10-Q/A

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 10-Q/A

Amendment No. 1

[X]	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the Quarterly Period Ended June 30, 2012
	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	Registrant; State of Incorporation; Address; and Telephone Number	I.R.S. Employer Identification No.
1-5324	NORTHEAST UTILITIES (a Massachusetts voluntary association) One Federal Street Building 111-4 Springfield, Massachusetts 01105 Telephone:  (413) 785-5871	04-2147929

0-00404 THE CONNECTICUT LIGHT AND POWER COMPANY
(a Connecticut corporation)
107 Selden Street
Berlin, Connecticut 06037-1616
Telephone:  (860) 665-5000 06-0303850

1-02301 NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street
Boston, Massachusetts 02199
Telephone:  (617) 424-2000 04-1278810

1-6392 PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
(a New Hampshire corporation)
Energy Park
780 North Commercial Street
Manchester, New Hampshire 03101-1134
Telephone:  (603) 669-4000 02-0181050

0-7624 WESTERN MASSACHUSETTS ELECTRIC COMPANY
(a Massachusetts corporation)
One Federal Street
Building 111-4
Springfield, Massachusetts 01105
Telephone:  (413) 785-5871 04-1961130

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 (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

Yes	No
ü

Indicate by check mark whether the registrants have submitted electronically and posted on its corporate web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes	No
ü

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.  See definition of "accelerated filer and large accelerated filer" in Rule 12b-2 of the Exchange Act.  (Check one):

	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer
Northeast Utilities	ü
The Connecticut Light and Power Company			ü
NSTAR Electric Company			ü
Public Service Company of New Hampshire			ü
Western Massachusetts Electric Company			ü

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act):

	Yes	No
Northeast Utilities		ü
The Connecticut Light and Power Company		ü
NSTAR Electric Company		ü
Public Service Company of New Hampshire		ü
Western Massachusetts Electric Company		ü

Indicate the number of shares outstanding of each of the issuers' classes of common stock, as of the latest practicable date:

Company - Class of Stock	Outstanding as of July 31, 2012
Northeast Utilities Common shares, $5.00 par value	313,804,466 shares
The Connecticut Light and Power Company Common stock, $10.00 par value	6,035,205 shares
NSTAR Electric Company Common Stock, $1.00 par value	100 shares
Public Service Company of New Hampshire Common stock, $1.00 par value	301 shares
Western Massachusetts Electric Company Common stock, $25.00 par value	434,653 shares

Northeast Utilities, directly or indirectly, holds all of the 6,035,205 shares, 100 shares, 301 shares, and 434,653 shares of the outstanding common stock of The Connecticut Light and Power Company, NSTAR Electric Company, Public Service Company of New Hampshire and Western Massachusetts Electric Company, respectively.  

FORM 10-Q/A EXPLANATORY NOTE

This Amendment No. 1 on Form 10−Q/A (this Amendment) amends the Quarterly Report on Form 10-Q of Northeast Utilities (NU), The Connecticut Light and Power Company (CL&P), NSTAR Electric Company (NSTAR Electric), Public Service Company of New Hampshire (PSNH), and Western Massachusetts Electric Company (WMECO) for the quarterly period ended June 30, 2012, originally filed with the Securities and Exchange Commission on August 7, 2012 (the Form 10-Q).  The sole purpose of this Amendment is to furnish the eXtensible Business Reporting Language (XBRL) information in Exhibit 101 in accordance with Rule 405 of Regulation S-T.  Exhibit 101 provides the consolidated financial statements and related notes from the Form 10-Q formatted in XBRL, which did not properly merge in the original XBRL transmission.

No other changes have been made to the Form 10-Q.  This Amendment No. 1 to the Form 10-Q speaks as of the original filing date of the Form 10-Q, does not reflect events that may have occurred after the original filing date and does not modify or update in any way disclosures made in the original Form 10-Q.

Pursuant to Rule 406T of Regulation S-T, the interactive data files on Exhibit 101 hereto are deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

1

ITEM 6.

EXHIBITS

Exhibit No.

Description

Listing of Exhibits (NU, CL&P, NSTAR Electric, PSNH and WMECO)

*10.1

Northeast Utilities System's Third and Restated Tax Allocation Agreement dated as of April 10, 2012

Listing of Exhibits (NU)

*12

Ratio of Earnings to Fixed Charges

*31

Certification of Thomas J. May, President and Chief Executive Officer of Northeast Utilities, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of Northeast Utilities, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*32

Certification of Thomas J. May, President and Chief Executive Officer of Northeast Utilities and James J. Judge, Executive Vice President and Chief Financial Officer of Northeast Utilities, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

**101.INS

XBRL Instance Document

**101.SCH

XBRL Taxonomy Extension Schema

**101.CAL

XBRL Taxonomy Extension Calculation

**101.DEF

XBRL Taxonomy Extension Definition

**101.LAB

XBRL Taxonomy Extension Labels

**101.PRE

XBRL Taxonomy Extension Presentation

Listing of Exhibits (CL&P)

*12

Ratio of Earnings to Fixed Charges

*31

Certification of Leon J. Olivier, Chief Executive Officer of The Connecticut Light and Power Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of The Connecticut Light and Power Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*32

Certification of Leon J. Olivier, Chief Executive Officer of The Connecticut Light and Power Company and James J. Judge, Executive Vice President and Chief Financial Officer of The Connecticut Light and Power Company, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

Listing of Exhibits (NSTAR Electric)

*12

Ratio of Earnings to Fixed Charges

*31

Certification of Leon J. Olivier, Chief Executive Officer of NSTAR Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of NSTAR Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*32

Certification of Leon J. Olivier, Chief Executive Officer of NSTAR Electric Company and James J. Judge, Executive Vice President and Chief Financial Officer of NSTAR Electric Company, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

2

Listing of Exhibits (PSNH)

*12

Ratio of Earnings to Fixed Charges

*31

Certification of Leon J. Olivier, Chief Executive Officer of Public Service Company of New Hampshire, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of Public Service Company of New Hampshire, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*32

Certification of Leon J. Olivier, Chief Executive Officer of Public Service Company of New Hampshire and James J. Judge, Executive Vice President and Chief Financial Officer of Public Service Company of New Hampshire, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

Listing of Exhibits (WMECO)

*12

Ratio of Earnings to Fixed Charges

*31

Certification of Leon J. Olivier, Chief Executive Officer of Western Massachusetts Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of Western Massachusetts Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

*32

Certification of Leon J. Olivier, Chief Executive Officer of Western Massachusetts Electric Company and James J. Judge, Executive Vice President and Chief Financial Officer of Western Massachusetts Electric Company, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated August 7, 2012

* Previously filed with the Quarterly Report on Form 10-Q of Northeast Utilities, The Connecticut Light and Power Company, NSTAR Electric Company, Public Service Company of New Hampshire, and Western Massachusetts Electric Company for the quarterly period ended June 30, 2012, originally filed with the Securities and Exchange Commission on August 7, 2012.

** Filed herewith.  

3

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.  

		NORTHEAST UTILITIES
		(Registrant)
Date:  August 8, 2012	By	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and
		Chief Accounting Officer
		(Principal Accounting Officer)

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.  

		THE CONNECTICUT LIGHT AND POWER COMPANY
		(Registrant)
Date:  August 8, 2012	By	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and
		Chief Accounting Officer
		(Principal Accounting Officer)

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.  

		NSTAR ELECTRIC COMPANY
		(Registrant)
Date:  August 8, 2012	By	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and
		Chief Accounting Officer
		(Principal Accounting Officer)

4

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

		PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
		(Registrant)
Date:  August 8, 2012	By	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and
		Chief Accounting Officer
		(Principal Accounting Officer)

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.  

		WESTERN MASSACHUSETTS ELECTRIC COMPANY
		(Registrant)
Date:  August 8, 2012	By	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and
		Chief Accounting Officer
		(Principal Accounting Officer)

5

XML

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Fair Value By Balance Sheet Grouping Text Block

		As of June 30, 2012				As of December 31, 2011
		NU				NU
		Carrying		Fair		Carrying		Fair
(Millions of Dollars)		Amount		Value		Amount		Value
Preferred Stock Not
	Subject to Mandatory
	Redemption	$	155.6	$	153.1	$	116.2	$	105.1
Long-Term Debt			7,619.7		8,302.7		4,950.7		5,517.0
Rate Reduction Bonds			160.1		163.6		112.3		116.8

		As of June 30, 2012
		CL&P				NSTAR Electric				PSNH				WMECO
		Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
(Millions of Dollars)		Amount		Value		Amount		Value		Amount		Value		Amount		Value
Preferred Stock Not
	Subject to Mandatory
	Redemption	$	116.2	$	110.1	$	43.0	$	43.0	$	-	$	-	$	-	$	-
Long-Term Debt			2,584.0		3,029.3		1,603.4		1,842.0		997.8		1,089.0		499.6		550.1
Rate Reduction Bonds			-		-		84.3		85.8		57.7		59.2		18.1		18.6
		As of December 31, 2011
		CL&P				NSTAR Electric(1)				PSNH				WMECO
		Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
(Millions of Dollars)		Amount		Value		Amount		Value		Amount		Value		Amount		Value
Preferred Stock Not
	Subject to Mandatory
	Redemption	$	116.2	$	105.1	$	43.0	$	41.2	$	-	$	-	$	-	$	-
Long-Term Debt			2,587.8		2,987.1		1,605.1		1,816.1		999.5		1,075.2		501.1		539.8
Rate Reduction Bonds			-		-		127.9		131.2		85.4		88.8		26.9		28.1

XML

PROPERTY, PLANT AND ACCUMULATED DEPRECIATION (Details) (USD $)	Jun. 30, 2012	Dec. 31, 2011
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	$ 11,168,100,000	$ 6,540,400,000
Public Utilities Property Plant And Equipment Distribution Natural Gas	2,160,100,000	1,247,600,000
Public Utilities Property Plant And Equipment Transmission	5,061,100,000	3,541,900,000
Public Utilities Property Plant And Equipment Generation Or Processing	1,147,300,000	1,096,000,000
Public Utilities Property Plant And Equipment Electric And Natural Gas Utility Total	19,536,600,000	12,425,900,000
Public Utilities Property Plant And Equipment Other Property Plant And Equipment	420,200,000	305,100,000
Public Utilities Property Plant And Equipment Plant In Service	19,956,800,000	12,731,000,000
ElectricAndNaturalGasUtilityAccumulatedDepreciation	(4,910,200,000)	(3,035,500,000)
OtherAccumulatedDepreciation	(160,800,000)	(120,200,000)
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(5,071,000,000)	(3,155,700,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	14,885,800,000	9,575,300,000
Public Utilities Property Plant And Equipment Construction Work In Progress	1,169,100,000	827,800,000
Property, Plant and Equipment, Net	16,054,913,000	10,403,065,000
The Connecticut Light And Power Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	4,590,200,000	4,419,600,000
Public Utilities Property Plant And Equipment Transmission	2,707,500,000	2,689,100,000
Public Utilities Property Plant And Equipment Generation Or Processing	0	0
Public Utilities Property Plant And Equipment Plant In Service	7,297,700,000	7,108,700,000
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,640,800,000)	(1,596,700,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	5,656,900,000	5,512,000,000
Public Utilities Property Plant And Equipment Construction Work In Progress	343,900,000	315,400,000
Property, Plant and Equipment, Net	6,000,783,000	5,827,384,000
Public Service Company Of New Hampshire [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	1,481,600,000	1,451,600,000
Public Utilities Property Plant And Equipment Transmission	558,200,000	546,400,000
Public Utilities Property Plant And Equipment Generation Or Processing	1,126,100,000	1,074,800,000
Public Utilities Property Plant And Equipment Plant In Service	3,165,900,000	3,072,800,000
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(916,700,000)	(893,600,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	2,249,200,000	2,179,200,000
Public Utilities Property Plant And Equipment Construction Work In Progress	66,800,000	77,500,000
Property, Plant and Equipment, Net	2,315,954,000	2,256,688,000
Western Massachusetts Electric Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	713,800,000	704,300,000
Public Utilities Property Plant And Equipment Transmission	352,600,000	297,400,000
Public Utilities Property Plant And Equipment Generation Or Processing	21,200,000	21,200,000
Public Utilities Property Plant And Equipment Plant In Service	1,087,600,000	1,022,900,000
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(247,300,000)	(240,500,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	840,300,000	782,400,000
Public Utilities Property Plant And Equipment Construction Work In Progress	376,100,000	295,400,000
Property, Plant and Equipment, Net	1,216,370,000	1,077,833,000
NSTAR Electric Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	4,418,700,000	4,334,400,000
Public Utilities Property Plant And Equipment Transmission	1,424,800,000	1,386,900,000
Public Utilities Property Plant And Equipment Generation Or Processing	0	0
Public Utilities Property Plant And Equipment Plant In Service	5,843,500,000	5,721,300,000
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,498,800,000)	(1,436,000,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	4,344,700,000	4,285,300,000
Public Utilities Property Plant And Equipment Construction Work In Progress	210,800,000	162,000,000
Property, Plant and Equipment, Net	$ 4,555,454,000	$ 4,447,258,000

XML

Other Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Excise And Sales Taxes	$ 30.5	$ 32.0	$ 65.5	$ 70.7
The Connecticut Light And Power Company [Member]
Excise And Sales Taxes	$ 27.7	$ 28.8	$ 57.1	$ 60.2

XML

SEGMENT INFORMATION (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Segment Reporting Information [Line Items]
Operating Revenues	$ 1,628,684,000	$ 1,047,481,000	$ 2,728,307,000	$ 2,282,732,000
Depreciation And Amortization	(210,800,000)	(107,700,000)	(315,400,000)	(232,400,000)
Operating Expenses	(1,258,400,000)	(761,700,000)	(2,039,000,000)	(1,644,800,000)
Operating Income	159,515,000	178,134,000	373,908,000	405,491,000
Total Interest Expense	(89,047,000)	(62,234,000)	(155,495,000)	(120,783,000)
Other Income/(Loss), Net	1,806,000	7,334,000	10,580,000	17,647,000
Income Tax Expense	(26,055,000)	(44,515,000)	(82,019,000)	(108,052,000)
Net Income	46,219,000	78,719,000	146,974,000	194,303,000
Net Income Attributable to Noncontrolling Interests	(1,880,000)	(1,441,000)	(3,373,000)	(2,870,000)
Net Income Attributable to Controlling Interests	44,339,000	77,278,000	143,601,000	191,433,000
Total Assets	27,506,300,000		27,506,300,000		15,647,066,000
Investments in Property, Plant and Equipment			690,376,000	468,526,000
The Connecticut Light And Power Company [Member]
Segment Reporting Information [Line Items]
Operating Revenues	562,141,000	608,013,000	1,154,106,000	1,281,695,000
Operating Income	40,381,000	114,799,000	152,245,000	240,782,000
Total Interest Expense	(33,771,000)	(34,298,000)	(67,278,000)	(64,050,000)
Other Income/(Loss), Net	447,000	2,058,000	5,747,000	6,663,000
Income Tax Expense	(124,000)	(29,924,000)	(29,796,000)	(66,423,000)
Net Income	6,933,000	52,635,000	60,918,000	116,972,000
Total Assets	8,835,371,000		8,835,371,000		8,791,396,000
Investments in Property, Plant and Equipment			220,712,000	201,966,000
Public Service Company Of New Hampshire [Member]
Segment Reporting Information [Line Items]
Operating Revenues	255,105,000	240,191,000	498,102,000	509,661,000
Operating Income	47,046,000	37,939,000	92,432,000	84,874,000
Total Interest Expense	(12,785,000)	(10,401,000)	(25,597,000)	(20,857,000)
Other Income/(Loss), Net	549,000	4,361,000	2,590,000	8,820,000
Income Tax Expense	(13,578,000)	(10,234,000)	(26,931,000)	(23,708,000)
Net Income	21,232,000	21,665,000	42,494,000	49,129,000
Total Assets	3,036,797,000		3,036,797,000		3,116,541,000
Investments in Property, Plant and Equipment			120,792,000	111,459,000
Western Massachusetts Electric Company [Member]
Segment Reporting Information [Line Items]
Operating Revenues	106,836,000	98,390,000	220,861,000	205,074,000
Operating Income	25,056,000	18,477,000	53,716,000	39,529,000
Total Interest Expense	(6,869,000)	(5,460,000)	(13,264,000)	(11,034,000)
Other Income/(Loss), Net	188,000	242,000	1,280,000	981,000
Income Tax Expense	(7,237,000)	(5,088,000)	(16,408,000)	(11,339,000)
Net Income	11,138,000	8,171,000	25,324,000	18,137,000
Total Assets	1,633,513,000		1,633,513,000		1,502,893,000
Investments in Property, Plant and Equipment			152,687,000	76,898,000
Electric Distribution Member
Segment Reporting Information [Line Items]
Operating Revenues	1,229,900,000	794,400,000	2,016,000,000	1,686,000,000
Depreciation And Amortization	(153,300,000)	(76,500,000)	(225,400,000)	(167,500,000)
Operating Expenses	(1,004,800,000)	(633,200,000)	(1,627,000,000)	(1,326,300,000)
Operating Income	71,800,000	84,700,000	163,600,000	192,200,000
Total Interest Expense	(44,800,000)	(31,000,000)	(77,900,000)	(60,600,000)
Interest Income	1,000,000	600,000	2,100,000	1,900,000
Other Income/(Loss), Net	(200,000)	2,800,000	4,200,000	6,600,000
Income Tax Expense	(6,900,000)	(17,200,000)	(28,300,000)	(43,600,000)
Net Income	20,900,000	39,900,000	63,700,000	96,500,000
Net Income Attributable to Noncontrolling Interests	(1,200,000)	(800,000)	(2,000,000)	(1,700,000)
Net Income Attributable to Controlling Interests	19,700,000	39,100,000	61,700,000	94,800,000
Total Assets	15,161,300,000		15,161,300,000		9,653,100,000
Investments in Property, Plant and Equipment			305,700,000	251,100,000
Electric Distribution Member | The Connecticut Light And Power Company [Member]
Segment Reporting Information [Line Items]
Operating Revenues	442,200,000	489,900,000	916,900,000	1,039,800,000
Net Income	(27,200,000)	19,800,000	(5,500,000)	49,200,000
Total Assets	6,137,500,000		6,137,500,000		6,161,000,000
Electric Distribution Member | Public Service Company Of New Hampshire [Member]
Segment Reporting Information [Line Items]
Operating Revenues	229,400,000	219,100,000	448,900,000	467,000,000
Net Income	14,700,000	16,000,000	29,900,000	37,500,000
Total Assets	2,451,500,000		2,451,500,000		2,551,300,000
Electric Distribution Member | Western Massachusetts Electric Company [Member]
Segment Reporting Information [Line Items]
Operating Revenues	81,600,000	85,400,000	173,600,000	179,300,000
Net Income	1,400,000	4,000,000	7,500,000	9,700,000
Total Assets	943,300,000		943,300,000		942,600,000
Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Operating Revenues	133,500,000	78,400,000	272,500,000	258,600,000
Depreciation And Amortization	(12,400,000)	(6,300,000)	(20,100,000)	(13,100,000)
Operating Expenses	(115,800,000)	(65,700,000)	(218,000,000)	(199,200,000)
Operating Income	5,300,000	6,400,000	34,400,000	46,300,000
Total Interest Expense	(8,800,000)	(5,200,000)	(14,300,000)	(10,400,000)
Interest Income	0	0	0	0
Other Income/(Loss), Net	100,000	400,000	100,000	800,000
Income Tax Expense	1,300,000	(400,000)	(7,600,000)	(13,000,000)
Net Income	(2,100,000)	1,200,000	12,600,000	23,700,000
Net Income Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Controlling Interests	(2,100,000)	1,200,000	12,600,000	23,700,000
Total Assets	2,432,700,000		2,432,700,000		1,511,300,000
Investments in Property, Plant and Equipment			59,700,000	45,400,000
Transmission [Member]
Segment Reporting Information [Line Items]
Operating Revenues	228,700,000	152,100,000	391,600,000	310,300,000
Depreciation And Amortization	(28,600,000)	(21,400,000)	(49,800,000)	(44,800,000)
Operating Expenses	(65,500,000)	(44,200,000)	(113,200,000)	(92,500,000)
Operating Income	134,600,000	86,500,000	228,600,000	173,000,000
Total Interest Expense	(26,200,000)	(19,100,000)	(45,800,000)	(35,400,000)
Interest Income	100,000	100,000	300,000	300,000
Other Income/(Loss), Net	700,000	3,300,000	3,900,000	8,100,000
Income Tax Expense	(44,800,000)	(28,000,000)	(75,600,000)	(57,900,000)
Net Income	64,400,000	42,800,000	111,400,000	88,100,000
Net Income Attributable to Noncontrolling Interests	(700,000)	(600,000)	(1,400,000)	(1,200,000)
Net Income Attributable to Controlling Interests	63,700,000	42,200,000	110,000,000	86,900,000
Total Assets	5,327,700,000		5,327,700,000		3,792,900,000
Investments in Property, Plant and Equipment			297,200,000	146,000,000
Transmission [Member] | The Connecticut Light And Power Company [Member]
Segment Reporting Information [Line Items]
Operating Revenues	119,900,000	118,100,000	237,200,000	241,900,000
Net Income	34,100,000	32,800,000	66,400,000	67,800,000
Total Assets	2,697,900,000		2,697,900,000		2,630,400,000
Transmission [Member] | Public Service Company Of New Hampshire [Member]
Segment Reporting Information [Line Items]
Operating Revenues	25,700,000	21,100,000	49,200,000	42,700,000
Net Income	6,500,000	5,700,000	12,600,000	11,600,000
Total Assets	585,300,000		585,300,000		565,200,000
Transmission [Member] | Western Massachusetts Electric Company [Member]
Segment Reporting Information [Line Items]
Operating Revenues	25,200,000	13,000,000	47,300,000	25,800,000
Net Income	9,700,000	4,200,000	17,800,000	8,400,000
Total Assets	690,200,000		690,200,000		560,300,000
Other Segment [Member]
Segment Reporting Information [Line Items]
Operating Revenues	230,200,000	130,800,000	363,400,000	261,200,000
Depreciation And Amortization	(17,700,000)	(3,900,000)	(21,600,000)	(8,300,000)
Operating Expenses	(263,000,000)	(126,800,000)	(397,800,000)	(261,700,000)
Operating Income	(50,500,000)	100,000	(56,000,000)	(8,800,000)
Total Interest Expense	(11,100,000)	(8,500,000)	(20,400,000)	(17,100,000)
Interest Income	1,400,000	1,500,000	2,600,000	2,700,000
Other Income/(Loss), Net	117,900,000	85,400,000	240,500,000	234,900,000
Income Tax Expense	25,000,000	2,000,000	31,000,000	7,800,000
Net Income	82,700,000	80,500,000	197,700,000	219,500,000
Net Income Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Controlling Interests	82,700,000	80,500,000	197,700,000	219,500,000
Total Assets	20,614,100,000		20,614,100,000		6,618,000,000
Investments in Property, Plant and Equipment			27,800,000	26,000,000
Eliminations Segment [Member]
Segment Reporting Information [Line Items]
Operating Revenues	(193,600,000)	(108,200,000)	(315,200,000)	(233,400,000)
Depreciation And Amortization	1,200,000	400,000	1,500,000	1,300,000
Operating Expenses	190,700,000	108,200,000	317,000,000	234,900,000
Operating Income	(1,700,000)	400,000	3,300,000	2,800,000
Total Interest Expense	1,900,000	1,600,000	2,900,000	2,700,000
Interest Income	(1,400,000)	(1,500,000)	(2,700,000)	(2,800,000)
Other Income/(Loss), Net	(117,800,000)	(85,300,000)	(240,400,000)	(234,800,000)
Income Tax Expense	(700,000)	(900,000)	(1,500,000)	(1,400,000)
Net Income	(119,700,000)	(85,700,000)	(238,400,000)	(233,500,000)
Net Income Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Controlling Interests	(119,700,000)	(85,700,000)	(238,400,000)	(233,500,000)
Total Assets	(16,029,500,000)		(16,029,500,000)		(5,928,200,000)
Investments in Property, Plant and Equipment			0	0
Total [Member]
Segment Reporting Information [Line Items]
Interest Income	1,100,000	700,000	2,300,000	2,100,000
Other Income/(Loss), Net	$ 700,000	$ 6,600,000	$ 8,300,000	$ 15,600,000

XML

MARKETABLE SECURITIES (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Schedule Of Available For Sale Securities [Line Items]
Fair Value Of Securities Under Fair Value Option	$ 43.8		$ 43.8		$ 41.1
Fair Value Option Changes In Fair Value Gain Loss	(0.5)	0.3	2.7	2.2
Investments, Debt and Equity Securities [Abstract]
Marketable Securities, Restricted, Noncurrent	304.0		304.0
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	451.5		451.5		131.3
Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	57.5		57.5		57.1
Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	221.1		221.1		42.9
Fair Value Inputs Level 1 Member | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	3.8		3.8		0.1
Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	230.4		230.4		88.4
Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	53.7		53.7		57.0
US Government Debt Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	59.5		59.5		11.1
US Government Debt Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	18.7		18.7		8.0
Corporate Bond Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	31.4		31.4		16.5
Corporate Bond Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	6.2		6.2		9.1
Asset Backed Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	27.4		27.4		25.9
Asset Backed Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	6.5		6.5		7.9
Municipal Bonds Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	96.4		96.4		16.1
Municipal Bonds Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	15.5		15.5		15.4
Other Debt Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	15.7		15.7		18.8
Other Debt Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	6.8		6.8		16.6
Cash And Cash Equivalents Member | Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	36.3		36.3		1.8
Cash And Cash Equivalents Member | Fair Value Inputs Level 1 Member | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	3.8		3.8		0.1
Mutual Funds [Member] | Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	184.8		184.8		41.1
Equity Securities [Member]
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	141.0		141.0
Available-for-sale Securities, Gross Unrealized Gains	12.0		12.0
Available-for-sale Securities, Gross Unrealized Losses	(5.6)		(5.6)
Available For Sale Securities Amortized Cost	134.6		134.6
Debt Securities [Member]
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	266.7		266.7		90.2
Available-for-sale Securities, Gross Unrealized Gains	10.9		10.9		2.0
Available-for-sale Securities, Gross Unrealized Losses	(0.3)		(0.3)		(0.2)
Available For Sale Securities Amortized Cost	256.1		256.1		88.4
Available For Sale Securities Debt Maturities Fair Value Abstract
Available For Sale Securities Debt Maturities After Five Through Ten Years Fair Value	54.9		54.9
Available For Sale Securities Debt Maturities After Ten Years Fair Value	103.9		103.9
Available For Sale Securities Debt Maturities After One Year Through Five Years Fair Value	55.0		55.0
Available For Sale Securities Debt Maturities Within One Year Fair Value	52.9		52.9
Available For Sale Securities Debt Maturities Fair Value	266.7		266.7
Available For Sale Securities Debt Maturities Amortized Cost Abstract
Available For Sale Securities Debt Maturities After One Through Five Years Amortized Cost	53.8		53.8
Available For Sale Securities Debt Maturities Within One Year Amortized Cost	52.9		52.9
Available For Sale Securities Debt Maturities After Ten Years Amortized Cost	97.5		97.5
Available For Sale Securities Debt Maturities After Five Through Ten Years Amortized Cost	51.9		51.9
Available For Sale Securities Debt Maturities Amortized Cost	256.1		256.1
Debt Securities [Member] | Western Massachusetts Electric Company [Member]
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	57.5		57.5		57.1
Available-for-sale Securities, Gross Unrealized Gains	0.1		0.1
Available-for-sale Securities, Gross Unrealized Losses	(0.1)		(0.1)		(0.2)
Available For Sale Securities Amortized Cost	57.5		57.5		57.3
Available For Sale Securities Debt Maturities Fair Value Abstract
Available For Sale Securities Debt Maturities After Five Through Ten Years Fair Value	6.1		6.1
Available For Sale Securities Debt Maturities After Ten Years Fair Value	9.7		9.7
Available For Sale Securities Debt Maturities After One Year Through Five Years Fair Value	23.2		23.2
Available For Sale Securities Debt Maturities Within One Year Fair Value	18.5		18.5
Available For Sale Securities Debt Maturities Fair Value	57.5		57.5
Available For Sale Securities Debt Maturities Amortized Cost Abstract
Available For Sale Securities Debt Maturities After One Through Five Years Amortized Cost	23.2		23.2
Available For Sale Securities Debt Maturities Within One Year Amortized Cost	18.5		18.5
Available For Sale Securities Debt Maturities After Ten Years Amortized Cost	9.8		9.8
Available For Sale Securities Debt Maturities After Five Through Ten Years Amortized Cost	6.0		6.0
Available For Sale Securities Debt Maturities Amortized Cost	$ 57.5		$ 57.5

XML

Provision for Uncollectible Accounts (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2012	Dec. 31, 2011
Accounts Notes And Loans Receivable Line Items
Allowance For Doubtful Accounts Receivable Current	$ 93.1	$ 34.9
The Connecticut Light And Power Company [Member]
Accounts Notes And Loans Receivable Line Items
Allowance For Doubtful Accounts Receivable Current	11.8	14.8
Public Service Company Of New Hampshire [Member]
Accounts Notes And Loans Receivable Line Items
Allowance For Doubtful Accounts Receivable Current	7.9	7.2
Western Massachusetts Electric Company [Member]
Accounts Notes And Loans Receivable Line Items
Allowance For Doubtful Accounts Receivable Current	3.7	4.6
NSTAR Electric Company [Member]
Accounts Notes And Loans Receivable Line Items
Allowance For Doubtful Accounts Receivable Current	$ 44.7	$ 27.1

XML

MARKETABLE SECURITIES (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Available For Sale Securities Reconciliation [Table TextBlock]

		As of June 30, 2012
				Pre-Tax		Pre-Tax
		Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains(1)		Losses(1)		Fair Value
NU
	Debt Securities(2)	$	256.1	$	10.9	$	(0.3)	$	266.7
	Equity Securities(2)		134.6		12.0		(5.6)		141.0
WMECO
	Debt Securities		57.5		0.1		(0.1)		57.5
		As of December 31, 2011
				Pre-Tax		Pre-Tax
		Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains(1)		Losses(1)		Fair Value
NU		$	88.4	$	2.0	$	(0.2)	$	90.2
WMECO			57.3		-		(0.2)		57.1

Investments Classified by Contractual Maturity Date [Table Text Block]

	NU				WMECO
	Amortized				Amortized
(Millions of Dollars)	Cost		Fair Value		Cost		Fair Value
Less than one year(1)	$	52.9	$	52.9	$	18.5	$	18.5
One to five years		53.8		55.0		23.2		23.2
Six to ten years		51.9		54.9		6.0		6.1
Greater than ten years		97.5		103.9		9.8		9.7
Total Debt Securities	$	256.1	$	266.7	$	57.5	$	57.5

Fair Value Heirarchy [Table Text Block]

			NU				WMECO
			As of		As of		As of		As of
(Millions of Dollars)			June 30, 2012		December 31, 2011		June 30, 2012		December 31, 2011
Level 1:
	Mutual Funds and Equity Securities		$	184.8	$	41.1	$	-	$	-
	Money Market Funds			36.3		1.8		3.8		0.1
Total Level 1			$	221.1	$	42.9	$	3.8	$	0.1
Level 2:
	U.S. Government Issued Debt Securities
		(Agency and Treasury)		59.5		11.1		18.7		8.0
	Corporate Debt Securities			31.4		16.5		6.2		9.1
	Asset-Backed Debt Securities			27.4		25.9		6.5		7.9
	Municipal Bonds			96.4		16.1		15.5		15.4
	Other Fixed Income Securities			15.7		18.8		6.8		16.6
Total Level 2			$	230.4	$	88.4	$	53.7	$	57.0
Total Marketable Securities			$	451.5	$	131.3	$	57.5	$	57.1

