
—
—
—
—
—
(21)
718
—
—
—
—
—
—
55
—
(2,101)
(1,845)
1,414
—
—
—
—
—
548
—
(633)
(601)
—
1,419
1,414
1,419
450
450
(2)
—
—
—
—
(2)
—
55
548
(1,845)
633
(22)
—
(725)
(987)
2,966
1,894
3,873
(1,479)
2,402
6,711
7,634
(1,892)
1,214
3,566
2,888
—
4
—
4
—
(7)
—
(7)
—
26
—
26
2
309
(4,456)
(4,145)
(2)
(1,274)
4,546
3,270
—
432
22
454
NEE
Other - net
—
(73)
1,479
(1,479)
—
— (7,272)
7,272
—
—
(271)
(47)
(391)
(96)
(238)
(38)
(372)
(102)
(1)
533
4,721
5,253
1
1,807
175
1,983
1
1
1,375
153
1,529
$ 1,807
$
175
$ 1,983
restricted cash at end of year
$
1
$
842
$
265
$ 1,108
$
(1) $
533
$ 4,721
$ 5,253
$
______________________
(a) Represents primarily FPL and consolidating adjustments.
111
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Concluded)
18. Quarterly Data (Unaudited)
Condensed consolidated quarterly financial information is as follows:
March 31(a)
June 30(a)
September 30(a)
December 31(a)
(millions, except per share amounts)
NEE:
2019
Operating revenues(b)
Operating income(b)
Net income(b)
Net income attributable to NEE(b)
Earnings per share attributable to NEE - basic(c)
Earnings per share attributable to NEE - assuming dilution(c)
Dividends per share
$
$
$
$
$
$
$
4,075
1,135
606
680
1.42
1.41
1.25
$
$
$
$
$
$
$
4,970
1,747
1,139
1,234
2.58
2.56
1.25
$
$
$
$
$
$
$
5,572
1,593
798
879
1.82
1.81
1.25
$
$
$
$
$
$
$
4,588
878
844
975
2.00
1.99
1.25
High-low common stock sales prices
$195.55 - $168.66
$208.91 - $187.30
$233.45 - $201.06
$245.01 - $220.66
2018
Operating revenues(b)
Operating income(b)
Net income(b)(d)
Net income attributable to NEE(b)(d)
Earnings per share attributable to NEE - basic(c)(d)
Earnings per share attributable to NEE - assuming dilution(c)(d)
Dividends per share
$
$
$
$
$
$
$
3,857
1,059
3,834
4,431
9.41
9.32
1.11
$
$
$
$
$
$
$
4,063
1,146
687
781
1.66
1.61
1.11
$
$
$
$
$
$
$
4,416
968
941
1,005
2.12
2.10
1.11
$
$
$
$
$
$
$
4,390
1,107
314
422
0.88
0.88
1.11
High-low common stock sales prices
$164.41 - $145.10
$169.53 - $155.06
$175.65 - $163.52
$184.20 - $164.78
2019
2018
FPL:
Operating revenues(b)
Operating income(b)
Net income(b)
Operating revenues(b)
Operating income(b)
Net income(b)
______________________
$
$
$
$
$
$
2,618
857
588
2,620
707
484
$
$
$
$
$
$
3,158
854
663
2,908
921
626
$
$
$
$
$
$
3,491
973
683
3,399
917
654
$
$
$
$
$
$
2,925
617
400
2,935
609
407
(a)
(b)
(c)
(d)
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.
The sum of the quarterly amounts may not equal the total for the year due to rounding.
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.
First quarter of 2018 includes gain on the deconsolidation of NEP (see Note 1 - NextEra Energy Partners, LP).
112
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, 2019, 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, 2019.
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
113
Item 10. Directors, Executive Officers and Corporate Governance
PART III
The information required by this item will be included under the headings "Business of the Annual Meeting," "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 2020 Annual Meeting of Shareholders (NEE's Proxy Statement) and is incorporated herein by
reference, or is included in Item 1. Business - Information About Our Executive Officers.
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 or waivers of the Senior Financial
Executive Code which are required to be disclosed to shareholders under SEC rules will be disclosed on the NEE website at the
address listed 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 at December 31, 2019 is as follows:
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)
Plan Category
Equity compensation plans approved by security holders
4,011,354 (a) $
123.09 (b)
6,414,488 (c)
Equity compensation plans not approved by security holders
—
—
—
Total
__________________________________
4,011,354
$
123.09
6,414,488
(a)
Includes an aggregate of 2,416,688 outstanding options, 1,422,352 unvested performance share awards (at maximum payout), 22,446 deferred fully vested
performance shares and 117,936 deferred stock awards (including future reinvested dividends) under the NextEra Energy, Inc. Amended and Restated 2011 Long
Term Incentive Plan and former LTIP, and 31,932 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)
Includes 5,939,880 shares under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan and 474,608 shares under the NextEra Energy,
Inc. 2017 Non-Employee Directors Stock 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.
