Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2012

Commitments and Contingencies [Abstract]

Schedule of Planned Capital Expenditures

At December 31, 2012, estimated capital expenditures for 2013 through 2017 were as follows:

	2013		2014		2015		2016		2017		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	915	$	760	$	295	$	130	$	—	$	2,100
Existing	645		710		675		580		555		3,165
Transmission and distribution	745		795		745		770		795		3,850
Nuclear fuel	125		175		245		245		260		1,050
General and other	155		145		105		125		120		650
Total	$	2,585	$	2,585	$	2,065	$	1,850	$	1,730	$	10,815
NEER:
Wind(d)	$	385	$	45	$	5	$	5	$	5	$	445
Solar(e)	830		175		5		—		—		1,010
Nuclear(f)	280		310		310		330		280		1,510
Other(g)	310		45		115		50		50		570
Total	$	1,805	$	575	$	435	$	385	$	335	$	3,535
Corporate and Other(h)	$	175	$	75	$	70	$	70	$	70	$	460

______________________

(a) Includes AFUDC of approximately $85 million, $52 million, $47 million and $27 million for 2013 through 2016, respectively.

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

(c) Consists of projects that have received FPSC approval.  Includes pre-construction costs and carrying charges (equal to a fixed pretax AFUDC rate) on construction costs recoverable through the capacity clause of approximately $42 million and $12 million in 2013 and 2014, respectively.  Excludes capital expenditures for the construction costs for the two additional nuclear units at FPL's Turkey Point site beyond what is required to receive an NRC license for each unit.  

(d) Consists of capital expenditures for new wind projects and related transmission totaling approximately 300 mw, including approximately 125 mw in Canada, that have received applicable internal approvals.  Excludes new Canadian wind projects requiring internal approvals with generation totaling approximately 470 mw in 2014 and 2015, with an estimated cost of approximately $1.3 billion to $1.5 billion.

(e) Consists of capital expenditures for new solar projects and related transmission totaling 645 mw that have received applicable internal approvals, including equity contributions associated with a 50% equity investment in a 550 mw solar project.  Excludes solar projects requiring internal approvals with generation totaling 250 mw with an estimated cost of approximately $600 million to $800 million.

(f) Includes nuclear fuel.

(g) Consists of capital expenditures that have received applicable internal approvals. 

(h) Consists of capital expenditures that have received applicable internal approvals and includes AFUDC related to Lone Star of approximately $21 million in 2013.

Required Capacity and/or Minimum Payments

The required capacity and/or minimum payments under the contracts discussed above as of December 31, 2012 were estimated as follows:

	2013		2014		2015		2016		2017		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	270	$	275	$	280	$	245	$	250	$	2,165
JEA and Southern subsidiaries	$	230	$	220	$	195	$	70	$	40	$	115
Minimum charges, at projected prices:
Natural gas, including transportation and storage(b)	$	1,995	$	1,310	$	570	$	535	$	530	$	6,405
Coal(b)	$	95	$	35	$	5	$	5	$	—	$	—
NEER	$	860	$	325	$	95	$	110	$	65	$	580
Corporate and Other(c)	$	45	$	10	$	15	$	10	$	10	$	10

______________________

(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $523 million, $511 million and $537 million for the years ended December 31, 2012, 2011 and 2010, respectively.  Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $276 million, $403 million and $434 million for the years ended December 31, 2012, 2011 and 2010, respectively.

(b) Recoverable through the fuel clause.

(c) Includes an approximately $68 million commitment to invest in clean power and technology businesses through 2021.