XML

SHARE-BASED PAYMENTS (Details) (USD $)	0 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Apr. 09, 2012	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]
Excess Tax Benefit from Share-based Compensation, Financing Activities				$ 2.8	$ 1.1
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized		4,500,000		4,500,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant		2,530,024		2,530,024		2,685,615
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost		12.8	3.0	16.4	6.1
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense		5.1	1.2	6.6	2.4
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized		34.9		34.9
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition				2.37
Employee Service Share Based Compensation Awards Other Than Options [Abstract]
Share-based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options NSTAR Deferred and Performance Awards Converted Upon Merger	421,775
Share-based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options NSTAR Deferred and Performance Awards Converted to NU RSU's Upon Merger, Value	15.5
Share-based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options NSTAR RSU Retention Awards Converted to NU RSU's Upon Merger	195,619
Share-based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options NSTAR RSU Retention Awards Converted to NU RSU Retention Awards Upon Merger, Value	7.2
Employee Service Share Based Compensation Stock Option Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term		4.7		4.7
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number		2,371,661		2,371,661		47,374
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period				(340,607)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period				0
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Lower Range Limit				$ 18.45		$ 18.58
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Upper Range Limit				$ 28.12		$ 18.90
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price		$ 23.90		$ 23.90		$ 18.78
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price		$ 23.84		$ 23.84
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price				$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Total Intrinsic Value				4.3
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value		35.4		35.4
Employee Service Share-based Compensation, Cash Received from Exercise of Stock Options				8.1
Employee Service Share-based Compensation, Tax Benefit Realized from Exercise of Stock Options				1.8
Share-base Compensation, Converted NSTAR Options, Exercise Price Range, Lower Range Limit	$ 16.47
Share-base Compensation, Converted NSTAR Options, Exercise Price Range, Upper Range Limit	$ 28.12
Share-based Compensation Arrangement by Share-based Payment Award, Options, Converted NSTAR Options Upon Merger	2,664,894
Share-based Compensation Arrangement by Share-based Payment Award, Options, Converted NSTAR Options Upon Merger, Weighted Average Exercise Price	$ 23.99
Share-based Compensation Arrangement by Share-based Payment Award, Options, Converted NSTAR Options Upon Merger, Total Value	30.5
Employee Service Share-based Compenation ESPP Disclosures [Abstract]
Stock Issued During Period, Shares, Employee Stock Purchase Plans				20,555		35,476
ESPP Discounted Purchase Price First Six Months				33.01	31.27
ESPP Discounted Purchase Price Second Six Months						32.30
Employee Stock Purchase Plan Shares Remaining For Future Issuance		876,147		876,147		896,702
The Connecticut Light And Power Company [Member]
Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost		0.9	1.7	3.0	3.5
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense		0.4	0.7	1.2	1.4
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized		6.8		6.8
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition				2.17
NSTAR Electric Company [Member]
Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost		2.8	1.9	4.9	3.8
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense		1.1	0.7	1.9	1.5
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized		9.8		9.8
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition				2.41
Nstar [Member]
Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized		3,500,000		3,500,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant		977,922		977,922		988,729
Public Service Company Of New Hampshire [Member]
Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost		0.3	0.6	1.1	1.2
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense		0.1	0.2	0.4	0.5
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized		2.5		2.5
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition				2.15
Western Massachusetts Electric Company [Member]
Employee Service Share-based Compensation, Aggregate Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost		0.2	0.3	0.6	0.7
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense		0.1	0.1	0.3	0.3
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized		$ 1.5		$ 1.5
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition				2.15
Restricted Stock Units (RSUs) [Member]
Employee Service Share Based Compensation Awards Other Than Options [Abstract]
Share-based Compensation Arragement by Share-based Payment Award Equity Instruments Other Than Options Beginning Balance						959,920
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period				538,724
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period				(300,460)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period				(76,361)
Share-based Compensation Arrangement by Share-based Payment Award Equity Instruments Other Than Options Ending Balance				2,190,575
Share-based Compensation Arrangement by Share-based Payment Award Equity Instruments Other Than Options Weighted Average Grant Date Fair Value Beginning Balance						$ 26.36
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value				$ 32.72
Share-based Compensation Arrangement By Share-based Payment Award Equity Instruments Other Than Options Issued In Period Weighted Average Grant Date Fair Value				$ 27.90
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period, Weighted Average Grant Date Fair Value		$ 34.77		$ 34.77
Share-based Compensation Arrangement By Share-based Payment Award Equity Instruments Other Than Options Weighted Average Grant Date Fair Value Ending Balance		$ 31.97		$ 31.97
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number		1,380,118		1,380,118		403,108
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value		$ 34.62		$ 34.62		$ 28.70
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period				459,274
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value				$ 30.02
Share-based Compensation Arrangement By Share-based Payment Award Vested Outstanding Number				805,038
Share-based Compensation Arrangement By Share-based Payment Award Expected To Vest				1,311,112
Share-based Compensation Arrangement By Share-based Payment Award Equity Instruments Other Than Options NSTAR Awards Converted To NU RSU's Upon Merger	617,394
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, NSTAR Awards Converted to RSU's Upon Merger, Weighted Average Grant Date Fair Value	$ 36.79
Employee Service Share-based Compensation Performance Share Disclosures [Abstract]
Share-based Compensation Arrangement By Share-based Payment Award Performance Shares Converted to RSUs Upon Merger	451,358
Share-based Compensation Arrangement By Share-based Payment Award Performance Shares Converted to RSUs Upon Merger Weighted Average Grant-Date Fair Value	$ 34.32
Performance Shares [Member]
Employee Service Share Based Compensation Awards Other Than Options [Abstract]
Share-based Compensation Arragement by Share-based Payment Award Equity Instruments Other Than Options Beginning Balance						483,133
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period				226,326
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period				(106,773)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period				0
Share-based Compensation Arrangement by Share-based Payment Award Equity Instruments Other Than Options Ending Balance				151,328
Share-based Compensation Arrangement by Share-based Payment Award Equity Instruments Other Than Options Weighted Average Grant Date Fair Value Beginning Balance						$ 29.18
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value				$ 34.46
Share-based Compensation Arrangement By Share-based Payment Award Equity Instruments Other Than Options Issued In Period Weighted Average Grant Date Fair Value				$ 24.52
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period, Weighted Average Grant Date Fair Value		$ 0		$ 0
Share-based Compensation Arrangement By Share-based Payment Award Equity Instruments Other Than Options Weighted Average Grant Date Fair Value Ending Balance		$ 25.04		$ 25.04
Employee Service Share-based Compensation Performance Share Disclosures [Abstract]
Share-based Compensation Arrangement By Share-based Payment Award Performance Shares Converted to RSUs Upon Merger	(451,358)
Share-based Compensation Arrangement By Share-based Payment Award Performance Shares Converted to RSUs Upon Merger Weighted Average Grant-Date Fair Value	$ 34.32

XML

SUBSEQUENT EVENTS (Details)	6 Months Ended
	Jun. 30, 2012
Subsequent Event [Line Items]
Subsequent Event, Description	On July 25, 2012, NU, NSTAR LLC, NSTAR Gas, CL&P, PSNH, WMECO, and Yankee Gas jointly entered into a five-year $1.15 billion revolving credit facility. The new facility replaced (1) the NSTAR LLC revolving credit facility of $175 million that served to backstop a commercial paper program utilized by NSTAR LLC and was scheduled to expire on December 31, 2012, (2) the NSTAR Gas revolving credit facility of $75 million that expired on June 8, 2012, and (3) the CL&P, PSNH, WMECO, and Yankee Gas joint three-year $400 million and NU parent three-year $500 million unsecured revolving credit facilities that were scheduled to expire on September 24, 2013. The new facility expires on July 25, 2017. Management expects the new facility to be used primarily to backstop the $1.15 billion commercial paper program at NU, which commenced July 25, 2012. On July 25, 2012, NSTAR Electric entered into a five-year $450 million revolving credit facility. This new facility serves to backstop NSTAR Electric’s existing $450 million commercial paper program. This new facility replaced a prior $450 million NSTAR Electric revolving credit facility that was scheduled to expire on December 31, 2012.

XML

Presentation (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

ScheduleOfReclassificationAdjustments

	Transmission Expense				Energy Efficiency Expense
	Three Months Ended		Six Months Ended		Three Months Ended		Six Months Ended
(Millions of Dollars)	June 30, 2011		June 30, 2011		June 30, 2011		June 30, 2011
NU	$	42.2	$	64.8	$	30.0	$	64.4
CL&P		23.2		39.8		21.3		44.7
PSNH		5.0		12.9		2.8		5.8
WMECO		5.3		10.4		5.0		10.4

XML

Merger of NU and NSTAR (Details) (USD $) In Millions, except Share data, unless otherwise specified	0 Months Ended	3 Months Ended		6 Months Ended
	Apr. 09, 2012	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Business Acquisition, Cost of Acquired Entity, Purchase Price [Abstract]
Number of NSTAR Shares Outstanding	103,696,000
Exchange Ratio	1.312
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	136,049,000
Business Acquisition Share Price	$ 36.79
Business Acquisition, Cost of Acquired Entity, Equity Interests Issued and Issuable	$ 5,005.0
Business Acquisition, Cost of Acquired Entity, Other Noncash Consideration	33.0
Business Acquisition, Cost of Acquired Entity, Purchase Price	5,038.0	5,038.0		5,038.0
Business Acquisition, Purchase Price Allocation [Abstract]
Business Acquisition, Purchase Price Allocation, Current Assets		754.0		754.0
Business Acquisition, Purchase Price Allocation, Property, Plant and Equipment		5,155.0		5,155.0
Business Acquisition, Purchase Price Allocation, Goodwill Amount		3,231.0		3,231.0
Business Acquisition, Purchase Price Allocation, Other Noncurrent Assets		2,115.0		2,115.0
Business Acquisition, Purchase Price Allocation, Current Liabilities		(1,332.0)		(1,332.0)
Business Acquisition, Purchase Price Allocation, Other Noncurrent Liabilities		(2,723.0)		(2,723.0)
Business Acquisition, Purchase Price Allocation, Noncurrent Liabilities, Long-term Debt		(2,123.0)		(2,123.0)
Business Aquisition, Purchase Price Allocation, Preferred Stock		(39.0)		(39.0)
Total Purchase Price	5,038.0	5,038.0		5,038.0
Business Acquisition, Pro Forma Information [Abstract]
Business Acquisition, Pro Forma Revenue		1,629.0	1,691.0	3,459.0	3,754.0
Business Acquisition, Pro Forma Net Income (Loss)		133.0	142.0	243.0	328.0
Business Acquisition, Pro Forma Earnings Per Share, Basic		$ 0.42	$ 0.45	$ 0.77	$ 1.05
Business Acquisition, Pro Forma Earnings Per Share, Diluted		$ 0.42	$ 0.45	$ 0.77	$ 1.04
CustomerRateCreditsForBusinessCombination		46.0		46.0
StormCostDeferralReduction		40.0		40.0
EnergyEfficiencyFundEstablishment		15.0		15.0
TotalImpactOfSettlementAgreements		101.0		101.0
BusinessCombinationAfterTaxTransactionCosts		29.0	2.0	31.0	16.0
AfterTaxSettlementCostsIncurred		60.0	0	60.0	0
AfterTaxCostsIncurredinConnectionwithMerger		89.0	2.0	91.0	16.0
Business Combination, Description [Abstract]
Business Acquisition, Percentage of Voting Interests Acquired	100.00%
Common Stock, Shares, Outstanding	314,000,000
Business Acquisition, Number of Shares Awards Vested Immediately Prior to Merger				109,000
Business Aquisition, Description of Settlement Agreements				Regulatory Approvals: On February 15, 2012, NU and NSTAR reached comprehensive settlement agreements with the Massachusetts Attorney General and the DOER related to the merger. On April 4, 2012, the DPU approved the settlement agreements and the merger of NU and NSTAR. On March 13, 2012, NU and NSTAR reached a comprehensive settlement agreement with both the Connecticut Attorney General and the Connecticut Office of Consumer Counsel. On April 2, 2012, the PURA approved the settlement agreement and the merger of NU and NSTAR. The settlement agreements included base distribution rate freezes until December 1, 2014 for CL&P and through 2015 for NSTAR Electric, NSTAR Gas and WMECO.
Nstar [Member]
Business Combination, Description [Abstract]
RevenuesfromAcquiredCompany				601.3
NetIncomeFromAcquiredCompany				35.9
The Connecticut Light And Power Company [Member]
Business Acquisition, Pro Forma Information [Abstract]
CustomerRateCreditsForBusinessCombination		25.0		25.0
StormCostDeferralReduction		40.0		40.0
TotalImpactOfSettlementAgreements		65.0		65.0
NSTAR Electric Company [Member]
Business Acquisition, Pro Forma Information [Abstract]
CustomerRateCreditsForBusinessCombination		15.0		15.0
TotalImpactOfSettlementAgreements		15.0		15.0
Western Massachusetts Electric Company [Member]
Business Acquisition, Pro Forma Information [Abstract]
CustomerRateCreditsForBusinessCombination		3.0		3.0
TotalImpactOfSettlementAgreements		$ 3.0		$ 3.0

XML

EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Earnings Per Share Basic And Diluted [Table Text Block]

The following table sets forth the components of basic and diluted EPS:
		For the Three Months Ended				For the Six Months Ended
(Millions of Dollars, except share information)		June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
Net Income Attributable to Controlling Interest		$	44.3	$	77.3	$	143.6	$	191.4
Weighted Average Common Shares Outstanding:
	Basic		301,047,753		177,347,374		239,551,735		177,267,791
	Dilutive Effect		769,131		279,618		575,434		286,204
	Diluted		301,816,884		177,626,992		240,127,169		177,553,995
Basic and Diluted EPS		$	0.15	$	0.44	$	0.60	$	1.08

XML

Long-Term Contractual Arrangements (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Long-term Purchase Commitment [Table Text Block]

	July - December
(Millions of Dollars)	2012		2013		2014		2015		2016		Thereafter		Totals
Supply/Stranded Cost Contracts/Obligations	$	16.3	$	28.7	$	33.0	$	32.9	$	12.6	$	7.1	$	130.6
Renewable Energy Supply Contracts		33.7		87.3		86.6		87.9		52.1		252.8		600.4
Transmission Support Commitments		1.9		3.7		3.6		3.5		0.0		0.0		12.7
Natural Gas Procurement Contracts		108.5		54.0		47.5		24.7		21.6		78.5		334.8
Future Minimum Operating Lease Payments		6.4		11.5		8.4		7.3		5.7		12.2		51.5
Electric Interconnection Agreement		1.7		3.4		3.4		3.4		3.3		41.1		56.3
Totals	$	168.5	$	188.6	$	182.5	$	159.7	$	95.3	$	391.7	$	1,186.3

XML

DERIVATIVE INSTURMENTS (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	$ (113,188,000)		$ (113,188,000)		$ (107,558,000)
Derivative Liabilities, Noncurrent	(946,621,000)		(946,621,000)		(959,876,000)
Derivative Assets Noncurrent	93,616,000		93,616,000		98,357,000
Current Derivative Assets Consolidated	12,800,000		12,800,000		11,000,000
Other Derivatives Not Designated As Hedging Instruments At Fair Value Net Total Abstract
Description of Derivative Activity Volume			NU also has NYMEX future contracts in order to reduce variability associated with the purchase price of approximately 6.2 million MMBtu of natural gas.
Effect Of Fair Value Hedges On Results Of Operations [Abstract]
Interest Realized In Earnings On Fair Value Hedge		2,700,000	2,500,000	5,400,000
Cash Flow Hedges Derivative Instruments At Fair Value Net [Abstract]
Cash Flow Hedge Gain Loss Reclassified To Interest Expense Net	700,000	100,000	1,600,000	200,000
Description Of Cash Flow Hedge Activity				In 2011, PSNH and WMECO settled interest rate swaps associated with $280 million and $50 million, respectively, of long-term debt issuances and as a result PSNH and WMECO recorded pre-tax reductions of $18.2 million and $6.9 million, respectively, to AOCI that are being amortized over the remaining lives of the associated debt.
Derivative Credit Risk Related Contingent Features Abstract
Derivative Net Liability Position Aggregate Fair Value	(21,100,000)		(21,100,000)		(23,500,000)
Collateral Already Posted Aggregate Fair Value	4,300,000		4,300,000		4,100,000
Additional Collateral Aggregate Fair Value	17,300,000		17,300,000		19,900,000
Minimum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
FairValueInputsDiscountForLackOfMarketability			10.00%
Fair Value inputs, Capacity Prices	1.4		1.4
Fair Value Inpts, Energy Prices	41		41
Fair Value Inputs, Renewable Energy Credit Prices	25		25
Fair Value Inputs, Forward Reserve	0.5		0.5
Maximum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
FairValueInputsDiscountForLackOfMarketability			32.00%
Fair Value inputs, Capacity Prices	10.18		10.18
Fair Value Inpts, Energy Prices	78		78
Fair Value Inputs, Renewable Energy Credit Prices	84		84
Fair Value Inputs, Forward Reserve	0.5		0.5
The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(97,704,000)		(97,704,000)		(95,881,000)
Derivative Liabilities, Noncurrent	(910,115,000)		(910,115,000)		(935,849,000)
Derivative Assets Noncurrent	91,146,000		91,146,000		93,755,000
The Connecticut Light And Power Company [Member] | Minimum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
Fair Value inputs, Capacity Prices	1.4		1.4
Fair Value Inpts, Energy Prices	47		47
Fair Value Inputs, Forward Reserve	0.5		0.5
The Connecticut Light And Power Company [Member] | Maximum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
Fair Value inputs, Capacity Prices	9.51		9.51
Fair Value Inpts, Energy Prices	52		52
Fair Value Inputs, Forward Reserve	0.5		0.5
Western Massachusetts Electric Company [Member] | Minimum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
Fair Value inputs, Capacity Prices	1.4		1.4
Fair Value Inpts, Energy Prices	41		41
Fair Value Inputs, Renewable Energy Credit Prices	25		25
Western Massachusetts Electric Company [Member] | Maximum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
Fair Value inputs, Capacity Prices	10.18		10.18
Fair Value Inpts, Energy Prices	78		78
Fair Value Inputs, Renewable Energy Credit Prices	84		84
NSTAR Electric Company [Member] | Minimum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
Fair Value inputs, Capacity Prices	1.4		1.4
Fair Value Inputs, Renewable Energy Credit Prices	25		25
NSTAR Electric Company [Member] | Maximum [Member]
Fairvalueinputsquantitativeinformationabstract [Abstract]
Fair Value inputs, Capacity Prices	10.18		10.18
Fair Value Inputs, Renewable Energy Credit Prices	60		60
Fair Value Inputs Level 2 [Member] | Public Service Company Of New Hampshire [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	1,000,000		1,000,000
Fair Value Inputs Level 2 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(13,900,000)		(13,900,000)
Derivative Liabilities, Noncurrent	(8,800,000)		(8,800,000)
Derivative Assets Noncurrent	400,000		400,000
Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	6,000,000		6,000,000		6,300,000
Derivative Liabilities - Current	(97,700,000)		(97,700,000)		(95,900,000)
Derivative Liabilities, Noncurrent	(910,100,000)		(910,100,000)		(935,800,000)
Derivative Assets Noncurrent	91,100,000		91,100,000		93,800,000
Fair Value Inputs Level 3 [Member] | Western Massachusetts Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(900,000)		(900,000)		(100,000)
Derivative Liabilities, Noncurrent	(12,600,000)		(12,600,000)		(7,200,000)
Fair Value Inputs Level 3 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	5,800,000		5,800,000		4,700,000
Derivative Liabilities - Current					(11,600,000)
Derivative Liabilities, Noncurrent					(16,900,000)
Derivative Assets Noncurrent	2,100,000		2,100,000		4,600,000
Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(700,000)		(700,000)
Derivative Liabilities, Noncurrent	(15,100,000)		(15,100,000)
Netting And Collateral [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	(12,100,000)		(12,100,000)		(11,600,000)
Derivative Liabilities - Current	4,600,000		4,600,000		4,500,000
Derivative Liabilities, Noncurrent	0		0		400,000
Derivative Assets Noncurrent	(76,200,000)		(76,200,000)		(80,400,000)
Netting And Collateral [Member] | Fair Value Inputs Level 2 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	4,600,000		4,600,000
Derivative Assets Noncurrent	(100,000)		(100,000)
Netting And Collateral [Member] | Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	(12,100,000)		(12,100,000)		(11,600,000)
Derivative Assets Noncurrent	(76,100,000)		(76,100,000)		(80,400,000)
Netting And Collateral [Member] | Fair Value Inputs Level 3 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current					4,500,000
Derivative Liabilities, Noncurrent					400,000
Derivative Assets Noncurrent	0		0
Designated As Hedging Instrument [Member] | Fair Value Inputs Level 2 [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current					2,300,000
Commodity [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	24,900,000		24,900,000		22,600,000
Derivative Liabilities - Current	(117,800,000)		(117,800,000)		(112,100,000)
Derivative Liabilities, Noncurrent	(946,600,000)		(946,600,000)		(960,300,000)
Derivative Assets Noncurrent	169,800,000		169,800,000		178,800,000
Other Derivatives Not Designated As Hedging Instruments At Fair Value Net Total Abstract
Description of Derivative Activity Volume			As of June 30, 2012 and December 31, 2011, NU had approximately 37 thousand MWh and 123 thousand MWh, respectively, of supply volumes remaining in its unregulated wholesale portfolio when expected sales are compared with supply contracts. Commodity supply and price risk management: As required by regulation, CL&P has capacity-related contracts with generation facilities. These contracts and similar UI contracts have an expected capacity of 787 MW. CL&P has a sharing agreement with UI, with 80 percent of each contract allocated to CL&P and 20 percent allocated to UI. The capacity contracts have terms up to 15 years and obligate the utilities to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the forward capacity market price received in the ISO-NE capacity markets. In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020. NSTAR Electric has a renewable energy contract to purchase approximately 60 thousand MWh of energy per year through 2017. NSTAR Electric also has a capacity related contract for approximately 25 MW to 35 MW that extends through 2019. WMECO has a renewable energy contract to purchase 0.1 million MWh of energy per year through 2027 with a facility that is expected to achieve commercial operation by December 2012.
Derivative Instruments Not Designated As Hedging Instruments Gain Loss Net Abstract
Derivative Instruments Gain Loss Recognized In Income Net	(200,000)	500,000	(1,000,000)	800,000
Derivative Instruments Gain Loss Recognized In Regulatory Asset Liability	(40,800,000)	(14,700,000)	(33,500,000)	(45,200,000)
Commodity [Member] | Fair Value Inputs Level 2 [Member] | Public Service Company Of New Hampshire [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	1,000,000		1,000,000
Commodity [Member] | Fair Value Inputs Level 2 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(18,500,000)		(18,500,000)
Derivative Liabilities, Noncurrent	(8,800,000)		(8,800,000)
Derivative Assets Noncurrent	500,000		500,000
Commodity [Member] | Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	18,100,000		18,100,000		17,900,000
Derivative Liabilities - Current	(97,700,000)		(97,700,000)		(95,900,000)
Derivative Liabilities, Noncurrent	(910,100,000)		(910,100,000)		(935,800,000)
Derivative Assets Noncurrent	167,200,000		167,200,000		174,200,000
Commodity [Member] | Fair Value Inputs Level 3 [Member] | Western Massachusetts Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(900,000)		(900,000)		(100,000)
Derivative Liabilities, Noncurrent	(12,600,000)		(12,600,000)		(7,200,000)
Commodity [Member] | Fair Value Inputs Level 3 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	5,800,000		5,800,000		4,700,000
Derivative Liabilities - Current					(16,100,000)
Derivative Liabilities, Noncurrent					(17,300,000)
Derivative Assets Noncurrent	2,100,000		2,100,000		4,600,000
Commodity [Member] | Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(700,000)		(700,000)
Derivative Liabilities, Noncurrent	$ (15,100,000)		$ (15,100,000)		$ (3,400,000)

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COMMON SHARES (Details) (USD $)	0 Months Ended
	Apr. 09, 2012	Jun. 30, 2012	Dec. 31, 2011
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share		$ 5	$ 5
Common Stock Shares Authorized		380,000,000	380,000,000
Common Stock Shares Issued		332,450,199	196,052,770
Treasury Stock Shares		18,674,189	18,894,078
Common Stock Issuance, Merger with NSTAR [Abstract]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	136,049,000
The Connecticut Light And Power Company [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share		$ 10	$ 10
Common Stock Shares Authorized		24,500,000	24,500,000
Common Stock Shares Issued		6,035,205	6,035,205
Public Service Company Of New Hampshire [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share		$ 1	$ 1
Common Stock Shares Authorized		100,000,000	100,000,000
Common Stock Shares Issued		301	301
Western Massachusetts Electric Company [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share		$ 25	$ 25
Common Stock Shares Authorized		1,072,471	1,072,471
Common Stock Shares Issued		434,653	434,653
NSTAR Electric Company [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share		$ 1	$ 1
Common Stock Shares Authorized		100,000,000	100,000,000
Common Stock Shares Issued		100	100

XML

Guarantees and Indemnifications (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2012
Guarantee Of Financial Obligations Of Npt [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	$ 25.0
Various Subsidiary Surety Bonds Expiring Between 2012 And 2013 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	35.0
Guarantee Of Letters Of Credit [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	19.5
Guarantee Of Rocky River Reality And Nusco Lease Payments For Real Estate And Vehicles Expiring 2019 Through 2024 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	21.9
Guarantee Of Nuei Surety Bonds Insurance Bonds And Performance Guarantees [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	109.4
Guarantee Of Ngs Performance Expiring In 2020 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	14.0
Guarantee Of Ngs Insurance Bond [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	1.2
Guarantee Of Es Boulos Surety Bonds Expiring Upon Project Completion [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	48.8
Guarantee Of Select Energy Wholesale Purchase Contracts [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	45.4
Guarantee of NE Hydro Companies' Long-Term Debt [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	$ 6.6

XML

Other Income, Net (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Component Of Other Income Nonoperating [Line Items]
Other Income/(Loss), Net	$ 1,806	$ 7,334	$ 10,580	$ 17,647
The Connecticut Light And Power Company [Member]
Component Of Other Income Nonoperating [Line Items]
Other Income/(Loss), Net	447	2,058	5,747	6,663
Public Service Company Of New Hampshire [Member]
Component Of Other Income Nonoperating [Line Items]
Other Income/(Loss), Net	549	4,361	2,590	8,820
Western Massachusetts Electric Company [Member]
Component Of Other Income Nonoperating [Line Items]
Other Income/(Loss), Net	$ 188	$ 242	$ 1,280	$ 981

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DERIVATIVE INSTRUMENTS

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Derivative Instruments and Hedging Activities Disclosure [Text Block]

5.       DERIVATIVE INSTRUMENTS

The Regulated companies purchase and procure energy and energy-related products for their customers, which are subject to price volatility. The costs associated with supplying energy to customers are recoverable through customer rates. The Company manages the risks associated with the price volatility of energy and energy-related products through the use of derivative contracts, many of which meet the definition of and are designated as "normal purchases or normal sales," (normal), and the use of nonderivative contracts.

Derivative contracts that are not recorded as normal under the applicable accounting guidance are recorded at fair value as current or long-term derivative assets or liabilities. For the Regulated companies, regulatory assets or liabilities are recorded for the changes in fair values of derivatives, as these contracts are part of current regulated operating costs, or have an allowed recovery mechanism, and management believes that these costs will continue to be recovered from or refunded to customers in cost-of-service, regulated rates. Changes in fair values of NU's remaining unregulated wholesale marketing contracts are included in Net Income. The costs and benefits of derivative contracts that meet the definition of normal are recognized in Operating Expenses or Operating Revenues on the accompanying unaudited condensed consolidated statements of income, as applicable, as electricity or natural gas is delivered.

CL&P, NSTAR Electric and WMECO mitigate the risks associated with the price volatility of energy and energy-related products through the use of SS, LRS, and basic service contracts, which fix the price of electricity purchased for customers and are accounted for as normal. CL&P has entered into derivatives, including FTR contracts, to manage the risk of congestion costs associated with its SS and LRS contracts. As required by regulation, CL&P has also entered into derivative and nonderivative contracts for the purchase of energy and energy-related products and contracts related to capacity. NSTAR Electric and WMECO have contracts to purchase renewable energy that are derivatives. NSTAR Electric also has a capacity related contract. While the risks managed by these contracts relate to capacity prices, regional congestion costs, and the development of renewable energy that are not specific to CL&P, NSTAR Electric and WMECO, electric distribution companies are required to enter into these contracts.NU also has NYMEX future contracts in order to reduce variability associated with the purchase price of approximately 6.2 million MMBtu of natural gas.

The costs or benefits from all of these derivative contracts are recoverable from or refundable to customers, and, therefore changes in fair value are recorded as Regulatory Assets or Regulatory Liabilities on the accompanying unaudited condensed consolidated balance sheets.

NU, through Select Energy, has one remaining fixed price forward sales contract to serve electrical load that is part of its remaining unregulated wholesale energy marketing portfolio. NU mitigates the price risk associated with this contract through the use of forward purchase contracts. The contracts are accounted for at fair value, and changes in their fair values are recorded in Purchased Power, Fuel and Transmission on the accompanying unaudited condensed consolidated statements of income.

The gross fair values of derivative assets and liabilities with the same counterparty are offset and reported as net Derivative Assets or Derivative Liabilities, with current and long-term portions, in the accompanying unaudited condensed consolidated balance sheets. Cash collateral posted or collected under master netting agreements is recorded as an offset to the derivative asset or liability. The following tables present the gross fair values of contracts, including capacity contracts required by regulation, and the net amounts recorded as current or long-term derivative liability or asset, by primary underlying risk exposure or purpose:

		As of June 30, 2012
			Commodity				Net Amount
			Supply and				Recorded as
			Price Risk		Collateral		Derivative
(Millions of Dollars)			Management		and Netting (1)		Asset/(Liability) (2)
Current Derivative Assets:
Level 2:
	PSNH		$	1.0	$	-	$	1.0
Level 3:
	CL&P			18.1		(12.1)		6.0
	Other			5.8		-		5.8
Total Current Derivative Assets			$	24.9	$	(12.1)	$	12.8
Long-Term Derivative Assets:
Level 2:
	Other		$	0.5	$	(0.1)	$	0.4
Level 3:
	CL&P			167.2		(76.1)		91.1
	Other			2.1		-		2.1
Total Long-Term Derivative Assets			$	169.8	$	(76.2)	$	93.6
Current Derivative Liabilities:
Level 2:
	Other		$	(18.5)	$	4.6	$	(13.9)
Level 3:
	CL&P			(97.7)		-		(97.7)
	NSTAR Electric			(0.7)		-		(0.7)
	WMECO			(0.9)		-		(0.9)
Total Current Derivative Liabilities			$	(117.8)	$	4.6	$	(113.2)
Long-Term Derivative Liabilities:
Level 2:
	Other		$	(8.8)	$	-	$	(8.8)
Level 3:
	CL&P			(910.1)		-		(910.1)
	NSTAR Electric			(15.1)		-		(15.1)
	WMECO			(12.6)		-		(12.6)
Total Long-Term Derivative Liabilities			$	(946.6)	$	-	$	(946.6)

		As of December 31, 2011
			Commodity				Net Amount
			Supply and				Recorded as
			Price Risk		Collateral		Derivative
(Millions of Dollars)			Management		and Netting (1)		Asset/(Liability) (2)
Current Derivative Assets:
Level 3:
	CL&P		$	17.9	$	(11.6)	$	6.3
	Other			4.7		-		4.7
Total Current Derivative Assets(3)			$	22.6	$	(11.6)	$	11.0
Long-Term Derivative Assets:
Level 3:
	CL&P		$	174.2	$	(80.4)	$	93.8
	Other			4.6		-		4.6
Total Long-Term Derivative Assets			$	178.8	$	(80.4)	$	98.4
Current Derivative Liabilities:
Level 3:
	CL&P		$	(95.9)	$	-	$	(95.9)
	WMECO			(0.1)		-		(0.1)
	Other			(16.1)		4.5		(11.6)
Total Current Derivative Liabilities			$	(112.1)	$	4.5	$	(107.6)
Long-Term Derivative Liabilities:
Level 3:
	CL&P		$	(935.8)	$	-	$	(935.8)
	WMECO			(7.2)		-		(7.2)
	Other			(17.3)		0.4		(16.9)
Total Long-Term Derivative Liabilities(4)			$	(960.3)	$	0.4	$	(959.9)

(1)       Amounts represent cash collateral posted under master netting agreements and the netting of derivative assets and liabilities. See "Credit Risk" below for discussion of cash collateral posted under master netting agreements.

(2)       Current derivative assets are included in Prepayments and Other Current Assets on the accompanying unaudited condensed consolidated balance sheets. NSTAR Electric and WMECO derivative liabilities are included in Other Current Liabilities and Other Long-Term Liabilities on their accompanying unaudited condensed consolidated balance sheets.The NSTAR Electric amounts are not included in NU consolidated as of December31, 2011.