114
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,
2019 and 2018. The amounts presented below reflect allocations from NEE for FPL's portion of the fees, as well as amounts billed
directly to FPL.
Audit fees(a)
Audit-related fees(b)
Tax fees(c)
All other fees(d)
Total
______________________
2019
2018
$
3,621,000 $
3,895,000
380,000
2,097,000
15,000
84,000
256,000
7,000
$
6,113,000 $
4,242,000
(a)
(b)
(c)
(d)
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, and consents.
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 relate to audits of subsidiary financial statements and attestation
services.
Tax fees consist of fees billed for professional services rendered for tax compliance, tax advice and tax planning. In 2019 and 2018, approximately $2,069,000
and $36,000, respectively, was paid related to tax compliance services. In 2019, these fees primarily related to research and development tax credit compliance
services. All other tax fees in 2019 and in 2018 related to tax advice and planning services.
All other fees consist of fees for products and services other than the services reported under the other named categories. In 2019 and 2018, 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 2019
and 2018, 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).
115
PART IV
Item 15. Exhibits, Financial Statement Schedules
(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 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
Page(s)
56
57
58
60
61
62
63
64
65
66
67
68
69 - 112
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
*2(a)
*2(b)
*3(i)a
*3(i)b
*3(ii)a
*3(ii)b
Description
Stock Purchase Agreement by and among The Southern Company, 700 Universe,
LLC and NextEra Energy, Inc. dated as of May 20, 2018 (filed as Exhibit 2(a) to Form
8-K dated May 23, 2018, File No. 1-8841)
Stock Purchase Agreement by and among NUI Corporation, Southern Company Gas,
700 Universe, LLC and NextEra Energy, Inc. dated as of May 20, 2018 (filed as Exhibit
2(b) to Form 8-K dated May 23, 2018, File No. 1-8841)
Restated Articles of Incorporation of NextEra Energy, Inc. (filed as Exhibit 3(i)(b) to Form
8-K dated May 21, 2015, File No. 1-8841)
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)
Amended and Restated Bylaws of NextEra Energy, Inc., effective October 14, 2016 (filed
as Exhibit 3(ii)(b) to Form 8-K dated October 14, 2016, File No. 1-8841)
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)
NEE
x
FPL
x
x
x
x
x
116
Exhibit
Number
*4(a)
*4(b)
*4(c)
*4(d)
*4(e)
*4(f)
Description
Mortgage and Deed of Trust dated as of January 1, 1944, as amended, 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-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(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(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 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; 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; Exhibit 4 to Form 8-K dated November 19, 2015, File No. 2-27612; Exhibit 4
(b) to Form 10-K dated December 31, 2017, File No. 2-27612; Exhibit 4(a) to Form 10-
Q dated March 31, 2018, File No. 2-27612; Exhibit 4(j), File No. 333-226056,
333-226056-01 and 333-226056-02; Exhibit 4(k), File No. 333-226056, 333-226056-01
and 333-226056-02; Exhibit 4(a) to Form 10-Q dated March 31, 2019, File No. 2-27612;
and Exhibit 4(f) to Form 10-Q dated September 30, 2019, File No. 2-27612)
Indenture (For Unsecured Debt Securities), dated as of November 1, 2017, between
Florida Power & Light Company and The Bank of New York Mellon (as Trustee) (filed as
Exhibit 4(a) to Form 8-K dated November 6, 2017, File No. 2-27612)
Officer's Certificate of Florida Power & Light Company, dated June 15, 2018, creating
the Floating Rate Notes, Series due June 15, 2068 (filed as Exhibit 4 to Form 8-K dated
June 15, 2018, File No. 2-27612)
Officer's Certificate of Florida Power & Light Company, dated November 14, 2018,
creating the Floating Rate Notes, Series due November 14, 2068 (filed as Exhibit 4 to
Form 8-K dated November 14, 2018, File No. 2-27612)
Officer's Certificate of Florida Power & Light Company, dated March 27, 2019, creating
the Floating Rate Notes, Series due March 27, 2069 (filed as Exhibit 4(b) to Form 8-K
dated March 27, 2019, File No. 2-27612)
Officer's Certificate of Florida Power & Light Company, dated May 7, 2019, creating the
Floating Rate Notes, Series due May 6, 2022 (filed as Exhibit 4 to Form 8-K dated
May 7, 2019, File No. 2-27612)
117
NEE
x
FPL
x
x
x
x
x
x
x
x
x
x
x
Exhibit
Number
*4(g)
*4(h)
*4(i)
*4(j)
*4(k)
*4(l)
*4(m)
*4(n)
*4(o)
*4(p)
*4(q)
*4(r)
*4(s)
*4(t)
*4(u)
*4(v)
*4(w)
*4(x)
Description
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)
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)
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)
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)
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)
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)
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)
Letter, dated August 9, 2018, from NextEra Energy Capital Holdings, Inc. to The Bank
of New York Mellon, as trustee, setting forth certain terms of the Series H Debentures
due September 1, 2020, effective August 9, 2018 (filed as Exhibit 4(b) to Form 8-K dated
August 9, 2018, File No. 1-8841)
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)
Letter, dated August 8, 2019, from NextEra Energy Capital Holdings, Inc. to The Bank
of New York Mellon, as trustee, setting forth certain terms of the Series I Debentures due
