Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2015

Commitments and Contingencies [Abstract]

Schedule of Planned Capital Expenditures

At June 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)	$	320	$	900	$	50	$	—	$	—	$	1,270
Existing	430		555		660		560		440		2,645
Transmission and distribution	950		1,960		1,755		1,625		1,680		7,970
Nuclear fuel	135		220		125		150		175		805
General and other	265		205		215		160		130		975
Total	$	2,100	$	3,840	$	2,805	$	2,495	$	2,425	$	13,665
NEER:
Wind(d)	$	1,105	$	855	$	45	$	10	$	10	$	2,025
Solar(e)	900		575		—		—		—		1,475
Nuclear, including nuclear fuel	155		285		225		245		270		1,180
Other	190		65		50		95		65		465
Total	$	2,350	$	1,780	$	320	$	350	$	345	$	5,145
Corporate and Other(f)	$	300	$	1,130	$	920	$	505	$	160	$	3,015

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(a) Includes AFUDC of approximately $48 million, $71 million and $8 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) Consists of capital expenditures for new wind projects and related transmission totaling approximately 1,655 MW.

(e) Consists of capital expenditures for new solar projects and related transmission totaling approximately 830 MW.

(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 June 30, 2015 were estimated as follows:

	Remainder of 2015		2016		2017		2018		2019		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	145	$	250	$	255	$	260	$	265	$	1,695
JEA and Southern subsidiaries	$	100	$	70	$	60	$	30	$	10	$	—
Minimum charges, at projected prices:(b)
Natural gas, including transportation and storage(c)	$	715	$	885	$	795	$	830	$	830	$	13,780
Coal, including transportation	$	60	$	50	$	35	$	—	$	—	$	—
NEER	$	1,730	$	1,250	$	140	$	135	$	80	$	395
Corporate and Other(d)(e)	$	255	$	915	$	710	$	380	$	65	$	25

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(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity cost recovery clause, totaled approximately $117 million and $123 million for the three months ended June 30, 2015 and 2014, respectively, and approximately $236 million and $246 million for the six months ended June 30, 2015 and 2014, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $78 million and $75 million for the three months ended June 30, 2015 and 2014, respectively, and approximately $122 million and $132 million for the six months ended June 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 $75 million commitment to invest primarily in clean power and technology businesses through 2021.

(e) Excludes approximately $450 million and $335 million in 2015 and 2016, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above.