(3)In addition to the amounts reflected in the table, as of December 31, 2011, NU had $2.3 million of hedging instruments that were classified as Level 2 in the fair value hierarchy, which related to a fair value hedge that expired on April 2, 2012 and was included in Prepayments and Other Current Assets on the accompanying unaudited condensed consolidated balance sheet.

(4)       As of December 31, 2011, NSTAR Electric had $3.4million of derivative liabilities classified as Level 3 within the fair value hierarchy and included in Other Long-Term Liabilities on the accompanying NSTAR Electric unaudited condensed consolidated balance sheet. These amounts are not included in NU consolidated as of December31, 2011.

For further information on the fair value of derivative contracts, see Note 1E, "Summary of Significant Accounting Policies - Fair Value Measurements."

Derivatives not designated as hedges

Commodity supply and price risk management: As required by regulation, CL&P has capacity-related contracts with generation facilities. These contracts and similar UI contracts have an expected capacity of 787 MW. CL&P has a sharing agreement with UI, with 80 percent of each contract allocated to CL&P and 20 percent allocated to UI. The capacity contracts have terms up to 15 years and obligate the utilities to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the forward capacity market price received in the ISO-NE capacity markets. In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020.

NSTAR Electric has a renewable energy contract to purchase approximately 60 thousand MWh of energy per year through 2017. NSTAR Electric also has a capacity related contract for approximately 25 MW to 35 MW that extends through 2019.

WMECO has a renewable energy contract to purchase 0.1 million MWh of energy per year through 2027 with a facility that is expected to achieve commercial operation by December 2012.

As of June 30, 2012 and December 31, 2011, NU had approximately 37 thousand MWh and 123 thousand MWh, respectively, of supply volumes remaining in its unregulated wholesale portfolio when expected sales are compared with supply contracts.

The following table presents the realized and unrealized gains/(losses) associated with NU's derivative contracts not designated as hedges (See Level 3 tables below for CL&P, NSTAR Electric and WMECO gains and losses on derivative contracts):

		Amounts Recognized on Derivative
Location of Amount		For the Three Months Ended				For the Six Months Ended
Recognized on Derivative		June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)
NU
Balance Sheet:
	Regulatory Assets		(40.8)		(14.7)		(33.5)		(45.2)
Statement of Income:
	Purchased Power, Fuel and Transmission		(0.2)		0.5		(1.0)		0.8

Hedging instruments

Fair Value Hedge: NU parent had a fixed to floating interest rate swap on its $263 million, fixed rate senior note that matured on April 1, 2012. This interest rate swap qualified and was designated as a fair value hedge.Prior to the settlement of the swap on April 2, 2012, $2.5 million of interest benefit was recorded in net income in the first quarter of 2012. For the three and six months ended June 30, 2011, $2.7 million and $5.4 million of interest benefit was recorded in net income, respectively.

Cash Flow Hedges:In 2011, PSNH and WMECO settled interest rate swaps associated with $280 million and $50million, respectively, of long-term debt issuances and as a result PSNH and WMECO recorded pre-tax reductions of $18.2 million and $6.9 million, respectively,to AOCI that are being amortized over the remaining lives of the associated debt. NU reclassified $0.7million and $1.6million of losses from AOCI into interest expense for the three and six months ended June 30, 2012, respectively. These amounts were $0.1 million and $0.2 million for the three and six months ended June 30, 2011, respectively.

Credit Risk

Certain of NU's contracts contain credit risk contingent features. These features require NU to maintain investment grade credit ratings from the major rating agencies and to post cash or standby LOCs as collateral for contracts in a net liability position over specified credit limits. The following summarizes the fair value of derivative contracts that were in a liability position and subject to credit risk contingent features, the fair value of cash collateral, and the additional collateral in the form of LOCs that would be required to be posted by NU if the unsecured debt credit ratings of NU parent were downgraded to below investment grade as of June 30, 2012 and December 31, 2011:

As of June 30, 2012

As of December 31, 2011

Additional Standby

Additional Standby

Fair Value

LOCs Required if

Fair Value

LOCs Required if

Subject to Credit

Cash

Downgraded

Subject to Credit

Cash

Downgraded

Risk Contingent

Collateral

Below Investment

Risk Contingent

Collateral

Below Investment

(Millions of Dollars)

Features

Posted

Grade

Features

Posted

Grade

NU

$

(21.1)

$

4.3

$

17.3

$

(23.5)

$

4.1

$

19.9

Fair Value Measurements of Derivative Instruments

Valuation of Derivative Instruments: Derivative contracts classified as Level 2 in the fair value hierarchy relate to the financial contracts for natural gas futures and the remaining unregulated wholesale marketing sourcing contracts to purchase energy for periods in which prices are quoted in an active market. Prices are obtained from broker quotes and are based on actual market activity. The contracts are valued using the mid-point of the bid-ask spread. Valuations of these contracts also incorporate discount rates using the yield curve approach.

The fair value of derivative contracts classified as Level 3 utilize significant unobservable inputs. The fair value is modeled using income techniques, such as discounted cash flow approaches adjusted for assumptions relating to exit price. Significant observable inputs for valuations of these contracts include energy and energy-related product prices in future years for which quoted prices in an active market exist. Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy and energy-related products, and accounting requirements. The future power and capacity prices for periods that are not quoted in an active market or established at auction are based on available market data and are escalated based on estimates of inflation to address the full time period of the contract.

Valuations of derivative contracts using discounted cash flow methodology include assumptions regarding the timing and likelihood of scheduled payments and also reflect non-performance risk, including credit, using the default probability approach based on the counterparty's credit rating for assets and the company's credit rating for liabilities. Valuations incorporate estimates of premiums or discounts that would be required by a market participant to arrive at an exit price, using historical market transactions adjusted for the terms of the contract.

The following is a summary of NU's, including CL&P's, NSTAR Electric's and WMECO's, Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts

	Range	Period Covered
Energy Prices:
NU	$41 - $78 per MWh	2017 - 2027
CL&P	$47 - $52 per MWh	2017 - 2020
WMECO	$41 - $78 per MWh	2017 - 2027
Capacity Prices:
NU	$1.40 - $10.18 per kW-Month	2016 - 2027
CL&P	$1.40 - $9.51 per kW-Month	2016 - 2026
NSTAR Electric	$1.40 - $10.18 per kW-Month	2016 - 2027
WMECO	$1.40 - $10.18 per kW-Month	2016 - 2027
Forward Reserve:
NU, CL&P	$0.50 per kW-Month	2012 - 2024
REC Prices:
NU	$25 - $84 per REC	2012 - 2027
NSTAR Electric	$25 - $60 per REC	2012 - 2017
WMECO	$25 - $84 per REC	2012 - 2027

Exit price premiums of 10 percent through 32 percent are also applied on these contracts.

Significant increases or decreases in future power or capacity prices in isolation would decrease or increase, respectively, the fair value of the derivative liability. Any increases in the risk premiums would increase the fair value of the derivative liabilities. Changes in these fair values are recorded as a regulatory asset or liability and would not impact net income.

Valuations using significant unobservable inputs: The following tables present changes for the three and six months ended June 30, 2012 and 2011 in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis. The derivative assets and liabilities are presented on a net basis. The fair value as of January1, 2012 reflects a reclassification of remaining unregulated wholesale marketing sourcing contracts that had previously been presented as a portfolio along with the unregulated wholesale marketing sales contract as Level 3 under the highest and best use valuation premise. These contracts are now classified within Level 2 of the fair value hierarchy.

		For the Three Months Ended				For the Six Months Ended
		June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)		NU		NU		NU		NU
Derivatives, Net:
Fair Value as of Beginning of Period		$	(901.5)	$	(872.7)	$	(962.2)	$	(840.2)
Increase due to Merger with NSTAR			(5.4)		-		(5.4)		-
Transfer to Level 2			-		-		32.2		-
Net Realized/Unrealized Gains/(Losses) Included in:
	Net Income(2)		(0.7)		0.5		7.4		0.8
	Regulatory Assets		(42.6)		(13.9)		(35.4)		(45.2)
Settlements			18.1		(0.1)		31.3		(1.6)
Fair Value as of End of Period		$	(932.1)	$	(886.2)	$	(932.1)	$	(886.2)

		For the Three Months Ended
		June 30, 2012						June 30, 2011
(Millions of Dollars)		CL&P		NSTAR Electric		WMECO		CL&P		NSTAR Electric(1)
Derivatives, Net:
Fair Value as of Beginning of Period		$	(899.6)	$	(5.4)	$	(12.3)	$	(842.6)	$	(2.1)
Net Realized/Unrealized Gains/(Losses)
	Included in Regulatory Assets		(31.8)		(9.6)		(1.2)		(13.9)		1.9
Settlements			20.7		(0.8)		-		(2.2)		(0.8)
Fair Value as of End of Period		$	(910.7)	$	(15.8)	$	(13.5)	$	(858.7)	$	(1.0)
		For the Six Months Ended
		June 30, 2012						June 30, 2011
(Millions of Dollars)		CL&P		NSTAR Electric(1)		WMECO		CL&P		NSTAR Electric(1)
Derivatives, Net:
Fair Value as of Beginning of Period		$	(931.6)	$	(3.4)	$	(7.3)	$	(806.1)	$	(2.4)
Net Realized/Unrealized Gains/(Losses)
	Included in Regulatory Assets		(21.0)		(10.2)		(6.2)		(45.1)		3.0
Settlements			41.9		(2.2)		-		(7.5)		(1.6)
Fair Value as of End of Period		$	(910.7)	$	(15.8)	$	(13.5)	$	(858.7)	$	(1.0)

• NSTAR Electric amounts are included in NU consolidated from the date of the merger, April 10, 2012, through June 30, 2012.
• The Net Income impact for the three and six months ended June 30, 2012 relate to the unregulated wholesale marketing sales contract and are offset by the gains/(losses) on the unregulated sourcing contracts classified as Level 2 in the fair value hierarchy, resulting in total losses of $0.2 million and $1 million for the three and six months ended June30, 2012, respectively.

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Long-Term Contractual Arrangements (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Jun. 30, 2012
Long-term Purchase Commitment [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	$ 168.5
Unrecorded Unconditional Purchase Obligation, Due within Two Years	188.6
Unrecorded Unconditional Purchase Obligation, Due within Three Years	182.5
Unrecorded Unconditional Purchase Obligation, Due within Four Years	159.7
Unrecorded Unconditional Purchase Obligation, Due within Five Years	95.3
Unrecorded Unconditional Purchase Obligation, Due after Five Years	391.7
Unrecorded Unconditional Purchase Obligation, Purchases	1,186.3
Operating Leases, Future Minimum Payments Due, Current	6.4
Operating Leases, Future Minimum Payments, Due in Two Years	11.5
Operating Leases, Future Minimum Payments, Due in Three Years	8.4
Operating Leases, Future Minimum Payments, Due in Four Years	7.3
Operating Leases, Future Minimum Payments Due Thereafter	12.2
Operating Leases, Future Minimum Payments Due	51.5
Operating Leases, Future Minimum Payments, Due in Five Years	5.7
Supply And Stranded Costs [Member]
Long-term Purchase Commitment [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	16.3
Unrecorded Unconditional Purchase Obligation, Due within Two Years	28.7
Unrecorded Unconditional Purchase Obligation, Due within Three Years	33.0
Unrecorded Unconditional Purchase Obligation, Due within Four Years	32.9
Unrecorded Unconditional Purchase Obligation, Due within Five Years	12.6
Unrecorded Unconditional Purchase Obligation, Due after Five Years	7.1
Unrecorded Unconditional Purchase Obligation, Purchases	130.6
Renewable Energy Supply Contracts [Member]
Long-term Purchase Commitment [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	33.7
Unrecorded Unconditional Purchase Obligation, Due within Two Years	87.3
Unrecorded Unconditional Purchase Obligation, Due within Three Years	86.6
Unrecorded Unconditional Purchase Obligation, Due within Four Years	87.9
Unrecorded Unconditional Purchase Obligation, Due within Five Years	52.1
Unrecorded Unconditional Purchase Obligation, Due after Five Years	252.8
Unrecorded Unconditional Purchase Obligation, Purchases	600.4
Transmission Support Commitments [Member]
Long-term Purchase Commitment [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	1.9
Unrecorded Unconditional Purchase Obligation, Due within Two Years	3.7
Unrecorded Unconditional Purchase Obligation, Due within Three Years	3.6
Unrecorded Unconditional Purchase Obligation, Due within Four Years	3.5
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0
Unrecorded Unconditional Purchase Obligation, Purchases	12.7
Natural Gas Procurement Contracts [Member]
Long-term Purchase Commitment [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	108.5
Unrecorded Unconditional Purchase Obligation, Due within Two Years	54.0
Unrecorded Unconditional Purchase Obligation, Due within Three Years	47.5
Unrecorded Unconditional Purchase Obligation, Due within Four Years	24.7
Unrecorded Unconditional Purchase Obligation, Due within Five Years	21.6
Unrecorded Unconditional Purchase Obligation, Due after Five Years	78.5
Unrecorded Unconditional Purchase Obligation, Purchases	334.8
Electric Interconnection Contracts [Member]
Long-term Purchase Commitment [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	1.7
Unrecorded Unconditional Purchase Obligation, Due within Two Years	3.4
Unrecorded Unconditional Purchase Obligation, Due within Three Years	3.4
Unrecorded Unconditional Purchase Obligation, Due within Four Years	3.4
Unrecorded Unconditional Purchase Obligation, Due within Five Years	3.3
Unrecorded Unconditional Purchase Obligation, Due after Five Years	41.1
Unrecorded Unconditional Purchase Obligation, Purchases	$ 56.3

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SEGMENTS (Tables)

6 Months Ended

Jun. 30, 2012

Segment Reporting Information [Line Items]

Schedule Of Segment Reporting Information By Segment Text Block

		For the Three Months Ended June 30, 2012
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	1,229.9	$	133.5	$	228.7	$	230.2	$	(193.6)	$	1,628.7
Depreciation and Amortization			(153.3)		(12.4)		(28.6)		(17.7)		1.2		(210.8)
Other Operating Expenses			(1,004.8)		(115.8)		(65.5)		(263.0)		190.7		(1,258.4)
Operating Income/(Loss)			71.8		5.3		134.6		(50.5)		(1.7)		159.5
Interest Expense			(44.8)		(8.8)		(26.2)		(11.1)		1.9		(89.0)
Interest Income			1.0		-		0.1		1.4		(1.4)		1.1
Other Income/(Loss), Net			(0.2)		0.1		0.7		117.9		(117.8)		0.7
Income Tax (Expense)/Benefit			(6.9)		1.3		(44.8)		25.0		(0.7)		(26.1)
Net Income/(Loss)			20.9		(2.1)		64.4		82.7		(119.7)		46.2
Net Income Attributable
	to Noncontrolling Interests		(1.2)		-		(0.7)		-		-		(1.9)
Net Income/(Loss) Attributable
	to Controlling Interest	$	19.7	$	(2.1)	$	63.7	$	82.7	$	(119.7)	$	44.3

		For the Six Months Ended June 30, 2012
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	2,016.0	$	272.5	$	391.6	$	363.4	$	(315.2)	$	2,728.3
Depreciation and Amortization			(225.4)		(20.1)		(49.8)		(21.6)		1.5		(315.4)
Other Operating Expenses			(1,627.0)		(218.0)		(113.2)		(397.8)		317.0		(2,039.0)
Operating Income/(Loss)			163.6		34.4		228.6		(56.0)		3.3		373.9
Interest Expense			(77.9)		(14.3)		(45.8)		(20.4)		2.9		(155.5)
Interest Income			2.1		-		0.3		2.6		(2.7)		2.3
Other Income, Net			4.2		0.1		3.9		240.5		(240.4)		8.3
Income Tax (Expense)/Benefit			(28.3)		(7.6)		(75.6)		31.0		(1.5)		(82.0)
Net Income			63.7		12.6		111.4		197.7		(238.4)		147.0
Net Income Attributable
	to Noncontrolling Interests		(2.0)		-		(1.4)		-		-		(3.4)
Net Income Attributable
	to Controlling Interest	$	61.7	$	12.6	$	110.0	$	197.7	$	(238.4)	$	143.6
Cash Flows for Total
	Investments in Plant	$	305.7	$	59.7	$	297.2	$	27.8	$	-	$	690.4

		For the Three Months Ended June 30, 2011
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	794.4	$	78.4	$	152.1	$	130.8	$	(108.2)	$	1,047.5
Depreciation and Amortization			(76.5)		(6.3)		(21.4)		(3.9)		0.4		(107.7)
Other Operating Expenses			(633.2)		(65.7)		(44.2)		(126.8)		108.2		(761.7)
Operating Income			84.7		6.4		86.5		0.1		0.4		178.1
Interest Expense			(31.0)		(5.2)		(19.1)		(8.5)		1.6		(62.2)
Interest Income			0.6		-		0.1		1.5		(1.5)		0.7
Other Income, Net			2.8		0.4		3.3		85.4		(85.3)		6.6
Income Tax (Expense)/Benefit			(17.2)		(0.4)		(28.0)		2.0		(0.9)		(44.5)
Net Income			39.9		1.2		42.8		80.5		(85.7)		78.7
Net Income Attributable
	to Noncontrolling Interests		(0.8)		-		(0.6)		-		-		(1.4)
Net Income Attributable
	to Controlling Interest	$	39.1	$	1.2	$	42.2	$	80.5	$	(85.7)	$	77.3

		For the Six Months Ended June 30, 2011
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	1,686.0	$	258.6	$	310.3	$	261.2	$	(233.4)	$	2,282.7
Depreciation and Amortization			(167.5)		(13.1)		(44.8)		(8.3)		1.3		(232.4)
Other Operating Expenses			(1,326.3)		(199.2)		(92.5)		(261.7)		234.9		(1,644.8)
Operating Income/(Loss)			192.2		46.3		173.0		(8.8)		2.8		405.5
Interest Expense			(60.6)		(10.4)		(35.4)		(17.1)		2.7		(120.8)
Interest Income			1.9		-		0.3		2.7		(2.8)		2.1
Other Income, Net			6.6		0.8		8.1		234.9		(234.8)		15.6
Income Tax (Expense)/Benefit			(43.6)		(13.0)		(57.9)		7.8		(1.4)		(108.1)
Net Income			96.5		23.7		88.1		219.5		(233.5)		194.3
Net Income Attributable
	to Noncontrolling Interests		(1.7)		-		(1.2)		-		-		(2.9)
Net Income Attributable
	to Controlling Interest	$	94.8	$	23.7	$	86.9	$	219.5	$	(233.5)	$	191.4
Cash Flows Used for
	Investments in Plant	$	251.1	$	45.4	$	146.0	$	26.0	$	-	$	468.5

The information related to the distribution and transmission segments for CL&P, PSNH and WMECO for the three and six months
ended June 30, 2012 and 2011 is as follows:
	For the Three Months Ended
	June 30, 2012						June 30, 2011
(Millions of Dollars)	Distribution		Transmission		Total		Distribution		Transmission		Total
CL&P
Operating Revenues	$	442.2	$	119.9	$	562.1	$	489.9	$	118.1	$	608.0
Net Income/(Loss)		(27.2)		34.1		6.9		19.8		32.8		52.6
PSNH
Operating Revenues		229.4		25.7		255.1		219.1		21.1		240.2
Net Income		14.7		6.5		21.2		16.0		5.7		21.7
WMECO
Operating Revenues		81.6		25.2		106.8		85.4		13.0		98.4
Net Income		1.4		9.7		11.1		4.0		4.2		8.2

	For the Six Months Ended
	June 30, 2012						June 30, 2011
(Millions of Dollars)	Distribution		Transmission		Total		Distribution		Transmission		Total
CL&P
Operating Revenues	$	916.9	$	237.2	$	1,154.1	$	1,039.8	$	241.9	$	1,281.7
Net Income/(Loss)		(5.5)		66.4		60.9		49.2		67.8		117.0
PSNH
Operating Revenues		448.9		49.2		498.1		467.0		42.7		509.7
Net Income		29.9		12.6		42.5		37.5		11.6		49.1
WMECO
Operating Revenues		173.6		47.3		220.9		179.3		25.8		205.1
Net Income		7.5		17.8		25.3		9.7		8.4		18.1

	Regulated Companies
NU	Distribution
(Millions of Dollars)	Electric		Natural Gas		Transmission		Other		Eliminations		Total
As of June 30, 2012	$	15,161.3	$	2,432.7	$	5,327.7	$	20,614.1	$	(16,029.5)	$	27,506.3
As of December 31, 2011		9,653.1		1,511.3		3,792.9		6,618.0		(5,928.2)		15,647.1
	As of June 30, 2012						As of December 31, 2011
(Millions of Dollars)	Distribution		Transmission		Total		Distribution		Transmission		Total
CL&P	$	6,137.5	$	2,697.9	$	8,835.4	$	6,161.0	$	2,630.4	$	8,791.4
PSNH		2,451.5		585.3		3,036.8		2,551.3		565.2		3,116.5
WMECO		943.3		690.2		1,633.5		942.6		560.3		1,502.9

XML

MERGER OF NU AND NSTAR (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Business Acquisitions By Acquisition Equity Interest Issued Or Issuable [Table Text Block]

NSTAR common shares outstanding as of April 9, 2012 (in thousands)*		103,696
Exchange ratio		1.312
NU common shares issued for NSTAR common shares outstanding (in thousands)		136,049
Closing price of NU common shares on April 9, 2012	$	36.79
Value of common shares issued (in millions)	$	5,005
Fair value of NU replacement stock-based compensation awards related to pre-merger service (in millions)		33
Total purchase price (in millions)	$	5,038

Schedule of Purchase Price Allocation [Table Text Block]

(Millions of Dollars)
Current Assets	$	754
Property Plant and Equipment, Net		5,155
Goodwill		3,231
Other Long-Term Assets, excluding Goodwill		2,115
Current Liabilities		(1,332)
Long-Term Liabilities		(2,723)
Long-Term Debt and Other Long-Term Obligations		(2,123)
Preferred Stock of Subsidiary		(39)
Total Purchase Price	$	5,038

Business Acquisition, Pro Forma Information [Table Text Block]

(Pro forma amounts in millions, except per share amounts)	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2012		2011		2012		2011
Operating Revenues	$	1,629	$	1,691	$	3,459	$	3,754
Net Income Attributable to Controlling Interest		133		142		243		328
Basic EPS		0.42		0.45		0.77		1.05
Diluted EPS		0.42		0.45		0.77		1.04

Business Acquisition, Integration, Restructuring and Other Related Costs [Text Block]

		For the Three Months Ended June 30,				For the Six Months Ended June 30,
(Millions of Dollars)		2012		2011		2012		2011
Transaction and Other Costs		$	29	$	2	$	31	$	16
Settlement Agreement Impacts			60		0		60		0
Total After-Tax Non-Recurring Costs Excluded
	from Net Income	$	89	$	2	$	91	$	16

	For The Three and Six Months Ended June 30, 2012
(Millions of Dollars)	NU		CL&P		NSTAR Electric		WMECO
Customer Rate Credits	$	46	$	25	$	15	$	3
Storm Costs Deferral Reduction		40		40		-		-
Establishment of Energy Efficiency Fund		15		-		-		-
Total	$	101	$	65	$	15	$	3

XML

Supplemental Cash Flow Information (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]

(Millions of Dollars)	As of June 30, 2012		As of June 30, 2011(1)
NU	$	166.3	$	109.4
CL&P		45.1		19.4
NSTAR Electric		22.7		18.8
PSNH		25.7		29.6
WMECO		56.5		39.7

XML

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Curtailments			$ 1.8
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year, Description			Contributions: NU’s policy is to annually fund the Pension Plans sponsored by NUSCO and NSTAR Electric in an amount at least equal to an amount that will satisfy the requirements of ERISA, as amended by the PPA of 2006, and the Internal Revenue Code. Based on the current status of the NUSCO Pension Plan, NU is required to make a contribution to the NUSCO Pension Plan of approximately $197.3 million in 2012 to meet minimum funding requirements under the PPA. Contributions are being made in installments and began in January 2012. NU made contributions totaling $35.1 million and $127.1 million ($87.7 million of which was contributed by PSNH in the first quarter of 2012) for the three and six months ended June 30, 2012, respectively. NSTAR Electric currently anticipates making contributions to the NSTAR Electric Pension Plan of approximately $25 million in 2012, of which $6.3 million was contributed in the second quarter of 2012. NSTAR Electric did not contribute to the Plan in the first quarter of 2012. The actual level of funding may differ from this estimate.
Defined Benefit Plan, Description of Settlements and Curtailments			Curtailment Expense (SERP): NU recorded curtailment expense of $1.8 million for the NUSCO SERP in the second quarter of 2012 to reflect charges related to organization changes that occurred as a result of the merger.
Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	22.8	14.0	38.1	27.7
Defined Benefit Plan Interest Cost	53.2	38.3	91.3	76.5
Defined Benefit Plan, Expected Return on Plan Assets	(59.4)	(42.2)	(101.9)	(85.3)
Defined Benefit Plan, Amortization of Gains (Losses)	47.4	21.1	77.4	42.1
Defined Benefit Plan Amortization Of Prior Service Cost Credit	2.0	2.4	4.1	4.8
Defined Benefit Plan Net Periodic Benefit Cost	66.0	33.6	109.0	65.8
Amount Capitalized Pension Expense	19.7	8.0	30.3	15.7
Other Postretirement Benefit Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	4.5	2.1	6.8	4.5
Defined Benefit Plan Interest Cost	13.9	6.5	20.1	12.9
Defined Benefit Plan, Expected Return on Plan Assets	(11.3)	(5.4)	(17.0)	(10.8)
Defined Benefit Plan, Amortization of Gains (Losses)	9.7	5.0	15.2	9.5
Defined Benefit Plan Amortization Of Transition Obligations Assets	3.1	2.9	5.9	5.8
Defined Benefit Plan Amortization Of Prior Service Cost Credit	(0.4)		(0.4)	(0.1)
Defined Benefit Plan Net Periodic Benefit Cost	19.5	11.1	30.6	21.8
The Connecticut Light And Power Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	5.4	4.9	10.9	9.7
Defined Benefit Plan Interest Cost	12.9	13.0	25.6	26.1
Defined Benefit Plan, Expected Return on Plan Assets	(17.7)	(19.1)	(35.2)	(38.3)
Defined Benefit Plan, Amortization of Gains (Losses)	12.6	8.2	24.5	16.6
Defined Benefit Plan Amortization Of Prior Service Cost Credit	0.9	1.0	1.8	2.0
Defined Benefit Plan Net Periodic Benefit Cost	14.1	8.0	27.6	16.1
Related Intercompany Allocationsof Defined Benefit Expense	10.7	8.7	21.3	16.5
Amount Capitalized Pension Expense	6.8	4.4	13.4	8.9
The Connecticut Light And Power Company [Member] | Other Postretirement Benefit Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	0.7	0.7	1.4	1.4
Defined Benefit Plan Interest Cost	2.3	2.5	4.6	5.0
Defined Benefit Plan, Expected Return on Plan Assets	(2.3)	(2.1)	(4.5)	(4.3)
Defined Benefit Plan, Amortization of Gains (Losses)	1.8	1.9	3.8	3.6
Defined Benefit Plan Amortization Of Transition Obligations Assets	1.5	1.5	3.0	3.1
Defined Benefit Plan Net Periodic Benefit Cost	4.0	4.5	8.3	8.8
Related Intercompany Allocationsof Defined Benefit Expense	1.9	2.0	4.1	4.1
Public Service Company Of New Hampshire [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	2.9	2.7	5.8	5.3
Defined Benefit Plan Interest Cost	6.1	6.1	12.2	12.3
Defined Benefit Plan, Expected Return on Plan Assets	(7.2)	(4.7)	(13.9)	(10.0)
Defined Benefit Plan, Amortization of Gains (Losses)	4.1	2.6	8.0	5.2
Defined Benefit Plan Amortization Of Prior Service Cost Credit	0.4	0.5	0.8	1.0
Defined Benefit Plan Net Periodic Benefit Cost	6.3	7.2	12.9	13.8
Related Intercompany Allocationsof Defined Benefit Expense	2.4	1.9	5.0	3.8
Amount Capitalized Pension Expense	1.9	2.0	3.9	3.9
Public Service Company Of New Hampshire [Member] | Other Postretirement Benefit Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	0.5	0.5	1.0	1.0
Defined Benefit Plan Interest Cost	1.1	1.2	2.3	2.4
Defined Benefit Plan, Expected Return on Plan Assets	(1.1)	(1.1)	(2.3)	(2.2)
Defined Benefit Plan, Amortization of Gains (Losses)	0.8	0.9	1.8	1.6
Defined Benefit Plan Amortization Of Transition Obligations Assets	0.6	0.6	1.2	1.2
Defined Benefit Plan Net Periodic Benefit Cost	1.9	2.1	4.0	4.0
Related Intercompany Allocationsof Defined Benefit Expense	0.5	0.5	1.0	1.0
Western Massachusetts Electric Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	1.1	1.0	2.1	2.0
Defined Benefit Plan Interest Cost	2.6	2.7	5.3	5.4
Defined Benefit Plan, Expected Return on Plan Assets	(4.1)	(4.4)	(8.2)	(8.8)
Defined Benefit Plan, Amortization of Gains (Losses)	2.7	1.7	5.2	3.4
Defined Benefit Plan Amortization Of Prior Service Cost Credit	0.2	0.2	0.4	0.4
Defined Benefit Plan Net Periodic Benefit Cost	2.5	1.2	4.8	2.4
Related Intercompany Allocationsof Defined Benefit Expense	2.0	1.6	4.0	3.0
Amount Capitalized Pension Expense	1.2	2.7	2.4	1.4
Western Massachusetts Electric Company [Member] | Other Postretirement Benefit Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	0.1	0.2	0.3	0.3
Defined Benefit Plan Interest Cost	0.5	0.5	1.0	1.1
Defined Benefit Plan, Expected Return on Plan Assets	(0.5)	(0.5)	(1.1)	(1.0)
Defined Benefit Plan, Amortization of Gains (Losses)	0.3	0.3	0.6	0.6
Defined Benefit Plan Amortization Of Transition Obligations Assets	0.3	0.3	0.7	0.6
Defined Benefit Plan Net Periodic Benefit Cost	0.7	0.8	1.5	1.6
Related Intercompany Allocationsof Defined Benefit Expense	0.4	0.9	0.8	1.7
NSTAR Electric Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	7.3	6.1	15.1	13.0
Defined Benefit Plan Interest Cost	14.7	15.3	29.5	30.5
Defined Benefit Plan, Expected Return on Plan Assets	(16.3)	(18.4)	(32.8)	(35.7)
Defined Benefit Plan, Amortization of Gains (Losses)	15.9	12.5	31.6	24.3
Defined Benefit Plan Amortization Of Prior Service Cost Credit	(0.1)	(0.2)	(0.3)	(0.4)
Defined Benefit Plan Net Periodic Benefit Cost	21.5	15.3	43.1	31.7
Related Intercompany Allocationsof Defined Benefit Expense	(3.0)	(2.0)	(6.2)	(4.5)
Amount Capitalized Pension Expense	8.9	4.9	15.2	9.9
Pension Expense Incurred Prior to Merger			21.6
NSTAR Electric Company [Member] | Other Postretirement Benefit Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Net Periodic Benefit Cost	$ 8.0	$ 5.1	$ 17.0	$ 12.8
Pension Expense Incurred Prior to Merger			9

XML

PRESENTATION (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended	6 Months Ended
	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Reclassification of Transmission Expense	$ 42.2		$ 64.8
Reclassification of Energy Efficiency Expense	30.0		64.4
Description of change in estimate		Effective January 1, 2012, NSTAR Electric increased its estimates with respect to the allowance for doubtful accounts, incurred but not reported claims on medical benefits, general and workers' compensation liabilities and various compensation accruals. The total aggregate impact of these increases in estimates to NSTAR Electric's accompanying unaudited condensed consolidated statements was approximately $11.4 million, after-tax, for the first quarter of 2012.
The Connecticut Light And Power Company [Member]
Reclassification of Transmission Expense	23.2		39.8
Reclassification of Energy Efficiency Expense	21.3		44.7
Public Service Company Of New Hampshire [Member]
Reclassification of Transmission Expense	5.0		12.9
Reclassification of Energy Efficiency Expense	2.8		5.8
Western Massachusetts Electric Company [Member]
Reclassification of Transmission Expense	5.3		10.4
Reclassification of Energy Efficiency Expense	$ 5.0		$ 10.4

XML

REGULATORY ACCOUNTING (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Regulatory Assets Text Block