September 1, 2021 effective August 8, 2019 (filed as Exhibit 4(b) to Form 8-K dated
August 8, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated April 28, 2017,
creating the 3.55% Debentures, Series due May 1, 2027 (filed as Exhibit 4 to Form 8-K
dated April 28, 2017, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated December 14, 2017,
creating the 2.80% Debentures, Series due January 15, 2023 (filed as Exhibit 4 to Form
8-K dated December 14, 2017, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated May 4, 2018, creating
the Floating Rate Debentures, Series due May 4, 2021 (filed as Exhibit 4 to Form 8-K
dated May 4, 2018, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated August 28, 2018,
creating the Floating Rate Debentures, Series due August 28, 2021 (filed as Exhibit 4
(b) to Form 8-K dated August 28, 2018, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated February 27, 2019,
creating the 3.20% Debentures, Series due February 25, 2022 (filed as Exhibit 4(b) to
Form 8-K dated February 27, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated February 27, 2019,
creating the Floating Rate Debentures, Series due February 25, 2022 (filed as Exhibit 4
(a) to Form 8-K dated February 27, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated March 6, 2019,
creating the 3.30% Debentures, Series due August 15, 2022 (filed as Exhibit 4(a) to
Form 8-K dated March 6, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated March 27, 2019,
creating the Floating Rate Debentures, Series due September 28, 2020 (filed as Exhibit
4(a) to Form 8-K dated March 27, 2019, File No. 1-8841)
118
NEE
x
FPL
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Exhibit
Number
*4(y)
*4(z)
*4(aa)
*4(bb)
*4(cc)
*4(dd)
*4(ee)
*4(ff)
*4(gg)
*4(hh)
*4(ii)
*4(jj)
*4(kk)
*4(ll)
*4(mm)
Description
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated April 4, 2019, creating
the 2.90% Debentures, Series due April 1, 2022 (filed as Exhibit 4(a) to Form 8-K dated
April 4, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated April 4, 2019, creating
the 3.15% Debentures, Series due April 1, 2024 (filed as Exhibit 4(b) to Form 8-K dated
April 4, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated April 4, 2019, creating
the 3.25% Debentures, Series due April 1, 2026 (filed as Exhibit 4(c) to Form 8-K dated
April 4, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated April 4, 2019, creating
the 3.50% Debentures, Series due April 1, 2029 (filed as Exhibit 4(d) to Form 8-K dated
April 4, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 9, 2019,
creating the Series J Debentures due September 1, 2024 (filed as Exhibit 4(e) to Form
10-Q dated September 30, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated October 3, 2019,
creating the 2.75% Debentures, Series due November 1, 2029 (filed as Exhibit 4 to Form
8-K dated October 3, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated October 7, 2019,
creating the 1.95% Debentures, Series due September 1, 2022 (filed as Exhibit 4 to Form
8-K dated October 7, 2019, File No. 1-8841)
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)
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)
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)
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)
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)
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 (filed as Exhibit 4 (cc) to Form 10-K for the year ended
December 31, 2016, File No. 1-8841)
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)
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)
119
NEE
x
FPL
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Exhibit
Number
*4(nn)
*4(oo)
*4(pp)
*4(qq)
*4(rr)
*4(ss)
*4(tt)
*4(uu)
*4(vv)
*4(ww)
*4(xx)
*4(yy)
4(zz)
*10(a)
*10(b)
Description
Amendment, dated November 9, 2016, to the Replacement Capital Covenant, dated
June 12, 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
(filed as Exhibit 4(hh) to Form 10-K for the year ended December 31, 2016, File No.
1-8841)
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)
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)
Officer'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)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 29, 2017,
creating the Series L Junior Subordinated Debentures due September 29, 2057 (filed as
Exhibit 4(c) to Form 8-K dated September 29, 2017, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated November 2, 2017,
creating the Series M Junior Subordinated Debentures due December 1, 2077 (filed as
Exhibit 4(a) to Form 8-K dated November 2, 2017, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc.,
dated March 15, 2019, creating the Series N Junior Subordinated Debentures due
March 1, 2079 (filed as Exhibit 4 to Form 8-K dated March 15, 2019, File No. 1-8841)
Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc.,
dated April 4, 2019, creating the Series O Junior Subordinated Debentures due
May 1, 2079 (filed as Exhibit 4(e) to Form 8-K dated April 4, 2019, File No. 1-8841)
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)
Purchase Contract Agreement, dated as of September 1, 2019, between NextEra Energy,
Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4
(c) to Form 10-Q for the quarter ended September 30, 2019, File No. 1-8841)
Pledge Agreement, dated as of September 1, 2019, 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(d) to Form 10-Q for the quarter ended September 30, 2019, File No.
