Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2015

Commitments and Contingencies [Abstract]

Schedule of Planned Capital Expenditures

At September 30, 2015, estimated capital expenditures for the remainder of 2015 through 2019 for which applicable internal approvals (and also FPSC approvals for FPL, if required) have been received were as follows:

	Remainder of 2015		2016		2017		2018		2019		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	150	$	865	$	45	$	—	$	—	$	1,060
Existing	375		585		660		535		470		2,625
Transmission and distribution	510		1,960		1,755		1,625		1,680		7,530
Nuclear fuel	20		220		125		150		175		690
General and other	130		215		215		160		130		850
Total	$	1,185	$	3,845	$	2,800	$	2,470	$	2,455	$	12,755
NEER:
Wind(d)	$	235	$	1,185	$	65	$	15	$	10	$	1,510
Solar(e)	780		1,100		—		—		—		1,880
Nuclear, including nuclear fuel	90		300		240		260		310		1,200
Other	105		70		45		100		45		365
Total	$	1,210	$	2,655	$	350	$	375	$	365	$	4,955
Corporate and Other(f)	$	155	$	1,215	$	915	$	505	$	160	$	2,950

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(a) Includes AFUDC of approximately $28 million, $79 million and $13 million for the remainder of 2015 through 2017, respectively.

(b) Includes land, generating structures, transmission interconnection and integration and licensing.

(c) Excludes capital expenditures for costs related to the two additional nuclear units at FPL's Turkey Point site beyond what is required to receive an NRC license for each unit.

(d) Includes capital expenditures for new wind projects and related transmission totaling approximately 1,790 MW, including 125 MW that received applicable internal approvals in October 2015.

(e) Consists of capital expenditures for new solar projects and related transmission totaling approximately 1,155 MW, including 220 MW that received applicable internal approvals in October 2015.

(f) Includes capital expenditures for construction of three natural gas pipelines, including equity contributions associated with equity investments in joint ventures for two pipelines and AFUDC associated with the third pipeline. The natural gas pipelines are subject to certain conditions, including FERC approval. See Contracts below.

Required capacity and/or minimum payments under contracts

The required capacity and/or minimum payments under the contracts discussed above as of September 30, 2015 were estimated as follows:

	Remainder of 2015		2016		2017		2018		2019		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Pay-for-performance	$	40	$	115	$	115	$	115	$	115	$	835
Take-or-pay	$	50	$	70	$	60	$	30	$	10	$	—
Minimum charges, at projected prices:(b)
Natural gas, including transportation and storage(c)	$	325	$	955	$	850	$	865	$	860	$	13,940
Coal, including transportation	$	30	$	60	$	40	$	—	$	—	$	—
NEER	$	930	$	1,710	$	155	$	160	$	90	$	620
Corporate and Other(d)(e)	$	155	$	1,005	$	665	$	385	$	65	$	25

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(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity cost recovery clause (capacity clause), totaled approximately $112 million and $123 million for the three months ended September 30, 2015 and 2014, respectively, and approximately $349 million and $369 million for the nine months ended September 30, 2015 and 2014, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $99 million and $110 million for the three months ended September 30, 2015 and 2014, respectively, and approximately $221 million and $242 million for the nine months ended September 30, 2015 and 2014, respectively.

(b) Recoverable through the fuel clause.

(c) Includes approximately $200 million, $295 million, $290 million and $8,245 million in 2017, 2018, 2019 and thereafter, respectively, of firm commitments, subject to certain conditions as noted above, related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection.

(d) Includes an approximately $65 million commitment to invest primarily in clean power and technology businesses through 2021.

(e) Excludes approximately $85 million and $615 million in 2015 and 2016, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above.