	As of June 30, 2012		As of December 31, 2011
(Millions of Dollars)	NU		NU
Deferred Benefit Costs	$	2,427.7	$	1,360.5
Regulatory Assets Offsetting Derivative Liabilities		941.2		939.6
Goodwill (2)		547.7		-
Income Taxes, Net		502.9		425.4
Storm Cost Deferrals		363.4		356.0
Securitized Assets		364.4		101.8
Unrecovered Contractual Obligations		236.1		100.9
Power Contracts Buy Out Agreements		105.7		8.6
Regulatory Tracker Deferrals		119.2		45.9
Asset Retirement Obligations		82.4		47.5
Losses on Reacquired Debt		40.7		24.5
Deferred Environmental Remediation Costs		58.4		38.5
Other Regulatory Assets		35.8		73.6
Total Regulatory Assets	$	5,825.6	$	3,522.8
Less: Current Portion	$	624.4	$	255.1
Total Long-Term Regulatory Assets	$	5,201.2	$	3,267.7

		As of June 30, 2012								As of December 31, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric		PSNH		WMECO		CL&P		Electric(1)		PSNH		WMECO
Deferred Benefit Costs		$	533.6	$	819.5	$	184.1	$	111.2	$	572.8	$	813.7	$	200.0	$	118.9
Regulatory Assets Offsetting
	Derivative Liabilities		911.0		15.8		-		13.5		932.0		3.4		-		7.3
Goodwill (2)			-		470.2		-		-		-		478.9		-		-
Income Taxes, Net			356.0		47.9		36.9		30.0		339.6		48.8		38.0		17.8
Storm Cost Deferrals			246.5		36.6		38.9		41.4		268.3		30.6		44.0		43.7
Securitized Assets			-		299.2		48.6		16.6		-		368.5		76.4		25.4
Unrecovered Contractual Obligations			72.4		26.8		-		17.4		80.9		30.8		-		20.0
Power Contracts Buy Out Agreements			-		97.9		7.8		-		-		109.5		8.6		-
Regulatory Tracker Deferrals			26.5		52.3		13.6		24.9		5.5		61.1		11.9		22.1
Asset Retirement Obligations			29.1		25.5		13.8		3.4		27.9		24.5		13.5		3.2
Losses on Reacquired Debt			13.7		16.9		8.5		0.3		13.9		18.2		9.0		0.3
Deferred Environmental Remediation
	Costs		-		-		9.9		-		-		-		9.7		-
Other Regulatory Assets			32.9		12.6		14.3		13.9		33.1		16.5		17.0		10.0
Total Regulatory Assets		$	2,221.7	$	1,921.2	$	376.4	$	272.6	$	2,274.0	$	2,004.5	$	428.1	$	268.7
Less: Current Portion		$	196.1	$	326.6	$	28.9	$	40.6	$	170.2	$	323.9	$	34.2	$	35.5
Total Long-Term Regulatory Assets		$	2,025.6	$	1,594.6	$	347.5	$	232.0	$	2,103.8	$	1,680.6	$	393.9	$	233.2

Schedule Of Regulatory Liabilities Text Block

Regulatory Liabilities: The components of regulatory liabilities are as follows:
	As of June 30, 2012		As of December 31, 2011
(Millions of Dollars)	NU		NU
Cost of Removal	$	454.4	$	172.2
Regulatory Tracker Deferrals		134.9		139.1
AFUDC Transmission Incentive		70.6		67.0
Overrecovered Spent Nuclear Fuel Costs and Contractual Obligations		15.4		15.4
Wholesale Transmission Overcollections		-		9.6
Other Regulatory Liabilities		80.2		30.6
Total Regulatory Liabilities	$	755.5	$	433.9
Less: Current Portion	$	203.8	$	167.8
Total Long-Term Regulatory Liabilities	$	551.7	$	266.1

		As of June 30, 2012										As of December 31, 2011
				NSTAR									NSTAR
(Millions of Dollars)		CL&P		Electric		PSNH		WMECO		CL&P			Electric(1)		PSNH		WMECO
Cost of Removal		$	52.0	$	240.5	$	51.9	$	4.1	$	63.8		$	235.8	$	53.2	$	7.2
Regulatory Tracker Deferrals			74.6		13.6		13.8		15.3		94.4			11.7		17.3		21.3
AFUDC Transmission Incentive			57.1		4.2		-		9.3		57.7			4.3		-		9.3
Overrecovered Spent Nuclear Fuel
	Costs and Contractual Obligations		15.4		-		-		-		15.4			-		-		-
Wholesale Transmission Overcollections			8.1		-		5.3		2.5		4.5			-		2.6		9.5
Other Regulatory Liabilities(2)			11.8		48.1		5.4		1.8		11.8			29.7		5.8		2.4
Total Regulatory Liabilities		$	219.0	$	306.4	$	76.4	$	33.0	$	247.6		$	281.5	$	78.9	$	49.7
Less: Current Portion		$	88.4	$	52.6	$	23.1	$	19.4	$	108.3		$	41.6	$	24.5	$	33.1
Total Long-Term Regulatory Liabilities		$	130.6	$	253.8	$	53.3	$	13.6	$	139.3		$	239.9	$	54.4	$	16.6

XML

DERIVATIVE INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Derivative Instruments In Statement Of Financial Position Fair Value Text Block

		As of June 30, 2012
			Commodity				Net Amount
			Supply and				Recorded as
			Price Risk		Collateral		Derivative
(Millions of Dollars)			Management		and Netting (1)		Asset/(Liability) (2)
Current Derivative Assets:
Level 2:
	PSNH		$	1.0	$	-	$	1.0
Level 3:
	CL&P			18.1		(12.1)		6.0
	Other			5.8		-		5.8
Total Current Derivative Assets			$	24.9	$	(12.1)	$	12.8
Long-Term Derivative Assets:
Level 2:
	Other		$	0.5	$	(0.1)	$	0.4
Level 3:
	CL&P			167.2		(76.1)		91.1
	Other			2.1		-		2.1
Total Long-Term Derivative Assets			$	169.8	$	(76.2)	$	93.6
Current Derivative Liabilities:
Level 2:
	Other		$	(18.5)	$	4.6	$	(13.9)
Level 3:
	CL&P			(97.7)		-		(97.7)
	NSTAR Electric			(0.7)		-		(0.7)
	WMECO			(0.9)		-		(0.9)
Total Current Derivative Liabilities			$	(117.8)	$	4.6	$	(113.2)
Long-Term Derivative Liabilities:
Level 2:
	Other		$	(8.8)	$	-	$	(8.8)
Level 3:
	CL&P			(910.1)		-		(910.1)
	NSTAR Electric			(15.1)		-		(15.1)
	WMECO			(12.6)		-		(12.6)
Total Long-Term Derivative Liabilities			$	(946.6)	$	-	$	(946.6)

		As of December 31, 2011
			Commodity				Net Amount
			Supply and				Recorded as
			Price Risk		Collateral		Derivative
(Millions of Dollars)			Management		and Netting (1)		Asset/(Liability) (2)
Current Derivative Assets:
Level 3:
	CL&P		$	17.9	$	(11.6)	$	6.3
	Other			4.7		-		4.7
Total Current Derivative Assets(3)			$	22.6	$	(11.6)	$	11.0
Long-Term Derivative Assets:
Level 3:
	CL&P		$	174.2	$	(80.4)	$	93.8
	Other			4.6		-		4.6
Total Long-Term Derivative Assets			$	178.8	$	(80.4)	$	98.4
Current Derivative Liabilities:
Level 3:
	CL&P		$	(95.9)	$	-	$	(95.9)
	WMECO			(0.1)		-		(0.1)
	Other			(16.1)		4.5		(11.6)
Total Current Derivative Liabilities			$	(112.1)	$	4.5	$	(107.6)
Long-Term Derivative Liabilities:
Level 3:
	CL&P		$	(935.8)	$	-	$	(935.8)
	WMECO			(7.2)		-		(7.2)
	Other			(17.3)		0.4		(16.9)
Total Long-Term Derivative Liabilities(4)			$	(960.3)	$	0.4	$	(959.9)

Schedule Of Derivative Instruments Gain Loss In Statement Of Financial Performance Text Block

		Amounts Recognized on Derivative
Location of Amount		For the Three Months Ended				For the Six Months Ended
Recognized on Derivative		June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)
NU
Balance Sheet:
	Regulatory Assets		(40.8)		(14.7)		(33.5)		(45.2)
Statement of Income:
	Purchased Power, Fuel and Transmission		(0.2)		0.5		(1.0)		0.8

Schedule Of Credit Risk Contingent Features [Table Text Block]

As of June 30, 2012

As of December 31, 2011

Additional Standby

Additional Standby

Fair Value

LOCs Required if

Fair Value

LOCs Required if

Subject to Credit

Cash

Downgraded

Subject to Credit

Cash

Downgraded

Risk Contingent

Collateral

Below Investment

Risk Contingent

Collateral

Below Investment

(Millions of Dollars)

Features

Posted

Grade

Features

Posted

Grade

NU

$

(21.1)

$

4.3

$

17.3

$

(23.5)

$

4.1

$

19.9

Rollforward Of Net Derivative Asset Liabilities Valued Using Unobservable Inputs

		For the Three Months Ended				For the Six Months Ended
		June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)		NU		NU		NU		NU
Derivatives, Net:
Fair Value as of Beginning of Period		$	(901.5)	$	(872.7)	$	(962.2)	$	(840.2)
Increase due to Merger with NSTAR			(5.4)		-		(5.4)		-
Transfer to Level 2			-		-		32.2		-
Net Realized/Unrealized Gains/(Losses) Included in:
	Net Income(2)		(0.7)		0.5		7.4		0.8
	Regulatory Assets		(42.6)		(13.9)		(35.4)		(45.2)
Settlements			18.1		(0.1)		31.3		(1.6)
Fair Value as of End of Period		$	(932.1)	$	(886.2)	$	(932.1)	$	(886.2)

		For the Three Months Ended
		June 30, 2012						June 30, 2011
(Millions of Dollars)		CL&P		NSTAR Electric		WMECO		CL&P		NSTAR Electric(1)
Derivatives, Net:
Fair Value as of Beginning of Period		$	(899.6)	$	(5.4)	$	(12.3)	$	(842.6)	$	(2.1)
Net Realized/Unrealized Gains/(Losses)
	Included in Regulatory Assets		(31.8)		(9.6)		(1.2)		(13.9)		1.9
Settlements			20.7		(0.8)		-		(2.2)		(0.8)
Fair Value as of End of Period		$	(910.7)	$	(15.8)	$	(13.5)	$	(858.7)	$	(1.0)
		For the Six Months Ended
		June 30, 2012						June 30, 2011
(Millions of Dollars)		CL&P		NSTAR Electric(1)		WMECO		CL&P		NSTAR Electric(1)
Derivatives, Net:
Fair Value as of Beginning of Period		$	(931.6)	$	(3.4)	$	(7.3)	$	(806.1)	$	(2.4)
Net Realized/Unrealized Gains/(Losses)
	Included in Regulatory Assets		(21.0)		(10.2)		(6.2)		(45.1)		3.0
Settlements			41.9		(2.2)		-		(7.5)		(1.6)
Fair Value as of End of Period		$	(910.7)	$	(15.8)	$	(13.5)	$	(858.7)	$	(1.0)

FairValueInputsLiabilitiesQuantitativeInformationTableTextBlock

	Range	Period Covered
Energy Prices:
NU	$41 - $78 per MWh	2017 - 2027
CL&P	$47 - $52 per MWh	2017 - 2020
WMECO	$41 - $78 per MWh	2017 - 2027
Capacity Prices:
NU	$1.40 - $10.18 per kW-Month	2016 - 2027
CL&P	$1.40 - $9.51 per kW-Month	2016 - 2026
NSTAR Electric	$1.40 - $10.18 per kW-Month	2016 - 2027
WMECO	$1.40 - $10.18 per kW-Month	2016 - 2027
Forward Reserve:
NU, CL&P	$0.50 per kW-Month	2012 - 2024
REC Prices:
NU	$25 - $84 per REC	2012 - 2027
NSTAR Electric	$25 - $60 per REC	2012 - 2017
WMECO	$25 - $84 per REC	2012 - 2027

XML

REGULATORY ACCOUNTING

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Public Utilities Disclosure [Text Block]

3.       REGULATORY ACCOUNTING

On April 10, 2012, NSTAR LLC's regulated utility subsidiaries, NSTAR Electric and NSTAR Gas, becamesubsidiaries of NU. For NSTAR Electric, certain regulatory asset and liability balances as of December 31, 2011 have been reclassified to the current period presentation in order to align the reporting of regulatory activities subsequent to the closing of the merger. See Note F and Note C, "Regulatory Assets," and Note E and Note B, "Asset Retirement Obligations and Cost of Removal," of the NSTAR and NSTAR Electric 2011 Form 10-Ks, respectively, for further information on specific regulatory assets and liabilities.

NU's Regulated companies continue to be rate-regulated on a cost-of-service basis; therefore, the accounting policies of the Regulated companies apply GAAP applicable to rate-regulated enterprises and historically reflect the effects of the rate-making process.

Management believes it is probable that the Regulated companies will recover their respective investments in long-lived assets, including regulatory assets. If management determined that it could no longer apply the accounting guidance applicable to rate-regulated enterprises to the Regulated companies' operations, or that management could not conclude it is probable that costs would be recovered or reflected in future rates, the costs would be charged to net income in the period in which the determination is made.

Regulatory Assets: The components of regulatory assets are as follows:

	As of June 30, 2012		As of December 31, 2011
(Millions of Dollars)	NU		NU
Deferred Benefit Costs	$	2,427.7	$	1,360.5
Regulatory Assets Offsetting Derivative Liabilities		941.2		939.6
Goodwill (2)		547.7		-
Income Taxes, Net		502.9		425.4
Storm Cost Deferrals		363.4		356.0
Securitized Assets		364.4		101.8
Unrecovered Contractual Obligations		236.1		100.9
Power Contracts Buy Out Agreements		105.7		8.6
Regulatory Tracker Deferrals		119.2		45.9
Asset Retirement Obligations		82.4		47.5
Losses on Reacquired Debt		40.7		24.5
Deferred Environmental Remediation Costs		58.4		38.5
Other Regulatory Assets		35.8		73.6
Total Regulatory Assets	$	5,825.6	$	3,522.8
Less: Current Portion	$	624.4	$	255.1
Total Long-Term Regulatory Assets	$	5,201.2	$	3,267.7

		As of June 30, 2012								As of December 31, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric		PSNH		WMECO		CL&P		Electric(1)		PSNH		WMECO
Deferred Benefit Costs		$	533.6	$	819.5	$	184.1	$	111.2	$	572.8	$	813.7	$	200.0	$	118.9
Regulatory Assets Offsetting
	Derivative Liabilities		911.0		15.8		-		13.5		932.0		3.4		-		7.3
Goodwill (2)			-		470.2		-		-		-		478.9		-		-
Income Taxes, Net			356.0		47.9		36.9		30.0		339.6		48.8		38.0		17.8
Storm Cost Deferrals			246.5		36.6		38.9		41.4		268.3		30.6		44.0		43.7
Securitized Assets			-		299.2		48.6		16.6		-		368.5		76.4		25.4
Unrecovered Contractual Obligations			72.4		26.8		-		17.4		80.9		30.8		-		20.0
Power Contracts Buy Out Agreements			-		97.9		7.8		-		-		109.5		8.6		-
Regulatory Tracker Deferrals			26.5		52.3		13.6		24.9		5.5		61.1		11.9		22.1
Asset Retirement Obligations			29.1		25.5		13.8		3.4		27.9		24.5		13.5		3.2
Losses on Reacquired Debt			13.7		16.9		8.5		0.3		13.9		18.2		9.0		0.3
Deferred Environmental Remediation
	Costs		-		-		9.9		-		-		-		9.7		-
Other Regulatory Assets			32.9		12.6		14.3		13.9		33.1		16.5		17.0		10.0
Total Regulatory Assets		$	2,221.7	$	1,921.2	$	376.4	$	272.6	$	2,274.0	$	2,004.5	$	428.1	$	268.7
Less: Current Portion		$	196.1	$	326.6	$	28.9	$	40.6	$	170.2	$	323.9	$	34.2	$	35.5
Total Long-Term Regulatory Assets		$	2,025.6	$	1,594.6	$	347.5	$	232.0	$	2,103.8	$	1,680.6	$	393.9	$	233.2

• NSTAR Electric amounts are not included in NU consolidated as of December 31, 2011.
• Originated from the merger that created NSTAR in 1999, recoverable in rates over 40 years.

Storm Costs:On August 1, 2012, PURA issued a final decision in the investigation of CL&P's performance related to both Tropical Storm Irene and the October 2011 snowstorm. The decision identified certain penalties that could be imposed on CL&P during its next rate case, including a reduction in allowed regulatory ROE and the disallowance of certain deferred storm restoration costs. However, PURA will consider and weigh the extent to which CL&P has taken steps in its restructuring of storm management and the establishment of new practices for execution in future storm response in determining any potential penalties. At this time, management cannot estimate the impact on CL&P's financial position, results of operations or cash flows. CL&P continues to believe that its response to these events was prudent, is consistent with industry norms, and probable that it will be able to recover its deferred costs.As of June 30, 2012, CL&P had recorded total deferred storm costs relating to Tropical Storm Irene and the October 2011 snowstorm of $283 million. The storm cost deferral regulatory asset balance also reflects a reserve of $40 million recorded in connection with the Connecticut settlement agreement. See Note 2, "Merger of NU and NSTAR," for further information.

Regulatory Costs Not Yet Approved:Additionally, the Regulated companies had $57.6 million ($5.2 million for CL&P, $23.2 million for NSTAR Electric, $23.5 million for PSNH and $2.3 million for WMECO) and $32.4 million ($5 million for CL&P, $22.4 million for PSNH and $1.6 million for WMECO) of regulatory costs as of June 30, 2012 and December 31, 2011, respectively, which were included in Other Long-Term Assets on the accompanying unaudited condensed consolidated balance sheets. For comparative purposes, NSTAR Electric had $9.5 million of such regulatory costs as of December 31, 2011. These amounts represent incurred costs that have not yet been approved for recovery by the applicable regulatory agency. Management believes it is probable that these costs will be recovered in future cost-of-service regulated rates.

Regulatory Liabilities: The components of regulatory liabilities are as follows:
	As of June 30, 2012		As of December 31, 2011
(Millions of Dollars)	NU		NU
Cost of Removal	$	454.4	$	172.2
Regulatory Tracker Deferrals		134.9		139.1
AFUDC Transmission Incentive		70.6		67.0
Overrecovered Spent Nuclear Fuel Costs and Contractual Obligations		15.4		15.4
Wholesale Transmission Overcollections		-		9.6
Other Regulatory Liabilities		80.2		30.6
Total Regulatory Liabilities	$	755.5	$	433.9
Less: Current Portion	$	203.8	$	167.8
Total Long-Term Regulatory Liabilities	$	551.7	$	266.1

		As of June 30, 2012										As of December 31, 2011
				NSTAR									NSTAR
(Millions of Dollars)		CL&P		Electric		PSNH		WMECO		CL&P			Electric(1)		PSNH		WMECO
Cost of Removal		$	52.0	$	240.5	$	51.9	$	4.1	$	63.8		$	235.8	$	53.2	$	7.2
Regulatory Tracker Deferrals			74.6		13.6		13.8		15.3		94.4			11.7		17.3		21.3
AFUDC Transmission Incentive			57.1		4.2		-		9.3		57.7			4.3		-		9.3
Overrecovered Spent Nuclear Fuel
	Costs and Contractual Obligations		15.4		-		-		-		15.4			-		-		-
Wholesale Transmission Overcollections			8.1		-		5.3		2.5		4.5			-		2.6		9.5
Other Regulatory Liabilities(2)			11.8		48.1		5.4		1.8		11.8			29.7		5.8		2.4
Total Regulatory Liabilities		$	219.0	$	306.4	$	76.4	$	33.0	$	247.6		$	281.5	$	78.9	$	49.7
Less: Current Portion		$	88.4	$	52.6	$	23.1	$	19.4	$	108.3		$	41.6	$	24.5	$	33.1
Total Long-Term Regulatory Liabilities		$	130.6	$	253.8	$	53.3	$	13.6	$	139.3		$	239.9	$	54.4	$	16.6

• NSTAR Electric amounts are not included in NU consolidated as of December 31, 2011.
• Other Regulatory Liabilities include amounts that are subject to various rate reconciling mechanisms that could result in refunds to customers.

XML

PROPERTY, PLANT AND ACCUMULATED DEPRECIATION (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule of Public Utility Property, Plant, and Equipment [Text Block]

4.PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

The following tables summarize the NU, CL&P, NSTAR Electric, PSNH and WMECO investments in utility property, plant and equipment:

		As of June 30, 2012		As of December 31, 2011
(Millions of Dollars)		NU		NU
Distribution - Electric		$	11,168.1	$	6,540.4
Distribution - Natural Gas			2,160.1		1,247.6
Transmission			5,061.1		3,541.9
Generation			1,147.3		1,096.0
Electric and Natural Gas Utility			19,536.6		12,425.9
Other (1)			420.2		305.1
Property, Plant and Equipment, Gross			19,956.8		12,731.0
Less: Accumulated Depreciation
	Electric and Natural Gas Utility		(4,910.2)		(3,035.5)
	Other		(160.8)		(120.2)
Total Accumulated Depreciation			(5,071.0)		(3,155.7)
Property, Plant and Equipment, Net			14,885.8		9,575.3
Construction Work in Progress			1,169.1		827.8
Total Property, Plant and Equipment, Net		$	16,054.9	$	10,403.1

(1)These assets are primarily comprised of building improvements at RRR and software and equipment at NUSCO as of June 30, 2012 and December 31, 2011, and telecommunications equipment at NSTAR Communications, Inc.as of June 30, 2012.

		As of June 30, 2012								As of December 31, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric		PSNH		WMECO		CL&P		Electric(1)		PSNH		WMECO
Distribution		$	4,590.2	$	4,418.7	$	1,481.6	$	713.8	$	4,419.6	$	4,334.4	$	1,451.6	$	704.3
Transmission			2,707.5		1,424.8		558.2		352.6		2,689.1		1,386.9		546.4		297.4
Generation			-		-		1,126.1		21.2		-		-		1,074.8		21.2
Property, Plant and
	Equipment, Gross		7,297.7		5,843.5		3,165.9		1,087.6		7,108.7		5,721.3		3,072.8		1,022.9
Less: Accumulated Depreciation			(1,640.8)		(1,498.8)		(916.7)		(247.3)		(1,596.7)		(1,436.0)		(893.6)		(240.5)
Property, Plant and Equipment, Net			5,656.9		4,344.7		2,249.2		840.3		5,512.0		4,285.3		2,179.2		782.4
Construction Work in Progress			343.9		210.8		66.8		376.1		315.4		162.0		77.5		295.4
Total Property, Plant and
	Equipment, Net	$	6,000.8	$	4,555.5	$	2,316.0	$	1,216.4	$	5,827.4	$	4,447.3	$	2,256.7	$	1,077.8

• NSTAR Electric amounts are not included in NU consolidated as of December 31, 2011.

XML

COMMON SHARES (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule of Stock by Class [Text Block]

12.       COMMON SHARES

The following table sets forth the NU common shares and the shares of CL&P, NSTAR Electric, PSNH and WMECO common stock authorized and issued as of June 30, 2012 and December 31, 2011 and the respective par values:

	Shares
	Authorized				Issued
	Per Share		As of June 30, 2012
	Par Value		and December 31, 2011		As of June 30, 2012		As of December 31, 2011
NU	$	5		380,000,000		332,450,199		196,052,770
CL&P	$	10		24,500,000		6,035,205		6,035,205
NSTAR Electric	$	1		100,000,000		100		100
PSNH	$	1		100,000,000		301		301
WMECO	$	25		1,072,471		434,653		434,653

As a result of the merger with NSTAR on April 10, 2012, NU issued approximately 136 million common shares to the NSTAR shareholders.

As of June 30, 2012 and December 31, 2011,18,674,189 and 18,894,078 NU common shares were held as treasury shares, respectively.

XML

Fair Value Measurements (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ (901.5)	$ (872.7)	$ (962.2)	$ (840.2)
Net Realized/Unrealized Gains Losses included in Net Income	(0.7)	0.5	7.4	0.8
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(42.6)	(13.9)	(35.4)	(45.2)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	18.1	(0.1)	31.3	(1.6)
Ending Balance	(932.1)	(886.2)	(932.1)	(886.2)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3			32.2
Derivative Liability Recorded at Merger Date	5.4		5.4
The Connecticut Light And Power Company [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(899.6)	(842.6)	(931.6)	(806.1)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(31.8)	(13.9)	(21.0)	(45.1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	20.7	(2.2)	41.9	(7.5)
Ending Balance	(910.7)	(858.7)	(910.7)	(858.7)
Western Massachusetts Electric Company [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(12.3)		(7.3)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(1.2)		(6.2)
Ending Balance	(13.5)		(13.5)
NSTAR Electric Company [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(5.4)	(2.1)	(3.4)	(2.4)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(9.6)	1.9	(10.2)	3.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(0.8)	(0.8)	(2.2)	(1.6)
Ending Balance	$ (15.8)	$ (1.0)	$ (15.8)	$ (1.0)

XML

CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Jun. 30, 2012	Dec. 31, 2011
Current Assets:
Cash	$ 28,483	$ 6,559
Receivables, Net	661,910	488,002
Unbilled Revenues	202,262	175,207
Fuel, Materials and Supplies	262,562	248,958
Regulatory Assets Current	624,397	255,144
Marketable Securities - Current	79,231	70,970
Prepayments and Other Current Assets	95,160	112,632
Total Current Assets	1,954,005	1,357,472
Property, Plant and Equipment, Net	16,054,913	10,403,065
Deferred Debits and Other Assets:
Regulatory Assets Long Term	5,201,154	3,267,710
Goodwill	3,518,454	287,591
Marketable Securities	372,302	60,311
Derivative Assets Noncurrent	93,616	98,357
Other Long-Term Assets	311,856	172,560
Total Deferred Debits and Other Assets	9,497,382	3,886,529
Total Assets	27,506,300	15,647,066
Current Liabilities:
Notes Payable to Banks	1,248,500	317,000
Long-Term Debt - Current Portion	683,208	331,582
Accounts Payable - Current	600,995	633,282
Regulatory Liability Current	203,767	167,844
Derivative Liabilities - Current	113,188	107,558
Other Liabilities - Current	640,809	390,416
Total Current Liabilities	3,490,467	1,947,682
Rate Reduction Bonds	160,133	112,260
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	3,249,323	1,868,316
Regulatory Liabilities Long-Term	551,690	266,145
Long-Term Derivative Liabilities	946,621	959,876
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	2,064,069	1,326,037
Other Long-Term Liabilities	884,317	420,011
Total Deferred Credits and Other Liabilities	7,696,020	4,840,385
Capitalization:
Long-Term Debt	6,936,473	4,614,913
Noncontrolling Interest in Consolidated Subsidiary:
Preferred Stock Not Subject to Mandatory Redemption	155,568	116,200
Common Shareholders' Equity:
Common Stock	1,662,251	980,264
Capital Surplus, Paid In	6,178,698	1,797,884
Retained Earnings	1,635,709	1,651,875
Accumulated Other Comprehensive Loss	(66,387)	(70,686)
Treasury Stock	(342,632)	(346,667)
Noncontrolling Interest	0	2,956
Common Shareholders' Equity	9,067,639	4,012,670
Total Equity	9,067,639	4,015,626
Total Capitalization	16,159,680	8,746,739
Total Liabilities and Capitalization	27,506,300	15,647,066
The Connecticut Light And Power Company [Member]
Current Assets:
Cash	4,523	1
Receivables, Net	259,940	295,028
Accounts Receivable from Affiliated Companies	973	1,548
Unbilled Revenues	82,355	94,995
Regulatory Assets Current	196,145	170,197
Materials and Supplies	63,449	61,102
Prepayments and Other Current Assets	21,535	53,920
Total Current Assets	628,920	676,791
Property, Plant and Equipment, Net	6,000,783	5,827,384
Deferred Debits and Other Assets:
Regulatory Assets Long Term	2,025,569	2,103,830
Derivative Assets Noncurrent	91,146	93,755
Other Long-Term Assets	88,953	89,636
Total Deferred Debits and Other Assets	2,205,668	2,287,221
Total Assets	8,835,371	8,791,396
Current Liabilities:
Notes Payable to Banks	330,000	31,000
Notes Payable To Affiliated Companies	5,000	58,525
Long-Term Debt - Current Portion		62,000
Accounts Payable - Current	193,582	340,321
Accounts Payable to Affiliated Companies	44,666	53,439
Obligations to Third Party Suppliers	62,459	67,967
Accrued Taxes	91,297	59,046
Regulatory Liability Current	88,373	108,291
Derivative Liabilities - Current	97,704	95,881
Other Liabilities - Current	87,763	102,065
Total Current Liabilities	1,000,844	978,535
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,241,020	1,215,989
Regulatory Liabilities Long-Term	130,573	139,307
Long-Term Derivative Liabilities	910,115	935,849
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	248,624	260,571
Other Long-Term Liabilities	204,227	215,640
Total Deferred Credits and Other Liabilities	2,734,559	2,767,356
Capitalization:
Long-Term Debt	2,584,036	2,521,753
Noncontrolling Interest in Consolidated Subsidiary:
Preferred Stock Not Subject to Mandatory Redemption	116,200	116,200
Common Shareholders' Equity:
Common Stock	60,352	60,352
Capital Surplus, Paid In	1,614,307	1,613,503
Retained Earnings	727,096	735,948
Accumulated Other Comprehensive Loss	(2,023)	(2,251)
Common Shareholders' Equity	2,399,732	2,407,552
Total Capitalization	5,099,968	5,045,505
Total Liabilities and Capitalization	8,835,371	8,791,396
Public Service Company Of New Hampshire [Member]
Current Assets:
Cash	203	56
Receivables, Net	83,335	87,545
Accounts Receivable from Affiliated Companies	616	1,294
Notes Receivable from Affiliated Companies	0	55,900
Unbilled Revenues	43,630	45,403
Fuel, Materials and Supplies	102,948	124,744
Regulatory Assets Current	28,912	34,178
Prepayments and Other Current Assets	37,235	35,261
Total Current Assets	296,879	384,381
Property, Plant and Equipment, Net	2,315,954	2,256,688
Deferred Debits and Other Assets:
Regulatory Assets Long Term	347,498	393,941
Other Long-Term Assets	76,466	81,531
Total Deferred Debits and Other Assets	423,964	475,472
Total Assets	3,036,797	3,116,541
Current Liabilities:
Notes Payable to Banks	65,000
Notes Payable To Affiliated Companies	13,500
Accounts Payable - Current	69,792	106,377
Accounts Payable to Affiliated Companies	16,532	18,895
Accrued Interest	9,517	9,670
Regulatory Liability Current	23,121	24,500
Other Liabilities - Current	29,365	36,497
Total Current Liabilities	226,827	195,939
Rate Reduction Bonds	57,742	85,368
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	410,763	392,712
Regulatory Liabilities Long-Term	53,272	54,415
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	168,428	258,718
Other Long-Term Liabilities	58,895	53,304
Total Deferred Credits and Other Liabilities	691,358	759,149
Capitalization:
Long-Term Debt	997,827	997,722
Common Shareholders' Equity:
Common Stock
Capital Surplus, Paid In	700,658	700,285
Retained Earnings	372,621	388,910
Accumulated Other Comprehensive Loss	(10,236)	(10,832)
Common Shareholders' Equity	1,063,043	1,078,363
Total Capitalization	2,060,870	2,076,085
Total Liabilities and Capitalization	3,036,797	3,116,541
Western Massachusetts Electric Company [Member]
Current Assets:
Cash	1	1
Receivables, Net	42,580	42,757
Accounts Receivable from Affiliated Companies	82	633
Notes Receivable from Affiliated Companies	0	11,000
Unbilled Revenues	15,440	16,277
Regulatory Assets Current	40,587	35,520
Marketable Securities - Current	18,461	26,335
Prepayments and Other Current Assets	8,057	8,719
Total Current Assets	125,208	141,242
Property, Plant and Equipment, Net	1,216,370	1,077,833
Deferred Debits and Other Assets:
Regulatory Assets Long Term	232,001	233,247
Marketable Securities	39,032	30,794
Other Long-Term Assets	20,902	19,777
Total Deferred Debits and Other Assets	291,935	283,818
Total Assets	1,633,513	1,502,893
Current Liabilities:
Notes Payable to Banks	110,000	0
Notes Payable To Affiliated Companies	5,400	0
Accounts Payable - Current	109,164	111,566
Accounts Payable to Affiliated Companies	8,463	10,626
Regulatory Liability Current	19,400	33,056
Other Liabilities - Current	27,033	20,755
Total Current Liabilities	279,460	176,003
Rate Reduction Bonds	18,079	26,892
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	265,871	244,511
Regulatory Liabilities Long-Term	13,643	16,597
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	26,556	29,546
Other Long-Term Liabilities	51,748	47,498
Total Deferred Credits and Other Liabilities	357,818	338,152
Capitalization:
Long-Term Debt	499,648	499,545
Common Shareholders' Equity:
Common Stock	10,866	10,866
Capital Surplus, Paid In	340,259	340,115
Retained Earnings	131,398	115,506
Accumulated Other Comprehensive Loss	(4,015)	(4,186)
Common Shareholders' Equity	478,508	462,301
Total Capitalization	978,156	961,846
Total Liabilities and Capitalization	1,633,513	1,502,893
NSTAR Electric Company [Member]
Current Assets:
Cash	9,044	9,373
Receivables, Net	211,388	232,828
Accounts Receivable from Affiliated Companies	48,254	389,652
Unbilled Revenues	53,409	40,380
Taxes Receivable	35,642	5,664
Regulatory Assets Current	326,630	323,871
Prepayments and Other Current Assets	21,588	31,470
Total Current Assets	705,955	1,033,238
Property, Plant and Equipment, Net	4,555,454	4,447,258
Deferred Debits and Other Assets:
Regulatory Assets Long Term	1,594,571	1,680,595
Other Long-Term Assets	75,516	78,273
Total Deferred Debits and Other Assets	1,670,087	1,758,868
Total Assets	6,931,496	7,239,364
Current Liabilities:
Notes Payable to Banks	344,500	141,500
Long-Term Debt - Current Portion	401,513	400,688
Accounts Payable - Current	114,308	150,581
Accounts Payable to Affiliated Companies	146,858	514,377
Deferred Tax Liabilities Current	94,398	101,819
Regulatory Liability Current	52,636	41,579
Other Liabilities - Current	103,606	103,634
Total Current Liabilities	1,257,819	1,454,178
Rate Reduction Bonds	84,312	127,860
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,300,332	1,310,180
Regulatory Liabilities Long-Term	253,766	239,858
Other Long-Term Liabilities	189,803	195,606
Defined Benefit Pension Plan, Liabilities, Noncurrent	385,235	357,685
Due to Related Parties, Noncurrent	70,569	75,905
Total Deferred Credits and Other Liabilities	2,199,705	2,179,234
Capitalization:
Long-Term Debt	1,201,871	1,203,344
Noncontrolling Interest in Consolidated Subsidiary:
Preferred Stock Not Subject to Mandatory Redemption	43,000	43,000
Common Shareholders' Equity:
Common Stock	0	0
Capital Surplus, Paid In	992,625	992,625
Retained Earnings	1,152,164	1,239,123
Common Shareholders' Equity	2,144,789	2,231,748
Total Capitalization	3,389,660	3,478,092
Total Liabilities and Capitalization	$ 6,931,496	$ 7,239,364

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Restricted Cash (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2012	Dec. 31, 2011
Restricted Cash And Cash Equivalents	$ 18.3	$ 17.9
Public Service Company Of New Hampshire [Member]
Restricted Cash And Cash Equivalents	7.4	7.0
The Connecticut Light And Power Company [Member]
Restricted Cash And Cash Equivalents	$ 9.4	$ 9.4

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Significant Accounting Policies [Text Block]

NORTHEAST UTILITIES AND SUBSIDIARIES

THE CONNECTICUT LIGHT AND POWER COMPANY AND SUBSIDIARY

NSTAR ELECTRIC COMPANY AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

Refer to the Glossary of Terms included in this combined Quarterly Report on Form 10-Q for abbreviations and acronyms used throughout the combined notes to the unaudited condensed consolidated financial statements.