1-8841)
Senior Note Indenture dated as of January 1, 1998, between Gulf Power Company and
Wells Fargo Bank, National Association, as Successor Trustee, and certain indentures
supplemental thereto (filed as Exhibit 4.1 to Form 8-K dated June 17, 1998, File No.
0-2429; Exhibit 4.2 to Form 8-K dated April 6, 2010, File No. 1-31737; Exhibit 4.2 to Form
8-K dated September 9, 2010, File No. 1-31737; Exhibit 4.2 to Form 8-K dated May 15,
2012, File No. 1-31737; Exhibit 4.2 to Form 8-K dated June 10, 2013, File No. 1-31737;
Exhibit 4.2 to Form 8-K dated September 16, 2014, File No. 1-31737; and Exhibit 4.2 to
Form 8-K dated May 15, 2017, File No. 1-31737)
Description of Securities Registered Pursuant to Section 12 of the Securities Exchange
Act of 1934
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)
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)
120
NEE
x
FPL
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Exhibit
Number
*10(c)
*10(d)
*10(e)
*10(f)
*10(g)
*10(h)
*10(i)
*10(j)
*10(k)
*10(l)
Description
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)
Appendix A1 (revised as of March 16, 2016) to the NextEra Energy, Inc. Supplemental
Executive Retirement Plan (filed as Exhibit 10(d) to Form 10-K dated December 31, 2017,
File No. 1-8841)
Appendix A2 (revised as of October 1, 2017) to the NextEra Energy, Inc. Supplemental
Executive Retirement Plan (filed as Exhibit 10(e) to Form 10-K dated December 31, 2017,
File No. 1-8841)
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)
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)
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)
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)
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)
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(c) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841)
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)
*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(b) to Form 10-Q for the quarter ended March 31, 2018, File No. 1-8841)
*10(n)
*10(o)
*10(p)
*10(q)
*10(r)
*10(s)
*10(t)
*10(u)
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)
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(c) to Form 10-Q for the quarter ended March 31, 2018, File No. 1-8841)
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)
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)
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)
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)
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)
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)
121
NEE
x
FPL
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Exhibit
Number
*10(v)
*10(w)
*10(x)
*10(y)
*10(z)
*10(aa)
*10(bb)
*10(cc)
*10(dd)
*10(ee)
*10(ff)
*10(gg)
10(hh)
*10(ii)
*10(jj)
*10(kk)
*10(ll)
Description
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)
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(d) to Form 10-Q for the quarter ended March 31, 2018, File No. 1-8841)
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 James L. Robo (filed as Exhibit 10(dd) to Form 10-K for the year
ended December 31, 2009, File No. 1-8841)
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)
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)
NextEra Energy, Inc. Deferred Compensation Plan effective January 1, 2005 as amended
and restated through February 11, 2016 (filed as Exhibit 10(h) to Form 10-Q for the
quarter ended March 31, 2016, File No. 1-8841)
FPL Group, Inc. Deferred Compensation Plan, amended and restated effective
January 1, 2003 (filed as Exhibit 10(k)
the year ended
December 31, 2002, File No. 1-8841)
to Form 10-K
for
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)
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)
FPL Group, Inc. 2007 Non-Employee Directors Stock Plan (filed as Exhibit 99 to Form
S-8, File No. 333-143739)
NextEra Energy, Inc. 2017 Non-Employee Directors Stock Plan, as amended and
restated as of May 18, 2017 (filed as Exhibit 10 to Form 10-Q for the quarter ended
June 30, 2017, File No. 1-8841)
NextEra Energy, Inc. Non-Employee Director Compensation Summary effective
January 1, 2019 (filed as Exhibit 10(hh) to Form 10-K for the year ended
December 31, 2018, File No. 1-8841)
NextEra Energy, Inc. Non-Employee Director Compensation Summary effective
January 1, 2020
Form of Amended and Restated Executive Retention Employment Agreement effective
December 10, 2009 between FPL Group, Inc. and each of 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)
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)
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 for the year
ended December 31, 2009, File No. 1-8841)
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)
*10(mm)
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)
122
NEE
x
FPL
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Exhibit
Number
*10(nn)
*10(oo)
*10(pp)
*10(qq)
*10(rr)
10(ss)
10(tt)
*10(uu)
*10(vv)
*10(ww)
*10(xx)
21
23
31(a)
31(b)
31(c)
31(d)
32(a)
32(b)
Description
Form of 2012 409A Amendment to NextEra Energy, Inc. Executive Retention Employment
Agreement effective October 11, 2012 between NextEra Energy, Inc. and each of James
L. Robo, 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)
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)
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)
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)
Executive Retention Employment Agreement between NextEra Energy, Inc. and
Rebecca J. Kujawa dated as of March 1, 2019 (filed as Exhibit 10(b) to Form 10-Q for
the quarter ended March 31, 2019, File No. 1-8841)
Executive Retention Employment Agreement between NextEra Energy, Inc. and Donald
Moul dated as of January 1, 2020
Executive Retention Employment Agreement between NextEra Energy, Inc. and Ronald
Reagan dated as of January 1, 2020
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)
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)
NextEra Energy Partners, LP 2014 Long-Term Incentive Plan (filed as Exhibit 10.8 to
Form 8-K dated July 1, 2014, File No. 1-36518)
Form of Restricted Unit Award Agreement under the NextEra Energy Partners, LP 2014
Long-Term Incentive Plan (filed as Exhibit 10.17 to Form 10-K for the year ended
December 31, 2017, File No. 1-36518)
Subsidiaries of NextEra Energy, Inc.