1.       SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A.       Basis of Presentation

NU is a public utility holding company primarily engaged through its wholly owned regulated utility subsidiaries in the energy delivery business. NU's wholly owned regulated utility subsidiaries included CL&P, PSNH, WMECO and Yankee Gasprior to NU's merger with NSTAR. On April 10, 2012, NU acquired 100 percent of the outstanding common shares of NSTAR and NSTAR (through a successor, NSTAR LLC) became a direct wholly owned subsidiary of NU. NSTAR Electric and NSTAR Gas, NSTAR LLC's regulated utility subsidiaries, are now also wholly owned subsidiaries of NU. NU provides energy delivery service to approximately 3.5 million electric and natural gas customers through six regulated utilities in Connecticut, Massachusetts and New Hampshire. NU's consolidated financial information includes NSTAR LLC and its subsidiaries' activity from April 10, 2012 through June 30, 2012.See Note2, "Merger of NU and NSTAR," for further information regarding the merger.

NSTAR Electric continues to maintain reporting requirements as an SEC registrant. The information disclosed for NSTAR Electric represents the results of operations of the entity for the three and six months ended June30, 2012 and 2011 and the financial position as of June 30, 2012 and December 31, 2011, presented on a comparable basis. NU did not apply “push-down accounting” to NSTAR Electric, whereby the adjustments of assets and liabilities to fair value and the resultant goodwill would be shown on the financial statements of the acquired subsidiary.

The combined notes to consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations. The accompanying unaudited condensed consolidated financial statements should be read in conjunction with the entirety of this combined Quarterly Report on Form 10-Q of NU,the first quarter 2012 combined Quarterly Report on Form 10-Q, the first quarter 2012 Quarterly Report on Form 10-Q for NSTAR Electric, the 2011 combined Annual Report on Form 10-K of NU, CL&P, PSNH and WMECO (NU 2011 Form 10-K), the 2011 Annual Report on Form 10-K of NSTAR (NSTAR 2011 Form 10-K) and the 2011 Annual Report on Form 10-K of NSTAR Electric (NSTAR Electric 2011 Form 10-K), which were filed with the SEC.

The accompanying unaudited condensed consolidated financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly NU's and the above companies' financial positions as of June 30, 2012 and December 31, 2011, the results of operations and comprehensive income for the three and six months ended June 30, 2012 and 2011, and cash flows for the six months ended June 30, 2012 and 2011. The results of operations and comprehensive income for the three and six months ended June 30, 2012 and 2011 and the cash flows for the six months ended June 30, 2012 and 2011 are not necessarily indicative of the results expected for a full year.The demand for electricity is affected by weather conditions, economic conditions, and consumer conservation behavior. Electric energy sales and revenues are typically higher in the winter and summer months than in the spring and fall months. Natural gas sales and revenues are typically higher in the winter months than during other periods of the year.

The unaudited condensed consolidated financial statements of NU, CL&P, NSTAR Electric, PSNH and WMECO include the accounts of all their respective subsidiaries. Intercompany transactions have been eliminated in consolidation.

The preparation of the unaudited condensed consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent liabilities as of the date of the unaudited condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

On April 10, 2012, upon consummation of the merger with NSTAR, NSTAR Electric's ownership in CYAPC and YAEC combined with CL&P's, PSNH's and WMECO's respective ownership interests in CYAPC and YAEC totaled greater than 50 percent, requiring NU to consolidate CYAPC and YAEC. The investment in CYAPC and YAEC had previously been accounted for under the equity method by NU. The consolidation of CYAPC and YAEC resulted in NU recording nuclear decommissioning trust marketable securities of$304 million, regulatory assets of $234 million, long-term debt associated with the long-term fuel disposal liabilities of $179 million, net accumulated deferred income taxes of $60 million and asset retirement obligations related to decommissioning activity of $292 million as of June30, 2012. At the NU consolidated level, intercompany transactions between CL&P, NSTAR Electric, PSNH and WMECO and CYAPC and YAEC have been eliminated in consolidation. For CL&P, NSTAR Electric, PSNH and WMECO, the investment in CYAPC and YAECcontinue to be accounted for under the equity method.

On April 10, 2012, upon consummation of the merger with NSTAR, an NSTAR subsidiary that owned 25 percent of NPTwas merged into NUTV, resulting in NUTV owning 100 percent of NPT. Accordingly, 100 percent ownership of NPTwas reflected in Common Shareholders' Equity as of June 30, 2012 on the accompanying unaudited condensed consolidated balance sheet. See Note 2, "Merger of NU and NSTAR," and Note 13, "Common Shareholders' Equity and Noncontrolling Interests," for further information.

Certain prior period amounts in NSTAR Electric's accompanying unaudited condensed consolidated balance sheet, statements of income and cash flows have been reclassified between line items for comparative purposes and in order to conform to NU's presentation. The reclassifications did not affect NSTAR Electric's net income.

Certain changes in classification and corresponding reclassifications of prior period data were made in the accompanying unaudited condensed consolidated statements of income for NU, CL&P, PSNH and WMECO and statements of cash flows for NU and PSNH to conform to current period presentation. The unaudited condensed consolidated statements of income reflect the reclassification of transmission expenses from Other Operating Expenses, as originally reported, to Purchased Power, Fuel and Transmission and the reclassification of energy efficiency expenses primarily from Other Operating Expenses, as originally reported, to Energy Efficiency Programs. In addition, Other Operating Expenses and Maintenance, as originally reported, were combined and are reported in aggregate as Operations and Maintenance. These reclassifications were made for comparative purposes to conform to the current period's presentation. The reclassifications on the statements of income were as follows:

	Transmission Expense				Energy Efficiency Expense
	Three Months Ended		Six Months Ended		Three Months Ended		Six Months Ended
(Millions of Dollars)	June 30, 2011		June 30, 2011		June 30, 2011		June 30, 2011
NU	$	42.2	$	64.8	$	30.0	$	64.4
CL&P		23.2		39.8		21.3		44.7
PSNH		5.0		12.9		2.8		5.8
WMECO		5.3		10.4		5.0		10.4

Effective January 1, 2012, NSTAR Electric increased its estimates with respect to the allowance for doubtful accounts, incurred but not reported claims on medical benefits, general and workers' compensation liabilities and various compensation accruals. The total aggregate impact of these increases in estimates to NSTAR Electric's accompanying unaudited condensed consolidated statements was approximately$11.4 million, after-tax, for the first quarter of 2012.

NU evaluates events and transactions that occur after the balance sheet date but before financial statements are issued and recognizes in the financial statements the effects of all subsequent events that provide additional evidence about conditions that existed as of the balance sheet date and discloses, but does not recognize, in the financial statements subsequent events that provide evidence about the conditions that arose after the balance sheet date but before the financial statements are issued. See Note 10C, "Commitments and Contingencies – Deferred Contractual Obligations," and Note 17, "Subsequent Events" for further information.

B.       Accounting Standards Recently Adopted

In the first quarter of 2012, NU adopted the Financial Accounting Standards Board's (FASB) final Accounting Standards Update (ASU) on fair value measurement. The ASU did not have an impact on NU's financial position, results of operations or cash flows, but required additional financial statement disclosures related to fair value measurements. For further information, see Note 5, “Derivative Instruments.”

In the first quarter of 2012, NU adopted the FASB's final ASU on testing goodwill for impairment. The ASU provides the election to perform a qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying value; if so, quantitative testing is required. The ASU does not change existing guidance relating to when an entity should test goodwill for impairment or the methodology to be utilized in performing quantitative testing. NU has not and does not currently intend to utilize the election provided by this ASU.

In the first quarter of 2012, NU adopted the FASB's final ASU on the presentation of comprehensive income. The ASU does not change existing guidance on which items should be presented in other comprehensive income but requires other comprehensive income to be presented as part of a single continuous statement of comprehensive income or in a statement of other comprehensive income immediately following the statement of net income. The ASU did not affect the calculation of net income, comprehensive income or EPS.The ASU did not have an impact on NU's financial position, results of operations or cash flows.

C.       Restricted Cash

As of June 30, 2012, NU, CL&P and PSNH had $18.3million, $9.4million, and $7.4million, respectively, of restricted cash, primarily relating to amounts held in escrow related to property damage at CL&P and insurance proceeds on bondable property at PSNH, which were included in Prepayments and Other Current Assets on the accompanying unaudited condensed consolidated balance sheets. As of December 31, 2011, these amounts for NU, CL&P and PSNH were $17.9 million, $9.4 million, and $7 million, respectively.

D.       Provision for Uncollectible Accounts

NU, including CL&P, NSTAR Electric, PSNH and WMECO, maintains a provision for uncollectible accounts to record receivables at an estimated net realizable value. This provision is determined based upon a variety of factors, including applying an estimated uncollectible account percentage to each receivable aging category, based upon historical collection and write-off experience and management's assessment of collectibility from individual customers. Management reviews the collectibility of the receivables, and if circumstances change, collectibility estimates are adjusted accordingly. Receivable balances are written off against the provision for uncollectible accounts when the accounts are terminated and these balances are deemed to be uncollectible.

The provision for uncollectible accounts, which is included in Receivables, Net on the accompanying unaudited condensed consolidated balance sheets, is as follows:

(Millions of Dollars)	As of June 30, 2012		As of December 31, 2011(1)
NU	$	93.1	$	34.9
CL&P		11.8		14.8
NSTAR Electric		44.7		27.1
PSNH		7.9		7.2
WMECO		3.7		4.6

• NSTAR Electric amounts are not included in NU consolidated as of December 31, 2011.

E.Fair Value Measurements

NU, including CL&P, NSTAR Electric, PSNH, and WMECO, applies fair value measurement guidance to derivative contracts recorded at fair value and to the marketable securities held in the NU supplemental benefit trust, WMECO's spent nuclear fuel trust and CYAPC's and YAEC'snuclear decommissioning trusts. Fair value measurement guidance is also applied to investment valuations used to calculate the funded status of NU'sPension and PBOP Plans, including NSTAR Electric's Pension Plan.

Fair Value Hierarchy: In measuring fair value, NU uses observable market data when available and minimizes the use of unobservable inputs. Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes. The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement. NU evaluates the classification of assets and liabilities measured at fair value on a quarterly basis, and NU's policy is to recognize transfers between levels of the fair value hierarchy as of the end of the reporting period. The three levels of the fair value hierarchy are described below:

Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.

Level 3 - Quoted market prices are not available. Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable. Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.

Determination of Fair Value: The valuation techniques and inputs used in NU's fair value measurements are described in Note 5, "Derivative Instruments," Note 6, "Marketable Securities," and Note11, "Fair Value of Financial Instruments.

F.       Other Income, Net

Items included within Other Income, Net on the accompanying unaudited condensed consolidated statements of income primarily consist of investment income/(loss), interest income, AFUDC related to equity funds and equity in earnings. For CL&P, NSTAR Electric, PSNH and WMECO, equity in earnings relate to investments in CYAPC, YAEC and MYAPC accounted for on the equity method. On an NU consolidated basis, equity in earnings relate to the investment in MYAPC and NU's investment in two regional transmission companies.

G.       Other Taxes

Gross receipts taxes levied by the state of Connecticut are collected by CL&P and Yankee Gas from their respective customers. These gross receipts taxes are shown on a gross basis with collections in Operating Revenues and payments in Taxes Other Than Income Taxes on the accompanying unaudited condensed consolidated statements of income as follows:

	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
NU	$	30.5	$	32.0	$	65.5	$	70.7
CL&P		27.7		28.8		57.1		60.2

Certain sales taxes are also collected by CL&P, NSTAR Electric, WMECO, Yankee Gas and NSTAR Gas from their respective customers as agents for state and local governments and are recorded on a net basis with no impact on the accompanying unaudited condensed consolidated statements of income.

H.       Supplemental Cash Flow Information

Non-cash investing activities include plant additions included in Accounts Payable as follows:

(Millions of Dollars)	As of June 30, 2012		As of June 30, 2011(1)
NU	$	166.3	$	109.4
CL&P		45.1		19.4
NSTAR Electric		22.7		18.8
PSNH		25.7		29.6
WMECO		56.5		39.7

• NSTAR Electric amounts are not included in NU consolidated as of June 30, 2011.

Short-term borrowings of NU, including CL&P, NSTAR Electric, PSNH and WMECO, have original maturities of three months or less. Accordingly, borrowings and repayments are shown net on the accompanying unaudited condensed consolidated statements of cash flows.

In February 2012, CL&P provided approximately $27 million of bill credits to its residential customers who remained without power after noon on November 5, 2011 as a result of the October 2011 snowstorm. This disbursement is reflected as a use of cash and recorded in Other Current Assets and Liabilities, Net on the accompanying unaudited condensed consolidated statements of cash flows for the six months ended June30, 2012 for CL&P and NU.

Refer to Note 2, “Merger of NU and NSTAR,” for details of the purchase price, which represents a significant non-cash transaction.

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LONG-TERM DEBT (Details)	6 Months Ended
	Jun. 30, 2012
Debt Instrument Line Items
Long-term Debt, Description	8.        LONG-TERM DEBT (NU, CL&P) On March 22, 2012, NU parent issued $300 million of floating rate Series D Senior Notes with a maturity date of September 20, 2013. The notes have a coupon rate based on the three-month LIBOR rate plus a credit spread of 0.75 percent and will reset quarterly. The notes had an interest rate of 1.22 percent as of June 30, 2012. The proceeds, net of issuance expenses, were used to repay at maturity the NU parent $263 million Series A Senior Notes that matured on April 1, 2012, to repay short-term borrowings outstanding under the NU parent Credit Agreement and for other general corporate purposes. The indenture under which the bonds were issued requires NU to comply with certain covenants as are customarily included in such indentures. On April 2, 2012, CL&P remarketed $62 million of tax-exempt PCRBs for a three-year period. The PCRBs, which mature on May 1, 2031, carry a coupon rate of 1.55 percent during the current three-year fixed rate period and are subject to mandatory tender for purchase on April 1, 2015. On April 2, 2012, NU parent repaid its $263 million 7.25 percent Series A Senior Notes that matured on April 1, 2012 with the proceeds from the issuance of floating rate Series D Senior Notes issued on March 22, 2012. In addition, as a result of consolidating CYAPC and YAEC, NU has consolidated $179 million in additional spent nuclear fuel obligations. The spent nuclear fuel obligation is payable to the DOE at any time prior to the first delivery to the DOE of spent nuclear fuel and radio-active waste used to generate electricity prior to April 7, 1983. Until payment is made to the DOE, the outstanding liability will continue to accrue interest at the 3-month Treasury bill yield rate. NU, including CL&P, NSTAR Electric, PSNH and WMECO, was in compliance with all its debt covenants as of June 30, 2012.
The Connecticut Light And Power Company [Member]
Debt Instrument Line Items
Long-term Debt, Description	On April 2, 2012, CL&P remarketed $62 million of tax-exempt PCRBs for a three-year period. The PCRBs, which mature on May 1, 2031, carry a coupon rate of 1.55 percent during the current three-year fixed rate period and are subject to mandatory tender for purchase on April 1, 2015.

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SHARE-BASED PAYMENTS (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Disclosure of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block]

			Weighted Average
	RSUs		Grant-Date
RSUs	(Units)		Fair Value
Outstanding as of December 31, 2011		959,920	$	26.36
Granted		538,724	$	32.72
Converted NSTAR awards upon merger		617,394	$	36.79
Converted from NU performance shares upon merger		451,358	$	34.32
Shares issued		(300,460)	$	27.90
Forfeited		(76,361)	$	34.77
Outstanding as of June 30, 2012		2,190,575	$	31.97

	Performance		Weighted Average
	Shares		Grant-Date
Performance Shares	(Units)		Fair Value
Outstanding as of December 31, 2011		483,133	$	29.18
Granted		226,326	$	34.46
Converted to RSUs upon merger		(451,358)	$	34.32
Shares issued		(106,773)	$	24.52
Forfeited		-	$	-
Outstanding as of June 30, 2012		151,328	$	25.04

NU	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
Compensation Cost Recognized	$	12.8	$	3.0	$	16.4	$	6.1
Associated Future Income Tax Benefit Recognized		5.1		1.2		6.6		2.4

	For the Three Months Ended
	June 30, 2012								June 30, 2011
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric(1)		PSNH		WMECO
Compensation Cost Recognized	$	0.9	$	2.8	$	0.3	$	0.2	$	1.7	$	1.9	$	0.6	$	0.3
Associated Future Income Tax Benefit Recognized		0.4		1.1		0.1		0.1		0.7		0.7		0.2		0.1
	For the Six Months Ended
	June 30, 2012								June 30, 2011
(Millions of Dollars)	CL&P		NSTAR Electric(1)		PSNH		WMECO		CL&P		NSTAR Electric(1)		PSNH		WMECO
Compensation Cost Recognized	$	3.0	$	4.9	$	1.1	$	0.6	$	3.5	$	3.8	$	1.2	$	0.7
Associated Future Income Tax Benefit Recognized		1.2		1.9		0.4		0.3		1.4		1.5		0.5		0.3

			Exercise Price Per Share
						Weighted		Intrinsic Value
	Options		Range			Average		(Millions)
Outstanding and Exercisable as of December 31, 2011		47,374	$ 18.58	-	$ 18.90	$	18.78
Converted NSTAR Options upon merger		2,664,894	$ 16.47	-	$ 28.12	$	23.99
Exercised		(340,607)				$	23.84	$	4.3
Forfeited and cancelled		-
Outstanding and Exercisable as of June 30, 2012		2,371,661	$ 18.45	-	$ 28.12	$	23.90	$	35.4

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DPU Safety And Reliability Programs (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2012
Notes To Consolidated Financial Statements [Abstract]
Cumulative Costs Associated With Cpsl Program At Nstar Electric	$ 90.0
Cpsl Annual Revenue Per Annum From Comprehensive Settlement Agreement	$ 15.0

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VARIABLE INTEREST ENTITIES

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Variable Interest Entities Text Block

16.       VARIABLE INTEREST ENTITIES

The Company's variable interests outside of the consolidated group are not material and consist of contracts that are required by regulation and provide for regulatory recovery of contract costs and benefits through customer rates. NU, CL&P and NSTAR Electric hold variable interests in variable interest entities (VIEs) through agreements with certain entities that own single renewable energy or peaking generation power plants and with other independent power producers. NU, CL&P and NSTAR Electric do not control the activities that are economically significant to these VIEs or provide financial or other support to these VIEs. Therefore, NU, CL&P and NSTAR Electric do not consolidate any power plant VIEs.

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Environmental Matters (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Environmental Loss Contingencies By Site Text Block

	As of June 30, 2012						As of December 31, 2011
					Portion Related to						Portion Related to
			Reserve		MGP Sites				Reserve		MGP Sites
	Number of Sites		(in millions)		(in millions)		Number of Sites		(in millions)		(in millions)
NU		83	$	41.8	$	37.4		59	$	31.7	$	28.9
CL&P		19		3.2		1.5		18		2.9		1.5
NSTAR Electric(1)		13		1.4		-		13		1.3		-
PSNH		19		6.5		5.5		18		6.6		5.8
WMECO		10		0.3		0.1		10		0.3		0.1

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SIGNIFCANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Organization Consolidation And Presentation Of Financial Statements Disclosure Text Block

NU is a public utility holding company primarily engaged through its wholly owned regulated utility subsidiaries in the energy delivery business. NU's wholly owned regulated utility subsidiaries included CL&P, PSNH, WMECO and Yankee Gasprior to NU's merger with NSTAR. On April 10, 2012, NU acquired 100 percent of the outstanding common shares of NSTAR and NSTAR (through a successor, NSTAR LLC) became a direct wholly owned subsidiary of NU. NSTAR Electric and NSTAR Gas, NSTAR LLC's regulated utility subsidiaries, are now also wholly owned subsidiaries of NU. NU provides energy delivery service to approximately 3.5 million electric and natural gas customers through six regulated utilities in Connecticut, Massachusetts and New Hampshire. NU's consolidated financial information includes NSTAR LLC and its subsidiaries' activity from April 10, 2012 through June 30, 2012.See Note2, "Merger of NU and NSTAR," for further information regarding the merger.

NSTAR Electric continues to maintain reporting requirements as an SEC registrant. The information disclosed for NSTAR Electric represents the results of operations of the entity for the three and six months ended June30, 2012 and 2011 and the financial position as of June 30, 2012 and December 31, 2011, presented on a comparable basis. NU did not apply “push-down accounting” to NSTAR Electric, whereby the adjustments of assets and liabilities to fair value and the resultant goodwill would be shown on the financial statements of the acquired subsidiary.

The combined notes to consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations. The accompanying unaudited condensed consolidated financial statements should be read in conjunction with the entirety of this combined Quarterly Report on Form 10-Q of NU,the first quarter 2012 combined Quarterly Report on Form 10-Q, the first quarter 2012 Quarterly Report on Form 10-Q for NSTAR Electric, the 2011 combined Annual Report on Form 10-K of NU, CL&P, PSNH and WMECO (NU 2011 Form 10-K), the 2011 Annual Report on Form 10-K of NSTAR (NSTAR 2011 Form 10-K) and the 2011 Annual Report on Form 10-K of NSTAR Electric (NSTAR Electric 2011 Form 10-K), which were filed with the SEC.

The accompanying unaudited condensed consolidated financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly NU's and the above companies' financial positions as of June 30, 2012 and December 31, 2011, the results of operations and comprehensive income for the three and six months ended June 30, 2012 and 2011, and cash flows for the six months ended June 30, 2012 and 2011. The results of operations and comprehensive income for the three and six months ended June 30, 2012 and 2011 and the cash flows for the six months ended June 30, 2012 and 2011 are not necessarily indicative of the results expected for a full year.The demand for electricity is affected by weather conditions, economic conditions, and consumer conservation behavior. Electric energy sales and revenues are typically higher in the winter and summer months than in the spring and fall months. Natural gas sales and revenues are typically higher in the winter months than during other periods of the year.

The unaudited condensed consolidated financial statements of NU, CL&P, NSTAR Electric, PSNH and WMECO include the accounts of all their respective subsidiaries. Intercompany transactions have been eliminated in consolidation.

The preparation of the unaudited condensed consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent liabilities as of the date of the unaudited condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

On April 10, 2012, upon consummation of the merger with NSTAR, NSTAR Electric's ownership in CYAPC and YAEC combined with CL&P's, PSNH's and WMECO's respective ownership interests in CYAPC and YAEC totaled greater than 50 percent, requiring NU to consolidate CYAPC and YAEC. The investment in CYAPC and YAEC had previously been accounted for under the equity method by NU. The consolidation of CYAPC and YAEC resulted in NU recording nuclear decommissioning trust marketable securities of$304 million, regulatory assets of $234 million, long-term debt associated with the long-term fuel disposal liabilities of $179 million, net accumulated deferred income taxes of $60 million and asset retirement obligations related to decommissioning activity of $292 million as of June30, 2012. At the NU consolidated level, intercompany transactions between CL&P, NSTAR Electric, PSNH and WMECO and CYAPC and YAEC have been eliminated in consolidation. For CL&P, NSTAR Electric, PSNH and WMECO, the investment in CYAPC and YAECcontinue to be accounted for under the equity method.

On April 10, 2012, upon consummation of the merger with NSTAR, an NSTAR subsidiary that owned 25 percent of NPTwas merged into NUTV, resulting in NUTV owning 100 percent of NPT. Accordingly, 100 percent ownership of NPTwas reflected in Common Shareholders' Equity as of June 30, 2012 on the accompanying unaudited condensed consolidated balance sheet. See Note 2, "Merger of NU and NSTAR," and Note 13, "Common Shareholders' Equity and Noncontrolling Interests," for further information.

Subsequent Events Policy Policy Text Block

NU evaluates events and transactions that occur after the balance sheet date but before financial statements are issued and recognizes in the financial statements the effects of all subsequent events that provide additional evidence about conditions that existed as of the balance sheet date and discloses, but does not recognize, in the financial statements subsequent events that provide evidence about the conditions that arose after the balance sheet date but before the financial statements are issued. See Note 10C, "Commitments and Contingencies – Deferred Contractual Obligations," and Note 17, "Subsequent Events" for further information.

Receivables Policy Text Block

Provision for Uncollectible Accounts

NU, including CL&P, NSTAR Electric, PSNH and WMECO, maintains a provision for uncollectible accounts to record receivables at an estimated net realizable value. This provision is determined based upon a variety of factors, including applying an estimated uncollectible account percentage to each receivable aging category, based upon historical collection and write-off experience and management's assessment of collectibility from individual customers. Management reviews the collectibility of the receivables, and if circumstances change, collectibility estimates are adjusted accordingly. Receivable balances are written off against the provision for uncollectible accounts when the accounts are terminated and these balances are deemed to be uncollectible.

Fair Value Of Financial Instruments Policy

Fair Value Measurements

NU, including CL&P, NSTAR Electric, PSNH, and WMECO, applies fair value measurement guidance to derivative contracts recorded at fair value and to the marketable securities held in the NU supplemental benefit trust, WMECO's spent nuclear fuel trust and CYAPC's and YAEC'snuclear decommissioning trusts. Fair value measurement guidance is also applied to investment valuations used to calculate the funded status of NU'sPension and PBOP Plans, including NSTAR Electric's Pension Plan.

Fair Value Hierarchy: In measuring fair value, NU uses observable market data when available and minimizes the use of unobservable inputs. Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes. The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement. NU evaluates the classification of assets and liabilities measured at fair value on a quarterly basis, and NU's policy is to recognize transfers between levels of the fair value hierarchy as of the end of the reporting period. The three levels of the fair value hierarchy are described below:

Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.

Level 3 - Quoted market prices are not available. Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable. Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.

Determination of Fair Value: The valuation techniques and inputs used in NU's fair value measurements are described in Note 5, "Derivative Instruments," Note 6, "Marketable Securities," and Note11, "Fair Value of Financial Instruments.

Other Taxes Policy

Other Taxes Gross receipts taxes levied by the state of Connecticut are collected by CL&P and Yankee Gas from their respective customers. These gross receipts taxes are shown on a gross basis with collections in Operating Revenues and payments in Taxes Other Than Income Taxes on the accompanying unaudited condensed consolidated statements of income as follows:

Public Utilities Policy Text Block

NU's Regulated companies continue to be rate-regulated on a cost-of-service basis; therefore, the accounting policies of the Regulated companies apply GAAP applicable to rate-regulated enterprises and historically reflect the effects of the rate-making process.

Management believes it is probable that the Regulated companies will recover their respective investments in long-lived assets, including regulatory assets. If management determined that it could no longer apply the accounting guidance applicable to rate-regulated enterprises to the Regulated companies' operations, or that management could not conclude it is probable that costs would be recovered or reflected in future rates, the costs would be charged to net income in the period in which the determination is made.

Derivatives Policy Text Block

DERIVATIVE INSTRUMENTS

The Regulated companies purchase and procure energy and energy-related products for their customers, which are subject to price volatility. The costs associated with supplying energy to customers are recoverable through customer rates. The Company manages the risks associated with the price volatility of energy and energy-related products through the use of derivative contracts, many of which meet the definition of and are designated as "normal purchases or normal sales," (normal), and the use of nonderivative contracts.

The gross fair values of derivative assets and liabilities with the same counterparty are offset and reported as net Derivative Assets or Derivative Liabilities, with current and long-term portions, in the accompanying unaudited condensed consolidated balance sheets.

Fair Value Measurements of Derivative Instruments

Valuation of Derivative Instruments: Derivative contracts classified as Level 2 in the fair value hierarchy relate to the financial contracts for natural gas futures and the remaining unregulated wholesale marketing sourcing contracts to purchase energy for periods in which prices are quoted in an active market. Prices are obtained from broker quotes and are based on actual market activity. The contracts are valued using the mid-point of the bid-ask spread. Valuations of these contracts also incorporate discount rates using the yield curve approach.

The fair value of derivative contracts classified as Level 3 utilize significant unobservable inputs. The fair value is modeled using income techniques, such as discounted cash flow approaches adjusted for assumptions relating to exit price. Significant observable inputs for valuations of these contracts include energy and energy-related product prices in future years for which quoted prices in an active market exist. Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy and energy-related products, and accounting requirements. The future power and capacity prices for periods that are not quoted in an active market or established at auction are based on available market data and are escalated based on estimates of inflation to address the full time period of the contract.

Valuations of derivative contracts using discounted cash flow methodology include assumptions regarding the timing and likelihood of scheduled payments and also reflect non-performance risk, including credit, using the default probability approach based on the counterparty's credit rating for assets and the company's credit rating for liabilities. Valuations incorporate estimates of premiums or discounts that would be required by a market participant to arrive at an exit price, using historical market transactions adjusted for the terms of the contract.