Consent of Independent Registered Public Accounting Firm
Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy, Inc.
Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of NextEra Energy, Inc.
Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of Florida Power & Light
Company
Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of Florida Power & Light
Company
Section 1350 Certification of NextEra Energy, Inc.
Section 1350 Certification of Florida Power & Light Company
101.INS
XBRL Instance Document - the instance document does not appear in the Interactive
Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH Inline XBRL Schema Document
101.PRE Inline XBRL Presentation Linkbase Document
101.CAL
Inline XBRL Calculation Linkbase Document
101.LAB
Inline XBRL Label Linkbase Document
101.DEF
Inline XBRL Definition Linkbase Document
104
Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
______________________
*
Incorporated herein by reference
NEE
x
FPL
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
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.
123
Item 16. Form 10-K Summary
Not applicable
124
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. SIGNATURES
NextEra Energy, Inc.
JAMES L. ROBO
James L. Robo
Chairman, President and Chief Executive Officer
and Director
(Principal Executive Officer)
Date: February 14, 2020
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 14, 2020:
REBECCA J. KUJAWA
Rebecca J. Kujawa
Executive Vice President, Finance
and Chief Financial Officer
(Principal Financial Officer)
JAMES M. MAY
James M. May
Vice President, Controller and Chief Accounting
Officer
(Principal Accounting Officer)
Directors:
SHERRY S. BARRAT
Sherry S. Barrat
JAMES L. CAMAREN
James L. Camaren
KENNETH B. DUNN
Kenneth B. Dunn
NAREN K. GURSAHANEY
Naren K. Gursahaney
KIRK S. HACHIGIAN
Kirk S. Hachigian
TONI JENNINGS
Toni Jennings
AMY B. LANE
Amy B. Lane
DAVID L. PORGES
David L. Porges
RUDY E. SCHUPP
Rudy E. Schupp
JOHN L. SKOLDS
John L. Skolds
WILLIAM H. SWANSON
William H. Swanson
HANSEL E. TOOKES, II
Hansel E. Tookes, II
DARRYL L. WILSON
Darryl L. Wilson
125
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
ERIC E. SILAGY
Eric E. Silagy
President and Chief Executive Officer and Director
(Principal Executive Officer)
Date: February 14, 2020
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 14, 2020:
REBECCA J. KUJAWA
Rebecca J. Kujawa
Executive Vice President, Finance
and Chief Financial Officer and Director
(Principal Financial Officer)
Director:
JAMES L. ROBO
James L. Robo
KEITH FERGUSON
Keith Ferguson
Controller
(Principal Accounting Officer)
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, 2019.
126
Exhibit 31(a)
I, James L. Robo, certify that:
Rule 13a-14(a)/15d-14(a) Certification
1.
I have reviewed this Form 10-K for the annual period ended December 31, 2019 of NextEra Energy, Inc. (the registrant);
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material
fact necessary to make the statements made, in light of the circumstances under which such statements were made, not
misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in
all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods
presented in this report;
4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and
procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be
designed under our supervision, to ensure that material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in
which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting
to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial
reporting and the preparation of financial statements for external purposes in accordance with generally accepted
accounting principles;
(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report
our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period
covered by this report based on such evaluation; and
(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during
the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report)
that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial
reporting; and
5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons
performing the equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial
reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and
report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in
the registrant's internal control over financial reporting.
Date: February 14, 2020
JAMES L. ROBO
James L. Robo
Chairman, President and Chief Executive Officer
of NextEra Energy, Inc.
Exhibit 31(b)
I, Rebecca J. Kujawa, certify that:
Rule 13a-14(a)/15d-14(a) Certification
1.
I have reviewed this Form 10-K for the annual period ended December 31, 2019 of NextEra Energy, Inc. (the registrant);
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material
fact necessary to make the statements made, in light of the circumstances under which such statements were made, not
misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in
all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods
presented in this report;
4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and
procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be
designed under our supervision, to ensure that material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in
which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting
to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial
reporting and the preparation of financial statements for external purposes in accordance with generally accepted
accounting principles;
(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report
our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period
covered by this report based on such evaluation; and
(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during
the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report)
that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial
reporting; and
5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons
performing the equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial
reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and
report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in
the registrant's internal control over financial reporting.
Date: February 14, 2020
REBECCA J. KUJAWA
Rebecca J. Kujawa
Executive Vice President, Finance and
Chief Financial Officer
of NextEra Energy, Inc.
Exhibit 31(c)
I, Eric E. Silagy, certify that:
Rule 13a-14(a)/15d-14(a) Certification
1.
I have reviewed this Form 10-K for the annual period ended December 31, 2019 of Florida Power & Light Company (the
registrant);
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material
fact necessary to make the statements made, in light of the circumstances under which such statements were made, not
misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in
all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods
presented in this report;
4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and
procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be
designed under our supervision, to ensure that material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in
which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting
to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial
reporting and the preparation of financial statements for external purposes in accordance with generally accepted
accounting principles;
(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report
our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period
covered by this report based on such evaluation; and
(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during
the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report)
that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial
reporting; and
5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons
performing the equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial
reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and
report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in
the registrant's internal control over financial reporting.
Date: February 14, 2020
ERIC E. SILAGY
Eric E. Silagy
President and Chief Executive Officer
of Florida Power & Light Company
Exhibit 31(d)
I, Rebecca J. Kujawa, certify that:
Rule 13a-14(a)/15d-14(a) Certification
1.
I have reviewed this Form 10-K for the annual period ended December 31, 2019 of Florida Power & Light Company (the
registrant);
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material
fact necessary to make the statements made, in light of the circumstances under which such statements were made, not
misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in
all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods
presented in this report;
4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and
procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be
designed under our supervision, to ensure that material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in
which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting
to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial
reporting and the preparation of financial statements for external purposes in accordance with generally accepted
accounting principles;
(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report
our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period
covered by this report based on such evaluation; and
(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during
the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report)
that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial
reporting; and
5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons
performing the equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial
reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and
report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in
the registrant's internal control over financial reporting.
Date: February 14, 2020
REBECCA J. KUJAWA
Rebecca J. Kujawa
Executive Vice President, Finance
and Chief Financial Officer
of Florida Power & Light Company
Exhibit 32(a)
Section 1350 Certification
We, James L. Robo and Rebecca J. Kujawa, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:
(1) The Annual Report on Form 10-K of NextEra Energy, Inc. (the registrant) for the annual period ended December 31, 2019
(Report) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of
operations of the registrant.
Dated: February 14, 2020
JAMES L. ROBO
James L. Robo
Chairman, President and Chief Executive Officer
of NextEra Energy, Inc.
REBECCA J. KUJAWA
Rebecca J. Kujawa
Executive Vice President, Finance and
Chief Financial Officer
of NextEra Energy, Inc.
A signed original of this written statement required by Section 906 has been provided to the registrant and will be retained by the
registrant and furnished to the Securities and Exchange Commission or its staff upon request.
The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section
906 of the Sarbanes-Oxley Act of 2002 and, accordingly, is not being filed with the Securities and Exchange Commission as part
of the Report and is not to be incorporated by reference into any filing of the registrant under the Securities Act of 1933 or the
Securities Exchange Act of 1934 (whether made before or after the date of the Report, irrespective of any general incorporation
language contained in such filing).
Exhibit 32(b)
Section 1350 Certification
We, Eric E. Silagy and Rebecca J. Kujawa, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:
(1) The Annual Report on Form 10-K of Florida Power & Light Company (the registrant) for the annual period ended
December 31, 2019 (Report) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange
Act of 1934; and
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of
operations of the registrant.
Dated: February 14, 2020
ERIC E. SILAGY
Eric E. Silagy
President and Chief Executive Officer
of Florida Power & Light Company
REBECCA J. KUJAWA
Rebecca J. Kujawa
Executive Vice President, Finance
and Chief Financial Officer
of Florida Power & Light Company
A signed original of this written statement required by Section 906 has been provided to the registrant and will be retained by the
registrant and furnished to the Securities and Exchange Commission or its staff upon request.