The following is a summary of NU's, including CL&P's, NSTAR Electric's and WMECO's, Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts

Marketable Securities Policy

U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates. Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar instrument and also incorporating yield curves, credit spreads and specific bond terms and conditions. Asset-backed debt securities include collateralized mortgage obligations, commercial mortgage backed securities, and securities collateralized by auto loans, credit card loans or receivables. Asset-backed debt securities are valued using recent trades of similar instruments, prepayment assumptions, yield curves, issuance and maturity dates and tranche information. Municipal bonds are valued using a market approach that incorporates reported trades and benchmark yields. Other fixed income securities are valued using pricing models, quoted prices of securities with similar characteristics, and discounted cash flows.

Earnings Per Share Policy Text Block

Basic EPS is computed based upon the monthly weighted average number of common shares outstanding during each period. Diluted EPS is computed on the basis of the monthly weighted average number of common shares outstanding plus the potential dilutive effect if certain securities are converted into common shares.

RSUs and performance shares are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. The dilutive effect of unvested RSUs and performance shares is calculated using the treasury stock method. Assumed proceeds of the units under the treasury stock method consist of the remaining compensation cost to be recognized and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the units (the difference between the market value of the average units outstanding for the period, using the average market price during the period, and the grant date market value).

The dilutive effect of stock options to purchase common shares is also calculated using the treasury stock method. Assumed proceeds for stock options consist of cash proceeds that would be received upon exercise, and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the stock options (the difference between the market value of the average stock options outstanding for the period, using the average market price during the period, and the exercise price).

Consolidation Variable Interest Entity Policy

VARIABLE INTEREST ENTITIES

The Company's variable interests outside of the consolidated group are not material and consist of contracts that are required by regulation and provide for regulatory recovery of contract costs and benefits through customer rates. NU, CL&P and NSTAR Electric hold variable interests in variable interest entities (VIEs) through agreements with certain entities that own single renewable energy or peaking generation power plants and with other independent power producers. NU, CL&P and NSTAR Electric do not control the activities that are economically significant to these VIEs or provide financial or other support to these VIEs. Therefore, NU, CL&P and NSTAR Electric do not consolidate any power plant VIEs.

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COMMON SHAREHOLDER EQUITY AND NCI (Details) (USD $) Share data in Thousands, unless otherwise specified	0 Months Ended	3 Months Ended		6 Months Ended
	Apr. 09, 2012	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Shareholders' Equity, Beginning Balance				$ 4,012,670,000
Net Income		46,219,000	78,719,000	146,974,000	194,303,000
Net Income Attributable to Noncontrolling Interests		1,880,000	1,441,000	3,373,000	2,870,000
Other Comprehensive Income/ (Loss)		2,435,000	(4,524,000)	4,299,000	(2,421,000)
Shareholders' Equity, Ending Balance		9,067,639,000		9,067,639,000
Common Stock Issuance, Merger with NSTAR [Abstract]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	136,049
Common Shareholders Equity [Member]
Shareholders' Equity, Beginning Balance		4,068,300,000	3,885,300,000
Net Income		46,200,000	78,700,000	147,000,000	194,300,000
Purchase Price Of Nstar		5,038,300,000		5,038,300,000
Other Impacts of Merger With NSTAR		3,400,000		3,400,000
Dividends on Common Shares		(107,600,000)	(48,900,000)	(160,200,000)	(97,700,000)
Dividends, Preferred Stock		(1,900,000)	(1,400,000)	(3,300,000)	(2,800,000)
Issuance of Common Shares		5,200,000		11,400,000	4,200,000
Other Transcations, Net		13,300,000	6,000,000	14,100,000	8,300,000
Net Income Attributable to Noncontrolling Interests				(100,000)
Noncontrolling Interest Member
Shareholders' Equity, Beginning Balance		3,400,000	1,500,000
Other Impacts of Merger With NSTAR		(3,400,000)		(3,400,000)
Contributions To Northern Pass Trans			300,000	300,000	300,000
Net Income Attributable to Noncontrolling Interests				100,000
Total Equity [Member]
Shareholders' Equity, Beginning Balance		4,071,700,000	3,886,800,000
Net Income		46,200,000	78,700,000	147,000,000	194,300,000
Purchase Price Of Nstar		5,038,300,000		5,038,300,000
Dividends on Common Shares		(107,600,000)	(48,900,000)	(160,200,000)	(97,700,000)
Dividends, Preferred Stock		(1,900,000)	(1,400,000)	(3,300,000)	(2,800,000)
Issuance of Common Shares		5,200,000		11,400,000	4,200,000
Contributions To Northern Pass Trans			300,000	300,000	300,000
Other Transcations, Net		13,300,000	6,000,000	14,100,000	8,300,000
Preferred Stock Member
Shareholders' Equity, Beginning Balance		116,200,000	116,200,000
Other Impacts of Merger With NSTAR		39,400,000		39,400,000
Dividends, Preferred Stock		(1,900,000)	(1,400,000)	(3,300,000)	(2,800,000)
Net Income Attributable to Noncontrolling Interests		$ 1,900,000	$ 1,400,000	$ 3,300,000	$ 2,800,000

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MERGER OF NU AND NSTAR

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Business Combination Disclosure [Text Block]

2.       MERGER OF NU AND NSTAR

On April 10, 2012, NU acquired 100 percent of the outstanding common shares of NSTAR. Pursuant to the terms and conditions of the Agreement and Plan of Merger, as amended, the "Merger Agreement," NSTAR merged into NSTAR LLC, becoming a wholly-owned subsidiary of NU.

NSTAR LLC is a holding company engaged through its subsidiaries in the energy delivery business serving electric and natural gas distribution customers in Massachusetts. The merger was structured as a merger of equals in a tax-free exchange of shares. As part of the merger, NSTAR shareholders received 1.312 NU common shares for each NSTAR common share owned (the "exchange ratio") as of the acquisition date. The exchange ratio was structured to result in a no-premium merger based on the average closing share price of each company's common shares for the 20 trading days preceding the announcement of the merger in October 2010. NU issued approximately 136 million common shares to the NSTAR shareholders as a result of the merger, which brought the total common shares outstanding to approximately 314 million shares as of April 10, 2012.

Purchase Price: Pursuant to the merger, all of the NSTAR common shares were exchanged at the fixed exchange ratio of 1.312 common shares of NU for each NSTAR common share. The total consideration transferred in the merger was based on the closing price of NU common shares on April 9, 2012, the day prior to the date the merger was completed, and was calculated as follows:

NSTAR common shares outstanding as of April 9, 2012 (in thousands)*		103,696
Exchange ratio		1.312
NU common shares issued for NSTAR common shares outstanding (in thousands)		136,049
Closing price of NU common shares on April 9, 2012	$	36.79
Value of common shares issued (in millions)	$	5,005
Fair value of NU replacement stock-based compensation awards related to pre-merger service (in millions)		33
Total purchase price (in millions)	$	5,038

*       Includes 109 thousand shares related to NSTAR stock-based compensation awards that vested immediately prior to the merger.

Certain of NSTAR's stock-based compensation awards, including deferred shares, performance shares and all outstanding stock options, were replaced with NU awards using the exchange ratio upon consummation of the merger. In accordance with accounting guidance for business combinations, the portion of the fair value of these awards attributable to pre-merger service is included in the purchase price as it represents consideration transferred in the merger. See Note 9B, "Employee Benefits – Share-Based Payments," for further information.

Purchase Price Allocation: The allocation of the total purchase price to the estimated fair values of the assets acquired and liabilities assumed has been determined based on the accounting guidance for fair value measurements, which defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The allocation of the total purchase price includes adjustments to record the fair value of NSTAR's unregulated telecommunications business, regulatory assets not earning a return, lease agreements, long-term debt and the preferred stock of NSTAR Electric. The fair values of NSTAR's assets and liabilities were determined based on significant estimates and assumptions, including Level 3 inputs, that are judgmental in nature. These estimates and assumptions include the timing and amounts of projected future cash flows and discount rates reflecting risk inherent in future cash flows.All purchase price adjustments are preliminary and subject to change as additional information is obtained.

The excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed was recognized as goodwill. The allocation of goodwill to NU's reporting units has not yet been completed. The preliminary allocation of the purchase price is as follows:

(Millions of Dollars)
Current Assets	$	754
Property Plant and Equipment, Net		5,155
Goodwill		3,231
Other Long-Term Assets, excluding Goodwill		2,115
Current Liabilities		(1,332)
Long-Term Liabilities		(2,723)
Long-Term Debt and Other Long-Term Obligations		(2,123)
Preferred Stock of Subsidiary		(39)
Total Purchase Price	$	5,038

Pro Forma Financial Information:The following unaudited pro forma financial information reflects the pro forma combined results of operations of NU and NSTAR and reflects the amortization of purchase price adjustments assuming the merger had taken place on January 1, 2011. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of NU. The pro forma financial information does not include potential cost savings or non-recurring costs. This information is preliminary in nature and subject to change.

(Pro forma amounts in millions, except per share amounts)	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2012		2011		2012		2011
Operating Revenues	$	1,629	$	1,691	$	3,459	$	3,754
Net Income Attributable to Controlling Interest		133		142		243		328
Basic EPS		0.42		0.45		0.77		1.05
Diluted EPS		0.42		0.45		0.77		1.04

NU and NSTAR incurred non-recurring transaction costs and costs related to the Connecticut and Massachusetts settlement agreements recorded in the second quarter of 2012 described below, with the following aggregate after-tax impacts not included in the pro forma earnings presented above:

		For the Three Months Ended June 30,				For the Six Months Ended June 30,
(Millions of Dollars)		2012		2011		2012		2011
Transaction and Other Costs		$	29	$	2	$	31	$	16
Settlement Agreement Impacts			60		0		60		0
Total After-Tax Non-Recurring Costs Excluded
	from Net Income	$	89	$	2	$	91	$	16

Regulatory Approvals: On February 15, 2012, NU and NSTAR reached comprehensive settlement agreements with the Massachusetts Attorney General and the DOER related to the merger. On April 4, 2012, the DPU approved the settlement agreements and the merger of NU and NSTAR.On March 13, 2012, NU and NSTAR reached a comprehensive settlement agreement with both the Connecticut Attorney General and the Connecticut Office of Consumer Counsel. On April 2, 2012, the PURA approved the settlement agreement and the merger of NU and NSTAR. The settlement agreements included base distribution rate freezes until December 1, 2014 for CL&P and through2015 for NSTAR Electric, NSTAR Gas and WMECO.

See Note 10B,"Commitments and Contingencies – Long-Term Contractual Arrangements,” for further information on commitments required under the settlement agreements.

The pre-tax financial impacts of the Connecticut and Massachusetts settlement agreements that were recognized by NU, CL&P, NSTAR Electric, and WMECO in the second quarter of 2012 are summarized as follows:

	For The Three and Six Months Ended June 30, 2012
(Millions of Dollars)	NU		CL&P		NSTAR Electric		WMECO
Customer Rate Credits	$	46	$	25	$	15	$	3
Storm Costs Deferral Reduction		40		40		-		-
Establishment of Energy Efficiency Fund		15		-		-		-
Total	$	101	$	65	$	15	$	3

NSTAR Revenues and Net Income: The impact of NSTAR LLC and its subsidiaries on the revenues and net income attributable to controlling interest of NU on the accompanying unaudited condensed consolidated statements of income for both the three and six months ended June 30, 2012 was an increase of $601.3 million and $35.9 million, respectively.

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CONSOLIDATED STATEMENTS OF INCOME (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Operating Revenues	1,628,684	1,047,481	2,728,307	2,282,732
Operating Expenses:
Fuel, Purchased and Net Interchange Power	542,014	382,542	937,358	879,246
Operations And Maintenance	529,977	269,701	791,940	533,323
Depreciation	144,485	73,637	225,324	147,588
Amortization of Regulatory Assets/(Liabilities), Net	25,590	16,992	31,016	50,491
Amortization of Rate Reduction Bonds	40,752	17,086	59,100	34,367
Energyefficiencyandrenewableenergyprograms	73,489	29,970	110,762	64,403
Taxes Other Than Income Taxes	112,862	79,419	198,899	167,823
Total Operating Expenses	1,469,169	869,347	2,354,399	1,877,241
Operating Income	159,515	178,134	373,908	405,491
Interest Expense:
Interest on Long-Term Debt	86,925	57,044	146,892	114,444
Interest on Rate Reduction Bonds	2,056	2,293	3,487	4,871
Other Interest	66	2,897	5,116	1,468
Total Interest Expense	89,047	62,234	155,495	120,783
Other Income/(Loss), Net	1,806	7,334	10,580	17,647
Income Before Income Tax Expense	72,274	123,234	228,993	302,355
Income Tax Expense	26,055	44,515	82,019	108,052
Net Income	46,219	78,719	146,974	194,303
Net Income Attributable to Noncontrolling Interests	1,880	1,441	3,373	2,870
Net Income Attributable to Controlling Interests	44,339	77,278	143,601	191,433
Earnings Per Share Basic And Diluted	0.15	0.44	0.60	1.08
Common Stock Dividends Per Share Declared	0.34	0.28	0.63	0.55
Weighted Average Common Shares Outstanding:
Basic	301,047,753	177,347,374	239,551,735	177,267,791
Diluted	301,816,884	177,626,992	240,127,169	177,553,995
The Connecticut Light And Power Company [Member]
Operating Revenues	562,141	608,013	1,154,106	1,281,695
Operating Expenses:
Fuel, Purchased and Net Interchange Power	196,806	230,380	417,697	502,338
Operations And Maintenance	205,471	136,669	338,373	272,411
Depreciation	41,519	38,442	82,588	77,917
Amortization of Regulatory Assets/(Liabilities), Net	3,263	13,705	11,257	32,339
Energyefficiencyandrenewableenergyprograms	20,995	21,291	42,968	44,715
Taxes Other Than Income Taxes	53,706	52,727	108,978	111,193
Total Operating Expenses	521,760	493,214	1,001,861	1,040,913
Operating Income	40,381	114,799	152,245	240,782
Interest Expense:
Interest on Long-Term Debt	31,696	33,430	63,218	66,758
Other Interest	2,075	868	4,060	(2,708)
Total Interest Expense	33,771	34,298	67,278	64,050
Other Income/(Loss), Net	447	2,058	5,747	6,663
Income Before Income Tax Expense	7,057	82,559	90,714	183,395
Income Tax Expense	124	29,924	29,796	66,423
Net Income	6,933	52,635	60,918	116,972
Public Service Company Of New Hampshire [Member]
Operating Revenues	255,105	240,191	498,102	509,661
Operating Expenses:
Fuel, Purchased and Net Interchange Power	82,116	74,372	163,165	169,375
Operations And Maintenance	68,435	76,281	133,413	140,469
Depreciation	21,811	18,122	43,018	36,030
Amortization of Regulatory Assets/(Liabilities), Net	2,798	2,465	177	18,032
Amortization of Rate Reduction Bonds	13,814	13,004	27,743	26,139
Energyefficiencyandrenewableenergyprograms	3,213	2,774	6,794	5,840
Taxes Other Than Income Taxes	15,872	15,234	31,360	28,902
Total Operating Expenses	208,059	202,252	405,670	424,787
Operating Income	47,046	37,939	92,432	84,874
Interest Expense:
Interest on Long-Term Debt	11,539	8,317	23,103	16,941
Interest on Rate Reduction Bonds	786	1,676	1,802	3,570
Other Interest	460	408	692	346
Total Interest Expense	12,785	10,401	25,597	20,857
Other Income/(Loss), Net	549	4,361	2,590	8,820
Income Before Income Tax Expense	34,810	31,899	69,425	72,837
Income Tax Expense	13,578	10,234	26,931	23,708
Net Income	21,232	21,665	42,494	49,129
Western Massachusetts Electric Company [Member]
Operating Revenues	106,836	98,390	220,861	205,074
Operating Expenses:
Fuel, Purchased and Net Interchange Power	32,715	37,965	73,269	83,195
Operations And Maintenance	27,847	20,556	50,449	41,306
Depreciation	6,994	6,625	14,691	12,963
Amortization of Regulatory Assets/(Liabilities), Net	(44)	1,526	(387)	728
Amortization of Rate Reduction Bonds	4,358	4,082	8,776	8,228
Energyefficiencyandrenewableenergyprograms	4,933	4,956	10,489	10,380
Taxes Other Than Income Taxes	4,977	4,203	9,858	8,745
Total Operating Expenses	81,780	79,913	167,145	165,545
Operating Income	25,056	18,477	53,716	39,529
Interest Expense:
Interest on Long-Term Debt	5,905	4,722	11,671	9,476
Interest on Rate Reduction Bonds	343	617	757	1,301
Other Interest	621	121	836	257
Total Interest Expense	6,869	5,460	13,264	11,034
Other Income/(Loss), Net	188	242	1,280	981
Income Before Income Tax Expense	18,375	13,259	41,732	29,476
Income Tax Expense	7,237	5,088	16,408	11,339
Net Income	11,138	8,171	25,324	18,137
NSTAR Electric Company [Member]
Operating Revenues	534,626	552,346	1,091,102	1,129,821
Operating Expenses:
Fuel, Purchased and Net Interchange Power	180,502	212,055	399,512	455,062
Operations And Maintenance	109,038	87,823	257,218	185,053
Depreciation	42,669	41,637	85,198	83,157
Amortization of Regulatory Assets/(Liabilities), Net	22,144	13,407	46,024	29,669
Amortization of Rate Reduction Bonds	22,581	22,581	45,161	45,161
Energyefficiencyandrenewableenergyprograms	35,487	32,865	82,391	72,956
Taxes Other Than Income Taxes	28,308	26,423	59,169	55,489
Total Operating Expenses	440,729	436,791	974,673	926,547
Operating Income	93,897	115,555	116,429	203,274
Interest Expense:
Interest on Long-Term Debt	22,279	22,583	44,567	45,176
Interest on Rate Reduction Bonds	927	1,839	2,253	4,053
Other Interest	(5,597)	(8,082)	(11,433)	(15,329)
Total Interest Expense	17,609	16,340	35,387	33,900
Other Income/(Loss), Net	6	910	1,227	1,719
Income Before Income Tax Expense	76,294	100,125	82,269	171,093
Income Tax Expense	30,812	39,471	32,847	67,546
Net Income	45,482	60,654	49,422	103,547

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FAIR VALUE OF FINANCIAL INSTRUMENTS

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Fair Value Disclosures [Text Block]

11.       FAIR VALUE OF FINANCIAL INSTRUMENTS

The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:

Preferred Stock, Long-Term Debt and Rate Reduction Bonds: The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections. The fair value of fixed-rate long-term debt securities and RRBs is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields. Adjustable rate securities are assumed to have a fair value equal to their carrying value. The fair values provided in the tables below are classified as Level 2 within the fair value hierarchy. Carrying amounts and estimated fair values are as follows:

		As of June 30, 2012				As of December 31, 2011
		NU				NU
		Carrying		Fair		Carrying		Fair
(Millions of Dollars)		Amount		Value		Amount		Value
Preferred Stock Not
	Subject to Mandatory
	Redemption	$	155.6	$	153.1	$	116.2	$	105.1
Long-Term Debt			7,619.7		8,302.7		4,950.7		5,517.0
Rate Reduction Bonds			160.1		163.6		112.3		116.8

		As of June 30, 2012
		CL&P				NSTAR Electric				PSNH				WMECO
		Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
(Millions of Dollars)		Amount		Value		Amount		Value		Amount		Value		Amount		Value
Preferred Stock Not
	Subject to Mandatory
	Redemption	$	116.2	$	110.1	$	43.0	$	43.0	$	-	$	-	$	-	$	-
Long-Term Debt			2,584.0		3,029.3		1,603.4		1,842.0		997.8		1,089.0		499.6		550.1
Rate Reduction Bonds			-		-		84.3		85.8		57.7		59.2		18.1		18.6
		As of December 31, 2011
		CL&P				NSTAR Electric(1)				PSNH				WMECO
		Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
(Millions of Dollars)		Amount		Value		Amount		Value		Amount		Value		Amount		Value
Preferred Stock Not
	Subject to Mandatory
	Redemption	$	116.2	$	105.1	$	43.0	$	41.2	$	-	$	-	$	-	$	-
Long-Term Debt			2,587.8		2,987.1		1,605.1		1,816.1		999.5		1,075.2		501.1		539.8
Rate Reduction Bonds			-		-		127.9		131.2		85.4		88.8		26.9		28.1

• NSTAR Electric amounts are not included in NU consolidated as of December 31, 2011.

Derivative Instruments: NU, including CL&P, NSTAR Electric, PSNH and WMECO, holds various derivative instruments that are carried at fair value. For further information, see Note 5, "Derivative Instruments," to the unaudited condensed consolidated financial statements.

Other Financial Instruments: Investments in marketable securities are carried at fair value on the accompanying unaudited condensed consolidated balance sheets. For further information, see Note 1E, "Summary of Significant Accounting Policies - Fair Value Measurements," and Note 6, "Marketable Securities."

The carrying value of other financial instruments included in current assets and current liabilities, including cash and cash equivalents and special deposits, approximates their fair value due to the short-term nature of these instruments.

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Document and Entity Information (USD $)	6 Months Ended
	Jun. 30, 2012	Jul. 31, 2012
Document And Entity [Line Items]
Entity Registrant Name	NORTHEAST UTILITIES
Document Period End Date	Jun. 30, 2012
Document Type	10-Q
Entity Central Index Key	0000072741
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		313,804,466
Entity Public Float	$ 12,177,646,948
Entity Filer Category	Large Accelerated Filer
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	Yes
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q2
Amendment Flag	false
The Connecticut Light And Power Company [Member]
Document And Entity [Line Items]
Entity Registrant Name	The Connecticut Light and Power Company
Entity Central Index Key	0000023426
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Public Service Company Of New Hampshire [Member]
Document And Entity [Line Items]
Entity Registrant Name	Public Service Company of New Hampshire
Entity Central Index Key	0000315256
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Western Massachusetts Electric Company [Member]
Document And Entity [Line Items]
Entity Registrant Name	Western Massachusetts Electric Company
Entity Central Index Key	0000106170
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
NSTAR Electric Company [Member]
Document And Entity [Line Items]
Entity Registrant Name	NSTAR Electric Company
Entity Central Index Key	0000013372
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

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COMMON SHARES

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule of Stock by Class [Text Block]

12.       COMMON SHARES

The following table sets forth the NU common shares and the shares of CL&P, NSTAR Electric, PSNH and WMECO common stock authorized and issued as of June 30, 2012 and December 31, 2011 and the respective par values:

	Shares
	Authorized				Issued
	Per Share		As of June 30, 2012
	Par Value		and December 31, 2011		As of June 30, 2012		As of December 31, 2011
NU	$	5		380,000,000		332,450,199		196,052,770
CL&P	$	10		24,500,000		6,035,205		6,035,205
NSTAR Electric	$	1		100,000,000		100		100
PSNH	$	1		100,000,000		301		301
WMECO	$	25		1,072,471		434,653		434,653

As a result of the merger with NSTAR on April 10, 2012, NU issued approximately 136 million common shares to the NSTAR shareholders.

As of June 30, 2012 and December 31, 2011,18,674,189 and 18,894,078 NU common shares were held as treasury shares, respectively.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Net Income	$ 46,219	$ 78,719	$ 146,974	$ 194,303
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Qualified Cash Flow Hedging Instruments	516	(5,095)	939	(3,922)
Change in Unrealized Gains/Losses in Other Securities	160	149	194	144
Change in Funded Status of Pension, SERP and Other Postretirement Benefit Plans	1,759	422	3,166	1,357
Other Comprehensive Income/ (Loss)	2,435	(4,524)	4,299	(2,421)
Comprehensive Income Attributable to Noncontrolling Interests	(1,880)	(1,441)	(3,373)	(2,870)
Comprehensive Income	46,774	72,754	147,900	189,012
The Connecticut Light And Power Company [Member]
Net Income	6,933	52,635	60,918	116,972
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Qualified Cash Flow Hedging Instruments	111	111	222	222
Change in Unrealized Gains/Losses in Other Securities	5	5	6	5
Other Comprehensive Income/ (Loss)	116	116	228	227
Comprehensive Income	7,049	52,751	61,146	117,199
Public Service Company Of New Hampshire [Member]
Net Income	21,232	21,665	42,494	49,129
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Qualified Cash Flow Hedging Instruments	291	(3,998)	581	(3,072)
Change in Unrealized Gains/Losses in Other Securities	9	8	11	8
Change in Funded Status of Pension, SERP and Other Postretirement Benefit Plans	4	0	4	0
Other Comprehensive Income/ (Loss)	304	(3,990)	596	(3,064)
Comprehensive Income	21,536	17,675	43,090	46,065
Western Massachusetts Electric Company [Member]
Net Income	11,138	8,171	25,324	18,137
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Qualified Cash Flow Hedging Instruments	84	(1,144)	169	(945)
Change in Unrealized Gains/Losses in Other Securities	2	2	2	2
Other Comprehensive Income/ (Loss)	86	(1,142)	171	(943)
Comprehensive Income	11,224	7,029	25,495	17,194
NSTAR Electric Company [Member]
Net Income	$ 45,482	$ 60,654	$ 49,422	$ 103,547

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SHORT TERM DEBT

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Short Term Debt Text Block

7.       SHORT-TERM DEBT (CL&P)

Limits: The amount of short-term borrowings that may be incurred by CL&P are subject to periodic approval by the FERC. On November 30, 2011, the FERC granted authorization to allow CL&P to incur total short-term borrowings up to a maximum of $450 million effective January 1, 2012 through December 31, 2013. On March 22, 2012, FERC approved CL&P's application requesting to increase its total short-term borrowing capacity from a maximum of $450 million to a maximum of $600 million for the authorization period through December 31, 2013.

CL&P Credit Agreement: On March 26, 2012, CL&P entered into a five-year unsecured revolving credit facility in the amount of $300 million, which expires on March 26, 2017. Under this facility, CL&P can borrow either on a short-term or a long-term basis subject to regulatory approval. As of June 30, 2012, CL&P had $300 million in short-term borrowings outstanding under this credit facility, which was recorded in Notes Payable to Banks on the accompanying unaudited condensed consolidated balance sheet.

Under this facility, CL&P may borrow at prime rates or LIBOR-based rates, plus an applicable margin based on the higher of S&P's or Moody's credit ratings. The weighted-average interest rate on the borrowings outstanding under this facility as of June 30, 2012 was 1.59 percent.

In addition, CL&P must comply with certain financial and non-financial covenants, including a consolidated debt to total capitalization ratio. CL&P was in compliance with these covenants as of June 30, 2012. If CL&P was not in compliance with these covenants, an event of default would occur requiring all outstanding borrowings to be repaid and additional borrowings would not be permitted under this credit facility.

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MARKETABLE SECURITIES

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Marketable Securities [Text Block]

6.       MARKETABLE SECURITIES (NU, WMECO)

NU maintains a supplemental benefit trust to fund NU's SERP and non-SERP obligations and WMECO maintains a spent nuclear fuel trust to fund WMECO's prior period spent nuclear fuel liability, each of which hold marketable securities. These trusts are not subject to regulatory oversight by state or federal agencies.As of April 10, 2012, upon consummation of the mergerwith NSTAR and consolidation of CYAPC and YAEC, NU's marketable securities also includes legally restricted trustsfor the decommissioning of nuclear power plants.

The Company elects to record mutual funds purchased by the NU supplemental benefit trust at fair value. As such, any change in fair value of these mutual funds is reflected in Net Income. These mutual funds, classified as Level 1 in the fair value hierarchy, totaled $43.8million and $41.1million as of June 30, 2012 and December31,2011, respectively, and are included in current Marketable Securities. Net losses on these securities of $0.5 million for the three months ended June 30, 2012 and netgains on these securities of $2.7million for the six months ended June 30, 2012 andnet gains of$0.3million and $2.2million for the three and six months ended June 30, 2011, respectively, were recorded in Other Income, Net on the accompanying unaudited condensed consolidated statements of income. Dividend income is recorded when dividends are declared and are recorded in Other Income, Net on the accompanying unaudited condensed consolidated statements of income. All other marketable securities are accounted for as available-for-sale.

Available-for-Sale Securities: The following is a summary of NU's available-for-sale securities held in the NU supplemental benefit trust, WMECO's spent nuclear fuel trust and CYAPC and YAEC's nuclear decommissioning trusts. These securities are recorded at fair value and included in current and long-term Marketable Securities on the accompanying unaudited condensed consolidated balance sheets.

		As of June 30, 2012
				Pre-Tax		Pre-Tax
		Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains(1)		Losses(1)		Fair Value
NU
	Debt Securities(2)	$	256.1	$	10.9	$	(0.3)	$	266.7
	Equity Securities(2)		134.6		12.0		(5.6)		141.0
WMECO
	Debt Securities		57.5		0.1		(0.1)		57.5
		As of December 31, 2011
				Pre-Tax		Pre-Tax
		Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains(1)		Losses(1)		Fair Value
NU		$	88.4	$	2.0	$	(0.2)	$	90.2
WMECO			57.3		-		(0.2)		57.1

• Unrealized gains and losses on debt securities for the NU supplemental benefit trust and WMECO spent nuclear fuel trust are recorded in AOCI and Other Long-Term Assets, respectively, on the accompanying unaudited condensed consolidated balance sheets.

(2)       NU's June 30, 2012 amounts include CYAPC's and YAEC's marketable securities held in nuclear decommissioning trusts of $304 million, the majority of which are legally restricted and can only be used for the decommissioning of the nuclear power plants owned by these companies. Unrealized gains and losses for the nuclear decommissioning trusts are offset against the spent nuclear fuel obligation recorded in Other Long-Term Liabilities on the accompanying unaudited condensed consolidated balance sheet. All of the equity securities accounted for as available-for-sale securities are held in these trusts.

Unrealized Losses and Other-than-Temporary Impairment: There have been no significant unrealized losses, other-than-temporary impairments or credit losses for the NU supplemental benefit trust or WMECO spent nuclear fuel trust.Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security. For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.

Realized Gains and Losses: Realized gains and losses on available-for-sale securities are recorded in Other Income, Net for the NU supplemental benefit trust and in Other Long-Term Assets for the WMECO spent nuclear fuel trust. NU utilizes the specific identification basis method for the NU supplemental benefit trust securities and the average cost basis method for the WMECO spent nuclear fuel trust and the CYAPC and YAEC nuclear decommissioning trusts to compute the realized gains and losses on the sale of available-for-sale securities.

Contractual Maturities: As of June 30, 2012, the contractual maturities of available-for-sale debt securities are as follows:

	NU				WMECO
	Amortized				Amortized
(Millions of Dollars)	Cost		Fair Value		Cost		Fair Value
Less than one year(1)	$	52.9	$	52.9	$	18.5	$	18.5
One to five years		53.8		55.0		23.2		23.2
Six to ten years		51.9		54.9		6.0		6.1
Greater than ten years		97.5		103.9		9.8		9.7
Total Debt Securities	$	256.1	$	266.7	$	57.5	$	57.5

(1)Amounts in the Less than one year category include securities in the nuclear decommissioning trust, which are restricted and are classified in long-term Marketable Securitieson the accompanying unaudited condensed consolidated balance sheet.

Fair Value Measurements: The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:

			NU				WMECO
			As of		As of		As of		As of
(Millions of Dollars)			June 30, 2012		December 31, 2011		June 30, 2012		December 31, 2011
Level 1:
	Mutual Funds and Equity Securities		$	184.8	$	41.1	$	-	$	-
	Money Market Funds			36.3		1.8		3.8		0.1
Total Level 1			$	221.1	$	42.9	$	3.8	$	0.1
Level 2:
	U.S. Government Issued Debt Securities
		(Agency and Treasury)		59.5		11.1		18.7		8.0
	Corporate Debt Securities			31.4		16.5		6.2		9.1
	Asset-Backed Debt Securities			27.4		25.9		6.5		7.9
	Municipal Bonds			96.4		16.1		15.5		15.4
	Other Fixed Income Securities			15.7		18.8		6.8		16.6
Total Level 2			$	230.4	$	88.4	$	53.7	$	57.0
Total Marketable Securities			$	451.5	$	131.3	$	57.5	$	57.1

U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates. Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar instrument and also incorporating yield curves, credit spreads and specific bond terms and conditions. Asset-backed debt securities include collateralized mortgage obligations, commercial mortgage backed securities, and securities collateralized by auto loans, credit card loans or receivables. Asset-backed debt securities are valued using recent trades of similar instruments, prepayment assumptions, yield curves, issuance and maturity dates and tranche information. Municipal bonds are valued using a market approach that incorporates reported trades and benchmark yields. Other fixed income securities are valued using pricing models, quoted prices of securities with similar characteristics, and discounted cash flows.