The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section
906 of the Sarbanes-Oxley Act of 2002 and, accordingly, is not being filed with the Securities and Exchange Commission as part
of the Report and is not to be incorporated by reference into any filing of the registrant under the Securities Act of 1933 or the
Securities Exchange Act of 1934 (whether made before or after the date of the Report, irrespective of any general incorporation
language contained in such filing).
BOARD OF DIRECTORS
JAMES L. ROBO
Chairman of the Board and Chief Executive Officer, NextEra Energy, Inc.
Director since 2012.
Chair: Executive Committee.
SHERRY S. BARRAT
Retired. Formerly Vice Chairman, Northern Trust Corporation
(financial holding company)
Director since 1998.
Member: Compensation Committee, Finance & Investment Committee.
JAMES L. CAMAREN
Private Investor. Formerly Chairman & Chief Executive Officer, Utilities, Inc.
(water utilities)
Director since 2002.
Member: Compensation Committee, Governance & Nominating Committee.
KENNETH B. DUNN
Emeritus Professor of Financial Economics and former Dean,
Tepper School of Business, Carnegie Mellon University
(higher education)
Director since 2010.
Member: Audit Committee, Finance & Investment Committee.
NAREN K. GURSAHANEY
Retired. Formerly President and Chief Executive Officer, ADT Corporation
(electronic security services)
Director since 2014.
Member: Audit Committee, Governance & Nominating Committee.
KIRK S. HACHIGIAN
Chairman of the Board, JELD-WEN, Inc.
(window and door manufacturer)
Director since 2013.
Chair: Compensation Committee.
Member: Governance & Nominating Committee, Executive Committee.
TONI JENNINGS
Chairman, Jack Jennings & Sons, Inc.
(construction)
Former Lt. Governor, State of Florida
Director since 2007.
Member: Audit Committee, Governance & Nominating Committee.
AMY B. LANE
Retired. Formerly Investment Banker, Merrill Lynch & Co., Inc.
(investment banking firm)
Director since 2015.
Chair: Finance & Investment Committee.
Member: Compensation Committee, Executive Committee.
DAVID L. PORGES
Retired. Formerly Chairman of the Board, Equitrans Midstream Corporation
(natural gas midstream operator)
Director since 2020.
Member: Finance & Investment Committee
RUDY E. SCHUPP
Retired. Formerly President, Valley National Bancorp and Chief Banking
Officer, Valley National Bank
(commercial bank)
Director since 2005.
Lead Director.
Chair: Governance & Nominating Committee.
Member: Finance & Investment Committee, Executive Committee.
JOHN L. SKOLDS
Retired. Formerly Executive Vice President of Exelon Corporation and
President of Exelon Energy Delivery and Exelon Generation
(utility services holding company)
Director since 2012.
Chair: Nuclear Committee.
Member: Audit Committee.
WILLIAM H. SWANSON
Retired. Formerly Chairman of the Board and Chief Executive Officer,
Raytheon Company
(global defense technology)
Director since 2009.
Chair: Audit Committee.
Member: Finance & Investment Committee, Executive Committee.
HANSEL E. TOOKES, II
Retired. Formerly President, Raytheon International
(defense and aerospace systems)
Director since 2005.
Member: Compensation Committee, Finance & Investment Committee.
DARRYL L. WILSON
Retired. Formerly Vice President, Commercial of GE Power
(power generation manufacturing)
Director since 2018.
Member: Audit Committee.
PROPOSED 2020 COMMON STOCK DIVIDEND DATES*
Declaration
February 14
May 22
July 30
October 16
Ex-Dividend
February 27
June 1
August 27
November 25
Record
February 28
June 2
August 28
November 27
Payment
March 16
June 15
September 15
December 15
* Declaration of dividends and dates shown are subject to the discretion of the Board of Directors of NextEra Energy, Inc.
Dates shown are based on the assumption that past patterns will prevail.
INVESTOR INFORMATION
CORPORATE OFFICES
NextEra Energy, Inc.
700 Universe Blvd.
Juno Beach, FL 33408
EXCHANGE LISTING
Common Stock
New York Stock Exchange
Ticker Symbol: NEE
NextEra Energy Capital Holdings, Inc.
Series I Junior Subordinated
Debentures
New York Stock Exchange
Ticker Symbol: NEE.PRI
NextEra Energy Capital Holdings, Inc.
Series J Junior Subordinated
Debentures
New York Stock Exchange
Ticker Symbol: NEE.PRJ
NextEra Energy Capital Holdings, Inc.
Series K Junior Subordinated
Debentures
New York Stock Exchange
Ticker Symbol: NEE.PRK
NextEra Energy Capital Holdings, Inc.
Series N Junior Subordinated
Debentures
New York Stock Exchange
Ticker Symbol: NEE.PRN
NextEra Energy Capital Holdings, Inc.
Series J Senior Debentures
(Corporate Unit)
New York Stock Exchange
Ticker Symbol: NEE.PRO
NextEra Energy Capital Holdings, Inc.