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SUBSEQUENT EVENTS

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Subsequent Events [Text Block]

17.       SUBSEQUENT EVENTS

On July 25, 2012, NU, NSTAR LLC, NSTAR Gas, CL&P, PSNH, WMECO, and Yankee Gas jointly entered into a five-year $1.15 billion revolving credit facility. The new facility replaced (1) the NSTAR LLC revolving credit facility of $175 million that served to backstop a commercial paper program utilized by NSTAR LLC and was scheduled to expire on December 31, 2012, (2) the NSTAR Gas revolving credit facility of $75 million that expired on June 8, 2012, and (3) the CL&P, PSNH, WMECO, and Yankee Gas joint three-year $400 million and NU parent three-year $500 million unsecured revolving credit facilities that were scheduled to expire on September 24, 2013. The new facility expires on July 25, 2017. Management expects the new facility to be used primarily to backstop the $1.15 billion commercial paper program at NU, which commenced July 25, 2012.

On July 25, 2012, NSTAR Electric entered into a five-year $450 million revolving credit facility. This new facility serves to backstop NSTAR Electric's existing $450 million commercial paper program. This new facility replaced a prior $450 million NSTAR Electric revolving credit facility that was scheduled to expire on December 31, 2012.

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COMMON SHARESHOLDERS' EQUITY AND NONCONTROLLING INTERESTS (NU)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

13.COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS (NU)

A summary of the changes in Common Shareholders' Equity and Noncontrolling Interests of NU is as follows:

		For the Three Months Ended
		June 30, 2012								June 30, 2011
								Noncontrolling								Noncontrolling
		Common						Interest -		Common						Interest -
		Shareholders'		Noncontrolling		Total		Preferred Stock		Shareholders'		Noncontrolling		Total		Preferred Stock
(Millions of Dollars)		Equity		Interest		Equity		of Subsidiaries		Equity		Interest		Equity		of Subsidiaries
Balance as of Beginning
	of Period	$	4,068.3	$	3.4	$	4,071.7	$	116.2	$	3,885.3	$	1.5	$	3,886.8	$	116.2
Net Income			46.2		-		46.2		-		78.7		-		78.7		-
Purchase Price of NSTAR(1)			5,038.3		-		5,038.3		-		-		-		-		-
Other Impacts of Merger with
	NSTAR(2)		3.4		(3.4)		-		39.4		-		-		-		-
Dividends on Common Shares			(107.6)		-		(107.6)		-		(48.9)		-		(48.9)		-
Dividends on Preferred Stock			(1.9)		-		(1.9)		(1.9)		(1.4)		-		(1.4)		(1.4)
Issuance of Common Shares			5.2		-		5.2		-		-		-		-		-
Contributions to NPT			-		-		-		-		-		0.3		0.3		-
Other Transactions, Net			13.3		-		13.3		-		6.0		-		6.0		-
Net Income Attributable to
	Noncontrolling Interests		-		-		-		1.9		-		-		-		1.4
Other Comprehensive Income			2.4		-		2.4		-		(4.6)		-		(4.6)		-
Balance as of End of Period		$	9,067.6	$	-	$	9,067.6	$	155.6	$	3,915.1	$	1.8	$	3,916.9	$	116.2
		For the Six Months Ended
		June 30, 2012								June 30, 2011
								Noncontrolling								Noncontrolling
		Common						Interest -		Common						Interest -
		Shareholders'		Noncontrolling		Total		Preferred Stock		Shareholders'		Noncontrolling		Total		Preferred Stock
(Millions of Dollars)		Equity		Interest		Equity		of Subsidiaries		Equity		Interest		Equity		of Subsidiaries
Balance as of Beginning
	of Period	$	4,012.7	$	3.0	$	4,015.7	$	116.2	$	3,811.2	$	1.5	$	3,812.7	$	116.2
Net Income			147.0		-		147.0		-		194.3		-		194.3		-
Purchase Price of NSTAR(1)			5,038.3		-		5,038.3		-		-		-		-		-
Other Impacts of Merger with
	NSTAR(2)		3.4		(3.4)		-		39.4		-		-		-		-
Dividends on Common Shares			(160.2)		-		(160.2)		-		(97.7)		-		(97.7)		-
Dividends on Preferred Stock			(3.3)		-		(3.3)		(3.3)		(2.8)		-		(2.8)		(2.8)
Issuance of Common Shares			11.4		-		11.4		-		4.2		-		4.2		-
Contributions to NPT			-		0.3		0.3		-		-		0.3		0.3		-
Other Transactions, Net			14.1		-		14.1		-		8.3		-		8.3		-
Net Income Attributable to
	Noncontrolling Interests		(0.1)		0.1		-		3.3		-		-		-		2.8
Other Comprehensive Income			4.3		-		4.3		-		(2.4)		-		(2.4)		-
Balance as of End of Period		$	9,067.6	$	0.0	$	9,067.6	$	155.6	$	3,915.1	$	1.8	$	3,916.9	$	116.2

• On April 10, 2012, in connection with the consummation of the merger with NSTAR, NU issued approximately 136 million common shares to the NSTAR shareholders.See Note 2, "Merger of NU and NSTAR," for further information.
• The preferred stock of NSTAR Electric is not subject to mandatory redemption and has been presented as a noncontrolling interest in NSTAR Electric in the accompanying unaudited condensed consolidated financial statements of NU. In addition, upon completion of the merger, an NSTAR subsidiary that held 25 percent of NPT was merged into NUTV, resulting in NUTV owning 100 percent of NPT. Accordingly, the noncontrolling interest balance was eliminated and 100 percent ownership of NPT is reflected in Common Shareholders' Equity as of June 30, 2012.

For the three and six months ended June 30, 2012, there was no change in NU parent's 100 percent ownership of the common equity of CL&P.

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SHARE-BASED PAYMENTS

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Shareholders' Equity and Share-based Payments [Text Block]

B.       Share-Based Payments

In accordance with accounting guidance for share-based payments, share-based compensation awards are recorded using the fair value-based method at the date of grant. NU, CL&P, NSTAR Electric, PSNH and WMECO record compensation cost related to these awards, as applicable, for shares issued or sold to NU, CL&P, NSTAR Electric, PSNH and WMECO employees and officers, as well as the allocation of costs associated with shares issued or sold to NU's service companies' employees and officers that support CL&P, NSTAR Electric, PSNH and WMECO.

Upon consummation of the merger of NU and NSTAR, the NSTAR 1997 Share Incentive Plan and the NSTAR 2007 Long-Term Incentive Plan were assumed by NU. Share-based awards granted under the NSTAR Plans and held by NSTARemployees and officers were generally converted into outstanding NU share-based compensation awards with the estimated fair value of $53.2 million. Refer to Note 2, "Merger of NU and NSTAR," for further information regarding the merger transaction. Specifically, as of the merger closing, and as adjusted by the exchange ratio, (1) NU converted outstanding NSTAR stock options into 2,664,894NU stock options valued at $30.5million, (2) NU converted NSTARDeferred Shares and NSTAR Performance Shares into 421,775 NU RSU's valued at $15.5 million, and (3) NU converted NSTAR RSU Retention Awards into 195,619 NU RSU Retention Awards valued at $7.2 million.

NU Incentive Plan: NU maintains long-term equity-based incentive plans under the NU Incentive Plan in which NU, CL&P, PSNH and WMECO employees, officers and board members are entitled to participate. The NU Incentive Plan was approved in 2007, and authorized NU to grant up to 4,500,000 new shares for various types of awards, including RSUs and performance shares, to eligible employees, officers, and board members. As of June30, 2012 and December 31, 2011, NU had 2,530,024and 2,685,615 common shares, respectively, available for issuance under the NU Incentive Plan. In addition to the NU Incentive Plan, NU maintains an ESPP for all eligible employees.

NSTAR Incentive Plans: Awards may continue to be granted following the merger under the NSTAR 2007 Long-Term Incentive Plan; however, no additional awards will be granted under the NSTAR 1997 Share Incentive Plan. The aggregate number of common shares initially authorized for issuance under the NSTAR 2007 Long-Term Incentive Plan was 3,500,000. As of June 30, 2012 and December 31, 2011, there were 977,922and 988,729 common shares, respectively, available for issuance under the NSTAR 2007 Long-Term Incentive Plan.

NU accounts for its various share-based plans as follows:

• For grants of RSUs, NU records compensation expense, net of estimated forfeitures, on a straight-line basis over the vesting period based upon the fair value of NU's common shares at the date of grant. The par value of RSUs is reclassified to Common Stock from APIC as RSUs become issued as common shares.
• For grants of performance shares, NU records compensation expense, net of estimated forfeitures, on a straight-line basis over the vesting period. Performance shares vest based upon the extent to which Company goals are achieved. For the majority of performance shares, fair value is based upon the value of NU's common shares at the date of grant and compensation expense is recorded based upon the probable outcome of the achievement of Company targets. For the remaining performance shares, vesting is based upon the achievement of the Company's share price as compared to an index of similar equity securities. The fair value at the date of grant for these remaining performance shares was determined using a lattice model and compensation expense is recorded over the vesting period.
• For shares sold under the ESPP, no compensation expense is recorded, as the ESPP qualifies as a non-compensatory plan.

For the six months ended June 30, 2012 and 2011, additional tax benefits totaling $2.8million and $1.1million, respectively, increased cash flows from financing activities.

RSUs: NU has granted RSUs under the 2004 through 2012 incentive programs that are subject to three-year graded vesting schedules for employees, and one-year graded vesting schedules for board members. RSUs are paid in shares, reduced by amounts sufficient to satisfy withholdings, subsequent to vesting. A summary of RSU transactions is as follows:

			Weighted Average
	RSUs		Grant-Date
RSUs	(Units)		Fair Value
Outstanding as of December 31, 2011		959,920	$	26.36
Granted		538,724	$	32.72
Converted NSTAR awards upon merger		617,394	$	36.79
Converted from NU performance shares upon merger		451,358	$	34.32
Shares issued		(300,460)	$	27.90
Forfeited		(76,361)	$	34.77
Outstanding as of June 30, 2012		2,190,575	$	31.97

As of June 30, 2012 and December 31, 2011, the number and weighted average grant-date fair value of unvested RSUs was 1,380,118and $34.62 per share, and 403,108and $28.70 per share, respectively. The number and weighted average grant-date fair value of RSUs vested during 2012 was 459,274 and $30.02per share, respectively. As of June 30, 2012, 805,038 RSUs were fully vested and an additional 1,311,112 are expected to vest.

Performance Shares: NU had granted performance shares under the annual Long-Term Incentive programs that vested based upon the extent to which the Company achieved targets at the end of three-year performance measurement periods. Performance shares are paid in shares, after the performance measurement period. A summary of performance share transactions is as follows:

	Performance		Weighted Average
	Shares		Grant-Date
Performance Shares	(Units)		Fair Value
Outstanding as of December 31, 2011		483,133	$	29.18
Granted		226,326	$	34.46
Converted to RSUs upon merger		(451,358)	$	34.32
Shares issued		(106,773)	$	24.52
Forfeited		-	$	-
Outstanding as of June 30, 2012		151,328	$	25.04

Upon closing of the merger with NSTAR, 451,358performance shares under the NU 2011 and 2012 Long-TermIncentive Programsconverted to RSUs according to the terms of these programs. The remaining performance shares were measured based upon a modified performance periodthrough the date of the merger in accordance with the terms of the NU 2010 Incentive Program with distribution in 2013.

The total compensation cost recognized by NU, CL&P, NSTAR Electric, PSNH and WMECO for share-based compensation awards was as follows:

NU	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
Compensation Cost Recognized	$	12.8	$	3.0	$	16.4	$	6.1
Associated Future Income Tax Benefit Recognized		5.1		1.2		6.6		2.4

	For the Three Months Ended
	June 30, 2012								June 30, 2011
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric(1)		PSNH		WMECO
Compensation Cost Recognized	$	0.9	$	2.8	$	0.3	$	0.2	$	1.7	$	1.9	$	0.6	$	0.3
Associated Future Income Tax Benefit Recognized		0.4		1.1		0.1		0.1		0.7		0.7		0.2		0.1
	For the Six Months Ended
	June 30, 2012								June 30, 2011
(Millions of Dollars)	CL&P		NSTAR Electric(1)		PSNH		WMECO		CL&P		NSTAR Electric(1)		PSNH		WMECO
Compensation Cost Recognized	$	3.0	$	4.9	$	1.1	$	0.6	$	3.5	$	3.8	$	1.2	$	0.7
Associated Future Income Tax Benefit Recognized		1.2		1.9		0.4		0.3		1.4		1.5		0.5		0.3

• NSTAR Electric amounts are not included in NU consolidated for the three and six months endedJune30, 2011. NSTAR Electric amounts are included in NU consolidated from the date of the merger, April 10, 2012, through June 30, 2012.

As of June 30, 2012, there was $34.9million of total unrecognized compensation cost related to nonvested share-based awards for NU, $6.8million for CL&P, $9.8million for NSTAR Electric, $2.5million for PSNH and $1.5million for WMECO. This cost is expected to be recognized ratably over a weighted-average period of 2.37 years for NU, 2.17 years for CL&P, 2.41years for NSTAR Electric, and 2.15years for PSNH and WMECO.

Stock Options:Awards are available for grant under the NU Incentive Plan and the NSTAR 2007 Long-Term Incentive Plan. Options currently outstanding expire ten years from the date of grant and the fair value of each stock option grant was estimated using the Black-Scholes option pricing model. The weighted average remaining contractual lives for the options outstanding as of June 30, 2012 is 4.7years.A summary of stock option transactions is as follows:

			Exercise Price Per Share
						Weighted		Intrinsic Value
	Options		Range			Average		(Millions)
Outstanding and Exercisable as of December 31, 2011		47,374	$ 18.58	-	$ 18.90	$	18.78
Converted NSTAR Options upon merger		2,664,894	$ 16.47	-	$ 28.12	$	23.99
Exercised		(340,607)				$	23.84	$	4.3
Forfeited and cancelled		-
Outstanding and Exercisable as of June 30, 2012		2,371,661	$ 18.45	-	$ 28.12	$	23.90	$	35.4

Cash received for options exercised during the six months ended June 30, 2012 totaled $8.1million. The tax benefit realized from stock options exercised totaled $1.8million for the six months ended June 30, 2012.

Employee Share Purchase Plan: NU maintains an ESPP for all eligible employees, which allows for NU common shares to be purchased by employees at the end of successive six-month offering periods at 95 percent of the closing market price on the last day of each six-month period. Employees are permitted to purchase shares having a value not exceeding 25 percent of their compensation as of the beginning of the offering period up to a limit of $25,000 per annum. The ESPP qualifies as a non-compensatory plan under accounting guidance for share-based payments, and no compensation expense is recorded for ESPP purchases.

During 2012, employees purchased 20,555 shares at a discounted price of $33.01. Employees purchased 35,476 shares in 2011 at discounted prices of $31.27 and $32.30. As of June 30, 2012 and December 31, 2011, 876,147and 896,702 shares, respectively, remained available for future issuance under the ESPP.

An income tax rate of 40 percent is used to estimate the tax effect on total share-based payments determined under the fair value-based method for all awards. The Company generally settles stock option exercises and fully vested RSUs and performance shares with the issuance of new common shares.

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Environmental Matters (Details) (USD $)	6 Months Ended	12 Months Ended
	Jun. 30, 2012	Dec. 31, 2011
Site Contingency [Line Items]
Environmental Site Quantity	83	59
Site Contingency [Abstract]
HWP Reserve Amount	$ 2,200,000
Cumulative Payments Environmental Loss Contingencies	17,300,000
Cumulative Environmental Remediation Expense	19.5
Accrual For Environmental Loss Contingencies	41,800,000	31,700,000
MGP Site accrual [Member]
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	37,400,000	28,900,000
The Connecticut Light And Power Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	19	18
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	3,200,000	2,900,000
The Connecticut Light And Power Company [Member] | MGP Site accrual [Member]
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	1,500,000	1,500,000
Public Service Company Of New Hampshire [Member]
Site Contingency [Line Items]
Environmental Site Quantity	19	18
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	6,500,000	6,600,000
Public Service Company Of New Hampshire [Member] | MGP Site accrual [Member]
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	5,500,000	5,800,000
Western Massachusetts Electric Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	10	10
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	300,000	300,000
Western Massachusetts Electric Company [Member] | MGP Site accrual [Member]
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	100,000	100,000
NSTAR Electric Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	13	13
Site Contingency [Abstract]
Accrual For Environmental Loss Contingencies	$ 1,400,000	$ 1,300,000

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LONG-TERM DEBT

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Long-term Debt [Text Block]

8.       LONG-TERM DEBT (NU, CL&P)

On March 22, 2012, NU parent issued $300 million of floating rate Series D Senior Notes with a maturity date of September 20, 2013. The notes have a coupon rate based on the three-month LIBOR rate plus a credit spread of 0.75 percent and will reset quarterly. The notes had an interest rate of 1.22 percent as of June 30, 2012. The proceeds, net of issuance expenses, were used to repay at maturity the NU parent $263 million Series A Senior Notes that matured on April 1, 2012, to repay short-term borrowings outstanding under the NU parent Credit Agreement and for other general corporate purposes. The indenture under which the bonds were issued requires NU to comply with certain covenants as are customarily included in such indentures.

On April 2, 2012, CL&P remarketed $62 million of tax-exempt PCRBs for a three-year period. The PCRBs, which mature on May 1, 2031, carry a coupon rate of 1.55 percent during the current three-year fixed rate period and are subject to mandatory tender for purchase on April 1, 2015.

On April 2, 2012, NU parent repaid its $263 million 7.25 percent Series A Senior Notes that matured on April1, 2012 with the proceeds from the issuance of floating rate Series D Senior Notes issued on March22, 2012.

In addition, as a result of consolidating CYAPC and YAEC, NU has consolidated $179 million in additional spent nuclear fuel obligations. The spent nuclear fuel obligation is payable to the DOE at any time prior to the first delivery to the DOE of spent nuclear fuel and radio-active waste used to generate electricity prior to April 7, 1983. Until payment is made to the DOE, the outstanding liability will continue to accrue interest at the 3-month Treasury bill yield rate.

NU, including CL&P, NSTAR Electric, PSNH and WMECO, was in compliance with all its debt covenants as of June 30, 2012.

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PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

9.EMPLOYEE BENEFITS

• Pension Benefits and Postretirement Benefits Other Than Pensions

NUSCO sponsors a Pension Plan that covers nonbargaining unit employees (and bargaining unit employees, as negotiated), including CL&P, PSNH, and WMECO employees, hired before 2006 (or as negotiated, for bargaining unit employees) andNSTAR Electricserves as plan sponsor for a defined benefit retirement plan that covers substantially all employees of NSTAR Electric & Gas, which is a Northeast Utilities service company. Both plans are subject to the provisions of ERISA, as amended by the PPA of 2006. NU and NSTAR Electric & Gas each maintain SERPs and other non-qualified defined benefit plans, which provide benefits in excess of Internal Revenue Code limitations to eligible current and retired participants that would have otherwise been provided under the Pension Plans. Amounts related to these plans are included with the Pension Plans in the tables below.

NUSCO and NSTAR Electric & Gas also sponsor plans that provide certain retiree health care benefits, primarily medical and dental, and life insurance benefits through PBOP Plans and Group Welfare Benefit Plans to employees that meet certain age and service eligibility requirements. Under certain circumstances, eligible retirees are required to contribute to the costs of postretirement benefits.

The funded status of each of the plans is recorded on the respective sponsor's balance sheet: NUSCO (NUSCO pension, NUSCO PBOP and NUSCO SERP), NSTAR Electric (NSTAR pension) and NSTAR Electric & Gas (NSTAR SERP and PBOP). The NUSCO plans are accounted for under the multiple-employer approach, and therefore, the funded status of the NUSCO plans is allocated to and recorded on the balance sheets of CL&P, PSNH and WMECO. The NSTAR plans were accounted for under the multi-employer approach prior to the merger and NU continues to account for these plans under the multi-employer approach. Under multi-employer accounting, the funded status is recorded on the plan sponsor's balance sheet and other subsidiaries that participate in the plan record any unpaid contributions to the plan on their respective balance sheets. Accordingly, the balance sheet of NSTAR Electric reflects the full funded status of the NSTAR ElectricPension Plan and does not reflect the funded status of the NSTAR PBOP or SERP plans.

The components of net periodic benefit expense for the Pension Plans (including the SERPs) and PBOP Plans, the portion of pension amounts capitalized relating to employees working on capital projects, andintercompany allocations not included in the net periodic benefit expense are as follows

	Pension and SERP Plans
	For the Three Months Ended				For the Six Months Ended
	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)	NU		NU		NU		NU
Service Cost	$	22.8	$	14.0	$	38.1	$	27.7
Interest Cost		53.2		38.3		91.3		76.5
Expected Return on Plan Assets		(59.4)		(42.2)		(101.9)		(85.3)
Actuarial Loss		47.4		21.1		77.4		42.1
Prior Service Cost		2.0		2.4		4.1		4.8
Total - Net Periodic Benefit Expense	$	66.0	$	33.6	$	109.0	$	65.8
Capitalized Pension Expense	$	19.7	$	8.0	$	30.3	$	15.7
	PBOP Plans and Group Welfare Benefit Plans
	For the Three Months Ended				For the Six Months Ended
	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)	NU		NU		NU		NU
Service Cost	$	4.5	$	2.1	$	6.8	$	4.5
Interest Cost		13.9		6.5		20.1		12.9
Expected Return on Plan Assets		(11.3)		(5.4)		(17.0)		(10.8)
Actuarial Loss		9.7		5.0		15.2		9.5
Prior Service Credit		(0.4)		-		(0.4)		(0.1)
Net Transition Obligation Cost		3.1		2.9		5.9		5.8
Total - Net Periodic Benefit Expense	$	19.5	$	11.1	$	30.6	$	21.8

		Pension and SERP Plans
		For the Three Months Ended June 30, 2012								For the Three Months Ended June 30, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric(1)		PSNH		WMECO		CL&P		Electric(1), (2)		PSNH		WMECO
Service Cost		$	5.4	$	7.3	$	2.9	$	1.1	$	4.9	$	6.1	$	2.7	$	1.0
Interest Cost			12.9		14.7		6.1		2.6		13.0		15.3		6.1		2.7
Expected Return on Plan Assets			(17.7)		(16.3)		(7.2)		(4.1)		(19.1)		(18.4)		(4.7)		(4.4)
Actuarial Loss			12.6		15.9		4.1		2.7		8.2		12.5		2.6		1.7
Prior Service Cost/(Credit)			0.9		(0.1)		0.4		0.2		1.0		(0.2)		0.5		0.2
Total - Net Periodic Benefit Expense		$	14.1	$	21.5	$	6.3	$	2.5	$	8.0	$	15.3	$	7.2	$	1.2
Related Intercompany
	Allocations	$	10.7	$	(3.0)	$	2.4	$	2.0	$	8.7	$	(2.0)	$	1.9	$	1.6
Capitalized Pension Expense		$	6.8	$	8.9	$	1.9	$	1.2	$	4.4	$	4.9	$	2.0	$	2.7
		Pension and SERP Plans
		For the Six Months Ended June 30, 2012								For the Six Months Ended June 30, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric(1), (2)		PSNH		WMECO		CL&P		Electric(1), (2)		PSNH		WMECO
Service Cost		$	10.9	$	15.1	$	5.8	$	2.1	$	9.7	$	13.0	$	5.3	$	2.0
Interest Cost			25.6		29.5		12.2		5.3		26.1		30.5		12.3		5.4
Expected Return on Plan Assets			(35.2)		(32.8)		(13.9)		(8.2)		(38.3)		(35.7)		(10.0)		(8.8)
Actuarial Loss			24.5		31.6		8.0		5.2		16.6		24.3		5.2		3.4
Prior Service Cost/(Credit)			1.8		(0.3)		0.8		0.4		2.0		(0.4)		1.0		0.4
Total - Net Periodic Benefit Expense		$	27.6	$	43.1	$	12.9	$	4.8	$	16.1	$	31.7	$	13.8	$	2.4
Related Intercompany
	Allocations	$	21.3	$	(6.2)	$	5.0	$	4.0	$	16.5	$	(4.5)	$	3.8	$	3.0
Capitalized Pension Expense		$	13.4	$	15.2	$	3.9	$	2.4	$	8.9	$	9.9	$	3.9	$	1.4

		PBOP Plans
		For the Three Months Ended June 30, 2012						For the Three Months Ended June 30, 2011
(Millions of Dollars)		CL&P			PSNH		WMECO	CL&P		PSNH		WMECO
Service Cost		$	0.7	$	0.5	$	0.1	$	0.7	$	0.5	$	0.2
Interest Cost			2.3		1.1		0.5		2.5		1.2		0.5
Expected Return on Plan Assets			(2.3)		(1.1)		(0.5)		(2.1)		(1.1)		(0.5)
Actuarial Loss			1.8		0.8		0.3		1.9		0.9		0.3
Net Transition Obligation Cost			1.5		0.6		0.3		1.5		0.6		0.3
Total - Net Periodic Benefits Expense		$	4.0	$	1.9	$	0.7	$	4.5	$	2.1	$	0.8
Related Intercompany
	Allocations	$	1.9	$	0.5	$	0.4	$	2.0	$	0.5	$	0.9
		PBOP Plans
		For the Six Months Ended June 30, 2012						For the Six Months Ended June 30, 2011
(Millions of Dollars)		CL&P		PSNH		WMECO		CL&P		PSNH		WMECO
Service Cost		$	1.4	$	1.0	$	0.3	$	1.4	$	1.0	$	0.3
Interest Cost			4.6		2.3		1.0		5.0		2.4		1.1
Expected Return on Plan Assets			(4.5)		(2.3)		(1.1)		(4.3)		(2.2)		(1.0)
Actuarial Loss			3.8		1.8		0.6		3.6		1.6		0.6
Net Transition Obligation Cost			3.0		1.2		0.7		3.1		1.2		0.6
Total - Net Periodic Benefits Expense		$	8.3	$	4.0	$	1.5	$	8.8	$	4.0	$	1.6
Related Intercompany
	Allocations	$	4.1	$	1.0	$	0.8	$	4.1	$	1.0	$	1.7

• NSTAR Electric's pension amounts do not include SERP expense.
• NSTAR Electric's pension expense for the six months ended June 30, 2012 included $21.6 million of costs incurred prior to the closing of NSTAR's merger with NU. These amounts are not included in NU's net periodic benefit costs for the six months ended June 30, 2012. The NSTAR Electric expenses are not included in the consolidated NU results for the three and six months ended June 30, 2011.

NSTAR Electric PBOP Expense: NSTAR Electric participates in a PBOP Plan sponsored by NSTAR Electric& Gas. NSTAR Electric recognizes unpaid contributions that are due to NSTAR Electric & Gas as a liability on the accompanying unaudited condensed consolidated balance sheets. The funded status of the PBOP plan is reflected on NU's accompanying unaudited condensed consolidated balance sheet. However, the funded status of the PBOP plan is not reflected on NSTAR Electric's accompanying unaudited condensed consolidated balance sheets.For the three and six months ended June 30, 2012, the net periodic postretirement benefits costs allocated to NSTAR Electric were $8 million and$17 million, respectively, of which $9 million was incurred prior to the closing of NSTAR's merger with NU. These amounts were $5.1 million and $12.8 million for the three and six months ended June 30, 2011, respectively. These amounts are fully recovered from customers in cost-of-service regulated rates.

Curtailment Expense (SERP): NU recorded curtailment expense of $1.8million for the NUSCO SERP in the second quarter of 2012 to reflect charges related to organization changes that occurred as a result of the merger.

Contributions:NU's policy is to annually fund the Pension Plans sponsored by NUSCO and NSTAR Electric in an amount at least equal to an amount that will satisfy the requirements of ERISA, as amended by the PPA of 2006, and the Internal Revenue Code. Based on the current status of the NUSCO Pension Plan, NU is required to make a contribution to the NUSCO Pension Plan of approximately $197.3 million in 2012 to meet minimum funding requirements under the PPA. Contributions are being made in installments and began in January 2012. NU made contributions totaling $35.1 million and $127.1 million($87.7 million of which was contributed by PSNH in the first quarter of 2012) for the three and six months ended June 30, 2012, respectively. NSTAR Electric currently anticipates making contributions to the NSTAR Electric PensionPlan of approximately $25 million in 2012, of which $6.3million was contributed in the second quarter of 2012.NSTAR Electric did not contribute to the Plan in the first quarter of 2012. The actual level of funding may differ from this estimate.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Commitments and Contingencies Disclosure [Text Block]

10.       COMMITMENTS AND CONTINGENCIES

A.       Environmental Matters

General: NU, CL&P, NSTAR Electric, PSNH and WMECO are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. NU, CL&P, NSTAR Electric, PSNH and WMECO have an active environmental auditing and training program and believe that they are substantially in compliance with all enacted laws and regulations.

The number of environmental sites and reserves related to these sites for which remediation or long-term monitoring, preliminary site work or site assessment are being performed, as well as the portion related to MGP sites are as follows:

	As of June 30, 2012						As of December 31, 2011
					Portion Related to						Portion Related to
			Reserve		MGP Sites				Reserve		MGP Sites
	Number of Sites		(in millions)		(in millions)		Number of Sites		(in millions)		(in millions)
NU		83	$	41.8	$	37.4		59	$	31.7	$	28.9
CL&P		19		3.2		1.5		18		2.9		1.5
NSTAR Electric(1)		13		1.4		-		13		1.3		-
PSNH		19		6.5		5.5		18		6.6		5.8
WMECO		10		0.3		0.1		10		0.3		0.1

(1)The NSTAR Electric balance is not included in the NU consolidated balance as of December 31, 2011.

MGP sites were operated several decades ago and manufactured gas from coal, which resulted in certain byproducts in the environment that may pose a risk to human health and the environment.

HWP: HWP, a subsidiary of NU, continues to investigate the potential need for additional remediation at a river site in Massachusetts containing tar deposits associated with an MGP site that HWP sold to HG&E, a municipal utility, in 1902. HWP shares responsibility for site remediation with HG&E and has conducted substantial investigative and remediation activities. The cumulative expense recorded to the reserve for this site since 1994 through June 30, 2012 was $19.5 million, of which $17.3 million had been spent, leaving $2.2million in the reserve as of June 30, 2012. There were no charges to the reserve for the three or six months ended June 30, 2012 or 2011. HWP's share of the costs related to this site is not recoverable from customers.

The $2.2 million reserve balance as of June 30, 2012 represents estimated costs that HWP considers probable over the remaining life of the project, including testing and related costs in the near term and field activities to be agreed upon with the MA DEP, further studies and long-term monitoring that are expected to be required by the MA DEP, and certain soft tar remediation activities. Various factors could affect management's estimates and require an increase to the reserve, which would be reflected as a charge to Net Income. Although a material increase to the reserve is not presently anticipated, management cannot reasonably estimate potential additional investigation or remediation costs because these costs would depend on, among other things, the nature, extent and timing of additional investigation and remediation that may be required by the MA DEP.

B.       Long-Term Contractual Arrangements

For information regarding long-term contractual obligations as of December 31, 2011, see Note 12B, "Commitments and Contingencies – Long-Term Contractual Arrangements," of the NU2011 Form 10-K, Note P, "Commitments and Contingencies," of the NSTAR 2011 Form 10-K and Note K, "Commitments and Contingencies," of the NSTAR Electric 2011 Form 10-K.

Estimated Future Annual Costs:As a result of the merger, the NU estimated future annual costs of significant long-term contractual arrangements as of June 30, 2012now incorporate commitments for NSTARLLC and its subsidiaries, which are as follows:

	July - December
(Millions of Dollars)	2012		2013		2014		2015		2016		Thereafter		Totals
Supply/Stranded Cost Contracts/Obligations	$	16.3	$	28.7	$	33.0	$	32.9	$	12.6	$	7.1	$	130.6
Renewable Energy Supply Contracts		33.7		87.3		86.6		87.9		52.1		252.8		600.4
Transmission Support Commitments		1.9		3.7		3.6		3.5		0.0		0.0		12.7
Natural Gas Procurement Contracts		108.5		54.0		47.5		24.7		21.6		78.5		334.8
Future Minimum Operating Lease Payments		6.4		11.5		8.4		7.3		5.7		12.2		51.5
Electric Interconnection Agreement		1.7		3.4		3.4		3.4		3.3		41.1		56.3
Totals	$	168.5	$	188.6	$	182.5	$	159.7	$	95.3	$	391.7	$	1,186.3

Merger-Related Commitments: The preceding table does not include the commitments made in connection with the Connecticut and Massachusetts settlement agreements, including NSTAR Electric's commitment to enter into a 15-year agreement to purchase 129MW of renewable energy from a wind facility to be constructed off the shores of Cape Cod, Massachusetts.