Series K Senior Debentures
(Corporate Unit)
New York Stock Exchange
Ticker Symbol: NEE.PRP
NEWSPAPER LISTING
Common Stock: NEE
REGISTRAR, TRANSFER
AND PAYING AGENTS
NextEra Energy, Inc. Common Stock
NextEra Energy, Inc.
c/o Computershare
P.O. Box 505000
Louisville, KY 40233-5000
Florida Power & Light Company
First Mortgage Bonds
Deutsche Bank Trust
Company Americas
5022 Gate Parkway
Suite 200
Jacksonville, FL 32256
800-735-7777
Gulf Power Company
Debentures
Wells Fargo Bank, N.A.
Corporate Trust Operations
MAC N9300-070
600 South Fourth Street
Minneapolis, MN 55402
Attn: Bondholder Communications:
1-800-344-5128.
NextEra Energy Capital Holdings, Inc.
Debentures
NextEra Energy Capital Holdings, Inc.
Junior Subordinated Debentures
NextEra Energy, Inc. Corporate Units
The Bank of New York Mellon
Bondholder Relations
111 Sanders Creek Parkway
East Syracuse, NY 13057
800-254-2826
SHAREHOLDER INQUIRIES
Communications concerning transfer
requirements, lost certificates,
dividend checks, address changes,
stock accounts and the dividend
reinvestment and direct stock
purchase plan should be directed to
Computershare: 888-218-4392 or
www.computershare.com/NEE.
Other shareholder communications to:
Shareholder Services 800-222-4511
ELECTRONIC PROXY MATERIAL
Shareholders may elect to receive
proxy materials electronically by
accessing
https://enroll.icsdelivery.com/NEE.
DIRECT DEPOSIT
OF DIVIDENDS
Cash dividends may be
deposited directly to personal
accounts at financial institutions.
Call Computershare for
authorization forms.
DIVIDEND REINVESTMENT
AND DIRECT STOCK
PURCHASE PLAN
NextEra Energy offers a plan for
the reinvestment of dividends and
the purchase of common stock.
Enrollment materials may be
obtained by calling Computershare
or by accessing
www.computershare.com/NEE.
DIRECT REGISTRATION
SERVICES
NextEra Energy common stock
can be issued in direct registration
(book entry) form.
ONLINE INVESTOR
INFORMATION
Visit our investor information site at
NextEraEnergy.com/investors to
get stock quotes, earnings reports,
financial releases, SEC filings and
other news. You can also request
and receive information via email.
Shareholders of record can receive
secure online account access
through a link to Computershare.
SEC FILINGS
All Securities and Exchange
Commission filings appear at
NextEraEnergy.com/investors.
Copies of SEC filings also are
available without charge by writing
to NextEra Energy, Shareholder
Services.
NEWS AND FINANCIAL
INFORMATION
Get the latest news and financial
information about NextEra Energy by
visiting NextEraEnergy.com.
ANALYST INQUIRIES
Investor Relations
561-694-4697
NEWS MEDIA INQUIRIES
Media Relations
561-694-4442
CERTIFIED PUBLIC
ACCOUNTANTS
Deloitte & Touche LLP
1800 North Military Trail
Suite 200
Boca Raton, FL 33431-6386
NextEra Energy, Inc. (NYSE: NEE) is a leading clean energy company headquartered in Juno Beach, Florida. NextEra Energy owns two electric companies in Florida: Florida Power & Light
Company, which serves more than 5 million customer accounts in Florida and is the largest rate-regulated electric utility in the United States as measured by retail electricity produced and
sold; and Gulf Power Company, which serves more than 470,000 customers in eight counties throughout northwest Florida. NextEra Energy also owns a competitive energy business, NextEra
Energy Resources, LLC, which, together with its affiliated entities, is the world’s largest generator of renewable energy from the wind and sun and a world leader in battery storage. Through its
subsidiaries, NextEra Energy generates clean, emissions-free electricity from eight commercial nuclear power units in Florida, New Hampshire, Iowa and Wisconsin. A Fortune 200 company and
included in the S&P 100 index, NextEra Energy has been recognized often by third parties for its efforts in sustainability, corporate responsibility, ethics and compliance, and diversity. NextEra
Energy is ranked No. 1 in the electric and gas utilities industry on Fortune’s 2020 list of “World's Most Admired Companies” and ranked among the top 25 on Fortune’s 2018 list of companies
that “Change the World.” For more information about NextEra Energy companies, visit these websites: NextEraEnergy.com, FPL.com, GulfPower.com, NextEraEnergyResources.com.
NextEra Energy, Inc.
700 Universe Boulevard
Juno Beach, FL 33408
For more information, go to:
NextEraEnergy.com
FPL.com
GulfPower.com
NextEraEnergyResources.com
103122