C.       Deferred Contractual Obligations

CL&P, NSTAR Electric, PSNH and WMECO have decommissioning and plant closure cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies collect decommissioning and closure costs through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric, PSNH and WMECO. These companies in turn recover these costs from their customers through state regulatory commission-approved retail rates.

CL&P, NSTAR Electric, PSNH and WMECO's percentage share of the obligations to support the Yankee Companies under FERC-approved rate tariffs is the same as their respective ownership percentages in the Yankee Companies.

The Yankee Companies are currently collecting amounts that management believes are adequate to recover the remaining decommissioning and closure cost estimates for the respective plants. Management believes CL&P, NSTAR Electric and WMECO will recover their shares of these decommissioning and closure obligations from their customers. PSNH has already recovered its share of these costs from its customers.

Spent Nuclear Fuel Litigation:

DOE Phase I Damages - In 1998, CYAPC, YAEC and MYAPC (Yankee Companies) filed separate complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal by January 31, 1998 pursuant to the terms of the 1983 spent fuel and high level waste disposal contracts between the Yankee Companies and the DOE (DOE Phase I Damages). In a ruling released on October 4, 2006, the Court of Federal Claims held that the DOE was liable for damages to CYAPC for $34.2 million through 2001, YAEC for $32.9 million through 2001 and MYAPC for $75.8 million through 2002.

In December 2006, the DOE appealed the ruling, and the Yankee Companies filed cross-appeals. The Court of Appeals issued its decision on August 7, 2008, effectively agreeing with the trial court's findings as to the liability of the DOE but disagreeing with the method that the trial court used to calculate damages. The Court of Appeals vacated the decision and remanded the case for new findings consistent with its decision.

On September 7, 2010, the trial court issued its decision following remand, and judgment on the decision was entered on September 9, 2010. The judgment awarded CYAPC $39.7 million, YAEC $21.2 million and MYAPC $81.7 million. The DOE filed an appeal and the Yankee Companies cross-appealed on November 8, 2010. Briefs were filed and oral arguments in the appeal of the remanded case occurred on November 7, 2011. On May 18, 2012, the U.S. Court of Appeals for the Federal Circuit issued a unanimous panel decision in favor of the Yankee Companies upholding the trial court's awards to each company in the remanded cases, and increasing YAEC damages by approximately $17 million to cover certain wet pool operating expenses. The DOE had 45 days (or until July2, 2012) to request reconsideration of the decision or file a request for additional time, and 90 days to file a petition for certiorari to the U.S. Supreme Court. The DOE has filed for an extension of time, and motions are pending to argue the matter; accordingly, the 90 day period for filing of a petition for certiorari to the U.S. Supreme Court has not yet begun. Interest on the judgments does not start to accrue until all appeals have been decided and/or all appeal periods have expired without appeals being filed.  The application of any damages, which are ultimately recovered to benefit customers, is established in the Yankee Companies' FERC-approved rate settlement agreements, although implementation will be subject to the final determination of the FERC.

DOE Phase II Damages -In December 2007, the Yankee Companies also filed subsequent lawsuits against the DOE seeking recovery of additional damages incurred in the years following 2001 and 2002 related to the alleged failure of the DOE to provide for a permanent facility to store spent nuclear fuel generated in years after 2001 for CYAPC and YAEC and after 2002 for MYAPC (DOE Phase II Damages). On November 18, 2011, the court ordered the record closed in the YAEC case, and closed the record in the CYAPC and MYAPC cases subject to a limited opportunity of the DOE to reopen the records for further limited proceedings. The record is now closed, all post-trial briefing has been completed, and the case is awaiting the court decision.

The refund to CL&P, NSTAR Electric, PSNH and WMECO of any damages that may be recovered from the DOE will be realized through the Yankee Companies' FERC-approved rate settlement agreements, subject to final determination of the FERC. CL&P, NSTAR Electric, PSNH and WMECO cannot at this time determine the timing or amount of any ultimate recovery the Yankee Companies may obtain from the DOE on this matter. However, NU believes that any net settlement proceeds it receives would be incorporated into FERC-approved recoveries, which would be passed on to its customers through reduced charges.

D.       Guarantees and Indemnifications

NU parent, or NSTAR LLC, as applicable, provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, in the form of guarantees and LOCs in the normal course of business.

NU provided guarantees and various indemnifications on behalf of external parties as a result of the sales of former subsidiaries of NU Enterprises, with maximum exposures either not specified or not material.

NU also issued a guaranty for the benefit of Hydro Renewable Energy under which, beginning at the time the Northern Pass Transmission line goes into commercial operation, NU will guarantee the financial obligations of NPT under the TSA in an amount not to exceed $25million. NU's obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations.

Management does not anticipate a material impact to Net Income to result from these various guarantees and indemnifications.

The following table summarizes NU's guarantees of its subsidiaries, including CL&P, NSTAR Electric, PSNH, and WMECO, as of June 30, 2012:

		Maximum
		Exposure
Subsidiary	Description	(in millions)			Expiration Dates
Various	Surety Bonds	$	35.0		July 2012 - Nov 2015 (1)
Various	Letters of Credit	$	19.5		Oct 2012 - Dec 2012
Various	NE Hydro Companies' Long-Term Debt	$	6.6		Unspecified
NUSCO and RRR	Lease Payments for Vehicles and Real Estate	$	21.9		2019 and 2024
NU Enterprises	Surety Bonds, Insurance Bonds and Performance Guarantees	$	109.4	(2)	(2)

(1)       Surety bond expiration dates reflect bond termination dates, the majority of which will be renewed or extended.

(2)       The maximum exposure includes $45.4million related to performance guarantees on wholesale purchase contracts, which expire in 2013. The maximum exposure also includes $14million related to a performance guarantee for which no maximum exposure is specified in the agreement. The maximum exposure was calculated as of June 30, 2012based on limits of the liability contained in the underlying service contract and assumes that NU Enterprises will perform under that contract through its expiration in 2020. Also included in the maximum exposure is $1.2million related to insurance bonds with no expiration date that are billed annually on their anniversary date. The remaining $48.8million of maximum exposure relates to surety bonds covering ongoing projects, which expire upon project completion.

Many of the underlying contracts that NU parent guarantees, as well as certain surety bonds, contain credit ratings triggers that would require NU parent to post collateral in the event that the unsecured debt credit ratings of NU, or NSTAR LLC, as applicable, are downgraded below investment grade.

E.       Exposure Regarding Complaint on FERC Base ROE

On September 30, 2011, several New England state attorneys general, state regulatory commissions, consumer advocates and other parties filed a joint complaint with the FERC under Sections 206 and 306 of the Federal Power Act alleging that the base ROE used in calculating formula rates for transmission service under the ISO-NE Open Access Transmission Tariff by New England transmission owners, including CL&P, NSTAR Electric, PSNH and WMECO, is unjust and unreasonable. The complainants asserted that the current 11.14 percent rate, which became effective in 2006, is excessive due to changes in the capital markets and are seeking an order to reduce the rate to 9.2 percent, effective September 30, 2011. In response, the New England transmission owners filed testimony and analysis based on standard FERC methodology and precedent justifying a base ROE of approximately 11.2 percent, thus demonstrating that the base ROE of 11.14 percent remained just and reasonable.

On May 3, 2012, the FERC issued an order establishing hearing and settlement procedures for the complaint. On August 1, 2012, the settlement judge recommended that FERC terminate the settlement proceedings, as the parties had reached an impasse in their efforts to reach a settlement.The FERC expects to render a final decision in the third quarter of 2013 with changes, if any, effective October 1, 2011. Management cannot at this time predict what ROE will ultimately be established or its impact on CL&P's, NSTAR Electric's, PSNH's, or WMECO's respective financial position, results of operations or cash flows.

F.       DPU Safety and Reliability Programs - CPSL (NSTAR Electric)

NSTAR Electric recovers incremental costs related to the Double Pole Inspection Program, Replacement/Restoration and Transfer Program and the Underground Electric Safety Program, which includes stray-voltage remediation, manhole inspections, repairs, and upgrades, in accordance with this DPU approved program. Recovery of these CPSL costs is subject to review and approval by the DPU through a rate-reconciling mechanism. From 2006 through June 2012, cumulative costs associated with the CPSL program have resulted in an incremental revenue requirement to customers of approximately $90 million. These amounts include incremental operations and maintenance costs and the related revenue requirement for specific capital investment relative to the CPSL programs.

On May 28, 2010, the DPU issued an order on NSTAR Electric's 2006 CPSL cost recovery filing (the May 2010 Order). The May 2010 Order is the basis that NSTAR Electric uses for recognizing revenue for the CPSL programs. On October 8, 2010, NSTAR Electric submitted a Compliance Filing with the DPU reconciling the cumulative CPSL program activity for the periods 2006 through 2009 in order to determine a proposed rate adjustment effective on January 1, 2011. The DPU allowed the proposed rates for the CPSL programs to go into effect on that date, subject to final reconciliation of CPSL program costs through a future DPU proceeding.

NSTAR Electric cannot predict the timing of any subsequent DPU order related to its CPSL filings for the period 2006 through 2009, or any period thereafter. Therefore, NSTAR Electric continues to record its revenues under the CPSL programs based on the May 2010 Order. Should any subsequent DPU order be different than the conclusion of the May 2010 Order, it could have a material impact on NSTAR Electric's results of operations, financial position and cash flows.

The comprehensive settlement agreement with the Massachusetts Attorney General stipulates a revenue requirement of up to $15 million per annum for 2012 through 2015 in order to continue these programs. CPSL revenues will end once NSTAR Electric has recovered its 2015-related CPSL costs. Realization of these revenues is subject to maintaining certain performance metrics and DPU approval.

G.       Basic Service Bad Debt Adder (NSTAR Electric)

On July 1, 2005, in response to a generic DPU order that required electric utilities in Massachusetts to recover the energy-related portion of bad debt costs in their Basic Service rates, NSTAR Electric increased its Basic Service rates and reduced its distribution rates for those bad debt costs. In furtherance of this generic DPU order, NSTAR Electric included a bad debt cost recovery mechanism as a component of its 2005 Rate Settlement Agreement. This recovery mechanism (bad debt adder) allows NSTAR Electric to recover its Basic Service bad debt costs on a fully reconciling basis. These rates were implemented, effective January 1, 2006, as part of the 2005 Rate Settlement Agreement.

On February 7, 2007, NSTAR Electric filed its 2006 Basic Service reconciliation with the DPU proposing an adjustment related to the increase of its Basic Service bad debt charge-offs. This proposed rate adjustment was anticipated to be implemented effective July 1, 2007. On June 28, 2007, the DPU issued an order approving the implementation of a revised Basic Service rate. However, the DPU instructed NSTAR Electric to reduce distribution rates by an amount equal to the increase in its Basic Service bad debt charge-offs. Such action would result in a further reduction to distribution rates from the adjustment NSTAR Electric made when it implemented the Settlement Agreement. This adjustment to NSTAR Electric's distribution rates would eliminate the fully reconciling nature of the Basic Service bad debt adder.

NSTAR Electric continued to defer the costs associated with these amounts as a regulatory asset, which totaled approximately $34 million as of December 31, 2011, as NSTAR Electric had concluded that these costs were probable of recovery in future rates. On June 18, 2010, NSTAR Electric filed an appeal of the DPU's order with the SJC, which was heard by the SJC in December 2011. On April 11, 2012, the SJC issued a procedural order waiving its standing 130-day rule for issuance of an order on the matter. This delay by the SJC caused NSTAR Electric to reassess its position as to the outcome. Due to the delay, NSTAR Electric concluded that while an ultimate outcome on the matter in its favor remained "more likely than not", it could no longer be deemed "probable". As a result, as of March 31, 2012, NSTAR Electric recognized a reserve of $28 million ($17 million after-tax) as a charge to Operations and Maintenance in the first quarter of 2012 to fully reserve the related regulatory asset on its balance sheet.

On June 4, 2012, the SJC vacated the DPU's June 28, 2007 order and remanded the matter to the DPU for a "statement of reasons, including subsidiary findings, of its conclusion of law and relevant facts." The continued uncertainty of the outcome of the DPU's preceding leaves NU and NSTAR Electric unable to conclude if the previously reserved amount is probable of recovery and therefore will continue to maintain a reserve on this amount until the ultimate outcome is determined by the DPU.

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Basic Service Bad Debt Adder (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2012
Notes To Consolidated Financial Statements [Abstract]
Deferred Costs Associated With Bad Debt Adder At Nstar Electric	$ 34.0
Before Tax Reserve For Bad Debt Service Adder	28.0
After Tax Bad Debt Service Adder Reserve	$ 17.0

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $)	Jun. 30, 2012	Dec. 31, 2011
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	$ 155,568,000	$ 116,200,000
Rate Reduction Bonds	160,133,000	112,260,000
Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	155,600,000	116,200,000
Rate Reduction Bonds	160,100,000	112,300,000
Other Long Term Debt	7,619,700,000	4,950,700,000
Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	153,100,000	105,100,000
Rate Reduction Bonds	163,600,000	116,800,000
Other Long Term Debt	8,302,700,000	5,517,000,000
The Connecticut Light And Power Company [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	116,200,000	116,200,000
The Connecticut Light And Power Company [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	116,200,000	116,200,000
Other Long Term Debt	2,584,000,000	2,587,800,000
The Connecticut Light And Power Company [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	110,100,000	105,100,000
Other Long Term Debt	3,029,300,000	2,987,100,000
Public Service Company Of New Hampshire [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Rate Reduction Bonds	57,742,000	85,368,000
Public Service Company Of New Hampshire [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Rate Reduction Bonds	57,700,000	85,400,000
Other Long Term Debt	997,800,000	999,500,000
Public Service Company Of New Hampshire [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Rate Reduction Bonds	59,200,000	88,800,000
Other Long Term Debt	1,089,000,000	1,075,200,000
Western Massachusetts Electric Company [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Rate Reduction Bonds	18,079,000	26,892,000
Western Massachusetts Electric Company [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Rate Reduction Bonds	18,100,000	26,900,000
Other Long Term Debt	499,600,000	501,100,000
Western Massachusetts Electric Company [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Rate Reduction Bonds	18,600,000	28,100,000
Other Long Term Debt	550,100,000	539,800,000
NSTAR Electric Company [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	43,000,000	43,000,000
Rate Reduction Bonds	84,312,000	127,860,000
NSTAR Electric Company [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	43,000,000	43,000,000
Rate Reduction Bonds	84,300,000	127,900,000
Other Long Term Debt	1,603,400,000	1,605,100,000
NSTAR Electric Company [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [ Line Items]
Preferred Stock Not Subject to Mandatory Redemption	43,000,000	41,200,000
Rate Reduction Bonds	85,800,000	131,200,000
Other Long Term Debt	$ 1,842,000,000	$ 1,816,100,000

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Deferred Contractual Obligations (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2012
Notes To Consolidated Financial Statements [Abstract]
Court Of Federal Claims Ruling To CYAPC	$ 34.2
Court Of Federal Claims Ruling To YAEC	32.9
Court Of Federal Claims Ruling MYAPC	75.8
Trial Court Ruling To CYAPC	39.7
Trial Court Ruling To YAEC	21.2
Trial Court Ruling To MYAPC	81.7
Court Of Federal Appeals Ruling Increase To YAEC Damages	$ 17.0

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Pension Benefits and Postretirement Benefits Other Than Pensions (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Net Benefit Costs [Table Text Block]

	Pension and SERP Plans
	For the Three Months Ended				For the Six Months Ended
	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)	NU		NU		NU		NU
Service Cost	$	22.8	$	14.0	$	38.1	$	27.7
Interest Cost		53.2		38.3		91.3		76.5
Expected Return on Plan Assets		(59.4)		(42.2)		(101.9)		(85.3)
Actuarial Loss		47.4		21.1		77.4		42.1
Prior Service Cost		2.0		2.4		4.1		4.8
Total - Net Periodic Benefit Expense	$	66.0	$	33.6	$	109.0	$	65.8
Capitalized Pension Expense	$	19.7	$	8.0	$	30.3	$	15.7
	PBOP Plans and Group Welfare Benefit Plans
	For the Three Months Ended				For the Six Months Ended
	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
(Millions of Dollars)	NU		NU		NU		NU
Service Cost	$	4.5	$	2.1	$	6.8	$	4.5
Interest Cost		13.9		6.5		20.1		12.9
Expected Return on Plan Assets		(11.3)		(5.4)		(17.0)		(10.8)
Actuarial Loss		9.7		5.0		15.2		9.5
Prior Service Credit		(0.4)		-		(0.4)		(0.1)
Net Transition Obligation Cost		3.1		2.9		5.9		5.8
Total - Net Periodic Benefit Expense	$	19.5	$	11.1	$	30.6	$	21.8

		Pension and SERP Plans
		For the Three Months Ended June 30, 2012								For the Three Months Ended June 30, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric(1)		PSNH		WMECO		CL&P		Electric(1), (2)		PSNH		WMECO
Service Cost		$	5.4	$	7.3	$	2.9	$	1.1	$	4.9	$	6.1	$	2.7	$	1.0
Interest Cost			12.9		14.7		6.1		2.6		13.0		15.3		6.1		2.7
Expected Return on Plan Assets			(17.7)		(16.3)		(7.2)		(4.1)		(19.1)		(18.4)		(4.7)		(4.4)
Actuarial Loss			12.6		15.9		4.1		2.7		8.2		12.5		2.6		1.7
Prior Service Cost/(Credit)			0.9		(0.1)		0.4		0.2		1.0		(0.2)		0.5		0.2
Total - Net Periodic Benefit Expense		$	14.1	$	21.5	$	6.3	$	2.5	$	8.0	$	15.3	$	7.2	$	1.2
Related Intercompany
	Allocations	$	10.7	$	(3.0)	$	2.4	$	2.0	$	8.7	$	(2.0)	$	1.9	$	1.6
Capitalized Pension Expense		$	6.8	$	8.9	$	1.9	$	1.2	$	4.4	$	4.9	$	2.0	$	2.7
		Pension and SERP Plans
		For the Six Months Ended June 30, 2012								For the Six Months Ended June 30, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric(1), (2)		PSNH		WMECO		CL&P		Electric(1), (2)		PSNH		WMECO
Service Cost		$	10.9	$	15.1	$	5.8	$	2.1	$	9.7	$	13.0	$	5.3	$	2.0
Interest Cost			25.6		29.5		12.2		5.3		26.1		30.5		12.3		5.4
Expected Return on Plan Assets			(35.2)		(32.8)		(13.9)		(8.2)		(38.3)		(35.7)		(10.0)		(8.8)
Actuarial Loss			24.5		31.6		8.0		5.2		16.6		24.3		5.2		3.4
Prior Service Cost/(Credit)			1.8		(0.3)		0.8		0.4		2.0		(0.4)		1.0		0.4
Total - Net Periodic Benefit Expense		$	27.6	$	43.1	$	12.9	$	4.8	$	16.1	$	31.7	$	13.8	$	2.4
Related Intercompany
	Allocations	$	21.3	$	(6.2)	$	5.0	$	4.0	$	16.5	$	(4.5)	$	3.8	$	3.0
Capitalized Pension Expense		$	13.4	$	15.2	$	3.9	$	2.4	$	8.9	$	9.9	$	3.9	$	1.4

		PBOP Plans
		For the Three Months Ended June 30, 2012						For the Three Months Ended June 30, 2011
(Millions of Dollars)		CL&P			PSNH		WMECO	CL&P		PSNH		WMECO
Service Cost		$	0.7	$	0.5	$	0.1	$	0.7	$	0.5	$	0.2
Interest Cost			2.3		1.1		0.5		2.5		1.2		0.5
Expected Return on Plan Assets			(2.3)		(1.1)		(0.5)		(2.1)		(1.1)		(0.5)
Actuarial Loss			1.8		0.8		0.3		1.9		0.9		0.3
Net Transition Obligation Cost			1.5		0.6		0.3		1.5		0.6		0.3
Total - Net Periodic Benefits Expense		$	4.0	$	1.9	$	0.7	$	4.5	$	2.1	$	0.8
Related Intercompany
	Allocations	$	1.9	$	0.5	$	0.4	$	2.0	$	0.5	$	0.9
		PBOP Plans
		For the Six Months Ended June 30, 2012						For the Six Months Ended June 30, 2011
(Millions of Dollars)		CL&P		PSNH		WMECO		CL&P		PSNH		WMECO
Service Cost		$	1.4	$	1.0	$	0.3	$	1.4	$	1.0	$	0.3
Interest Cost			4.6		2.3		1.0		5.0		2.4		1.1
Expected Return on Plan Assets			(4.5)		(2.3)		(1.1)		(4.3)		(2.2)		(1.0)
Actuarial Loss			3.8		1.8		0.6		3.6		1.6		0.6
Net Transition Obligation Cost			3.0		1.2		0.7		3.1		1.2		0.6
Total - Net Periodic Benefits Expense		$	8.3	$	4.0	$	1.5	$	8.8	$	4.0	$	1.6
Related Intercompany
	Allocations	$	4.1	$	1.0	$	0.8	$	4.1	$	1.0	$	1.7

XML

REGULATORY ACCOUNTING (Details) (USD $)	6 Months Ended
	Jun. 30, 2012	Dec. 31, 2011
Regulatory Asset [Line Items]
Regulatory Assets Current	$ 624,397,000	$ 255,144,000
Regulatory Assets Long Term	5,201,154,000	3,267,710,000
Regulatory Assets, Total	5,825,600,000	3,522,800,000
Regulatory Assets And Liabilities Other Disclosures Abstract
Description of Regulatory Costs Not yet Approved	Regulatory Costs Not Yet Approved: Additionally, the Regulated companies had $57.6 million ($5.2 million for CL&P, $23.2 million for NSTAR Electric, $23.5 million for PSNH and $2.3 million for WMECO) and $32.4 million ($5 million for CL&P, $22.4 million for PSNH and $1.6 million for WMECO) of regulatory costs as of June 30, 2012 and December 31, 2011, respectively, which were included in Other Long-Term Assets on the accompanying unaudited condensed consolidated balance sheets. For comparative purposes, NSTAR Electric had $9.5 million of such regulatory costs as of December 31, 2011. These amounts represent incurred costs that have not yet been approved for recovery by the applicable regulatory agency. Management believes it is probable that these costs will be recovered in future cost-of-service regulated rates.
Major Storm Costs Incurred, Tropical Storm Irene And October 2011 Snowstorm	Storm Costs: On August 1, 2012, PURA issued a final decision in the investigation of CL&P’s performance related to both Tropical Storm Irene and the October 2011 snowstorm. The decision identified certain penalties that could be imposed on CL&P during its next rate case, including a reduction in allowed regulatory ROE and the disallowance of certain deferred storm restoration costs. However, PURA will consider and weigh the extent to which CL&P has taken steps in its restructuring of storm management and the establishment of new practices for execution in future storm response in determining any potential penalties. At this time, management cannot estimate the impact on CL&P’s financial position, results of operations or cash flows. CL&P continues to believe that its response to these events was prudent, is consistent with industry norms, and probable that it will be able to recover its deferred costs. As of June 30, 2012, CL&P had recorded total deferred storm costs relating to Tropical Storm Irene and the October 2011 snowstorm of $283 million. The storm cost deferral regulatory asset balance also reflects a reserve of $40 million recorded in connection with the Connecticut settlement agreement. See Note 2, "Merger of NU and NSTAR," for further information.
Regulatory Liabilities [Line Items]
Regulatory Liability Current	203,767,000	167,844,000
Regulatory Liabilities Long-Term	551,690,000	266,145,000
Regulatory Liabilities, Total	755,500,000	433,900,000
Cost Of Removal [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	454,400,000	172,200,000
Regulatory Tracker Deferrals Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	134,900,000	139,100,000
AFUDC Transmission Incentive [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	70,600,000	67,000,000
Overrecovered Spent Nuclear Fuel Costs And Contractual Obligations [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	15,400,000	15,400,000
Wholesale Transmission Overcollections [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	0	9,600,000
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	80,200,000	30,600,000
The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets Current	196,145,000	170,197,000
Regulatory Assets Long Term	2,025,569,000	2,103,830,000
Regulatory Assets, Total	2,221,700,000	2,274,000,000
Regulatory Liabilities [Line Items]
Regulatory Liability Current	88,373,000	108,291,000
Regulatory Liabilities Long-Term	130,573,000	139,307,000
Regulatory Liabilities, Total	219,000,000	247,600,000
The Connecticut Light And Power Company [Member] | Cost Of Removal [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	52,000,000	63,800,000
The Connecticut Light And Power Company [Member] | Regulatory Tracker Deferrals Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	74,600,000	94,400,000
The Connecticut Light And Power Company [Member] | AFUDC Transmission Incentive [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	57,100,000	57,700,000
The Connecticut Light And Power Company [Member] | Overrecovered Spent Nuclear Fuel Costs And Contractual Obligations [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	15,400,000	15,400,000
The Connecticut Light And Power Company [Member] | Wholesale Transmission Overcollections [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	8,100,000	4,500,000
The Connecticut Light And Power Company [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	11,800,000	11,800,000
NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets Current	326,630,000	323,871,000
Regulatory Assets Long Term	1,594,571,000	1,680,595,000
Regulatory Assets, Total	1,921,200,000	2,004,500,000
Regulatory Liabilities [Line Items]
Regulatory Liability Current	52,636,000	41,579,000
Regulatory Liabilities Long-Term	253,766,000	239,858,000
Regulatory Liabilities, Total	306,400,000	281,500,000
NSTAR Electric Company [Member] | Cost Of Removal [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	240,500,000	235,800,000
NSTAR Electric Company [Member] | Regulatory Tracker Deferrals Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	13,600,000	11,700,000
NSTAR Electric Company [Member] | AFUDC Transmission Incentive [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	4,200,000	4,300,000
NSTAR Electric Company [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	48,100,000	29,700,000
Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets Current	28,912,000	34,178,000
Regulatory Assets Long Term	347,498,000	393,941,000
Regulatory Assets, Total	376,400,000	428,100,000
Regulatory Liabilities [Line Items]
Regulatory Liability Current	23,121,000	24,500,000
Regulatory Liabilities Long-Term	53,272,000	54,415,000
Regulatory Liabilities, Total	76,400,000	78,900,000
Public Service Company Of New Hampshire [Member] | Cost Of Removal [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	51,900,000	53,200,000
Public Service Company Of New Hampshire [Member] | Regulatory Tracker Deferrals Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	13,800,000	17,300,000
Public Service Company Of New Hampshire [Member] | AFUDC Transmission Incentive [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	0	0
Public Service Company Of New Hampshire [Member] | Wholesale Transmission Overcollections [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	5,300,000	2,600,000
Public Service Company Of New Hampshire [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	5,400,000	5,800,000
Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets Current	40,587,000	35,520,000
Regulatory Assets Long Term	232,001,000	233,247,000
Regulatory Assets, Total	272,600,000	268,700,000
Regulatory Liabilities [Line Items]
Regulatory Liability Current	19,400,000	33,056,000
Regulatory Liabilities Long-Term	13,643,000	16,597,000
Regulatory Liabilities, Total	33,000,000	49,700,000
Western Massachusetts Electric Company [Member] | Cost Of Removal [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	4,100,000	7,200,000
Western Massachusetts Electric Company [Member] | Regulatory Tracker Deferrals Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	15,300,000	21,300,000
Western Massachusetts Electric Company [Member] | AFUDC Transmission Incentive [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	9,300,000	9,300,000
Western Massachusetts Electric Company [Member] | Wholesale Transmission Overcollections [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	2,500,000	9,500,000
Western Massachusetts Electric Company [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	1,800,000	2,400,000
Deferred Benefit Costs [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	2,427,700,000	1,360,500,000
Deferred Benefit Costs [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	533,600,000	572,800,000
Deferred Benefit Costs [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	819,500,000	813,700,000
Deferred Benefit Costs [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	184,100,000	200,000,000
Deferred Benefit Costs [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	111,200,000	118,900,000
Regulatory Assets Offsetting Derivative Liabilities [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	941,200,000	939,600,000
Regulatory Assets Offsetting Derivative Liabilities [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	911,000,000	932,000,000
Regulatory Assets Offsetting Derivative Liabilities [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	15,800,000	3,400,000
Regulatory Assets Offsetting Derivative Liabilities [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	0	0
Regulatory Assets Offsetting Derivative Liabilities [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	13,500,000	7,300,000
Goodwill [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	547,700,000
Goodwill [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	470,200,000	478,900,000
Deferred Income Tax Charges Member
Regulatory Asset [Line Items]
Regulatory Assets, Total	502,900,000	425,400,000
Deferred Income Tax Charges Member | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	356,000,000	339,600,000
Deferred Income Tax Charges Member | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	47,900,000	48,800,000
Deferred Income Tax Charges Member | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	36,900,000	38,000,000
Deferred Income Tax Charges Member | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	30,000,000	17,800,000
Storm Cost Deferrals [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	363,400,000	356,000,000
Storm Cost Deferrals [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	246,500,000	268,300,000
Storm Cost Deferrals [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	36,600,000	30,600,000
Storm Cost Deferrals [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	38,900,000	44,000,000
Storm Cost Deferrals [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	41,400,000	43,700,000
Securitized Assets [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	364,400,000	101,800,000
Securitized Assets [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	0	0
Securitized Assets [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	299,200,000	368,500,000
Securitized Assets [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	48,600,000	76,400,000
Securitized Assets [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	16,600,000	25,400,000
Unrecovered Contractual Obligations [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	236,100,000	100,900,000
Unrecovered Contractual Obligations [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	72,400,000	80,900,000
Unrecovered Contractual Obligations [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	26,800,000	30,800,000
Unrecovered Contractual Obligations [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	0	0
Unrecovered Contractual Obligations [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	17,400,000	20,000,000
Power Contracts Buy Out Agreements [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	105,700,000	8,600,000
Power Contracts Buy Out Agreements [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	97,900,000	109,500,000
Power Contracts Buy Out Agreements [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	7,800,000	8,600,000
Regulatory Tracker Deferrals Regulatory Assets [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	119,200,000	45,900,000
Regulatory Tracker Deferrals Regulatory Assets [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	26,500,000	5,500,000
Regulatory Tracker Deferrals Regulatory Assets [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	52,300,000	61,100,000
Regulatory Tracker Deferrals Regulatory Assets [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	13,600,000	11,900,000
Regulatory Tracker Deferrals Regulatory Assets [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	24,900,000	22,100,000
Asset Retirement Obligation Costs Member
Regulatory Asset [Line Items]
Regulatory Assets, Total	82,400,000	47,500,000
Asset Retirement Obligation Costs Member | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	29,100,000	27,900,000
Asset Retirement Obligation Costs Member | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	25,500,000	24,500,000
Asset Retirement Obligation Costs Member | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	13,800,000	13,500,000
Asset Retirement Obligation Costs Member | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	3,400,000	3,200,000
Loss On Reacquired Debt Member
Regulatory Asset [Line Items]
Regulatory Assets, Total	40,700,000	24,500,000
Loss On Reacquired Debt Member | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	13,700,000	13,900,000
Loss On Reacquired Debt Member | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	16,900,000	18,200,000
Loss On Reacquired Debt Member | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	8,500,000	9,000,000
Loss On Reacquired Debt Member | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	300,000	300,000
Deferred Environmental Remediation Costs Member
Regulatory Asset [Line Items]
Regulatory Assets, Total	58,400,000	38,500,000
Deferred Environmental Remediation Costs Member | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	9,900,000	9,700,000
Other Regulatory Assets [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	35,800,000	73,600,000
Other Regulatory Assets [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	32,900,000	33,100,000
Other Regulatory Assets [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	12,600,000	16,500,000
Other Regulatory Assets [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	14,300,000	17,000,000
Other Regulatory Assets [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	$ 13,900,000	$ 10,000,000

XML

SEGMENT INFORMATION

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Segment Reporting Disclosure [Text Block]

15.       SEGMENT INFORMATION

Presentation: NU is organized between the Regulated companies' segments and Other operations based on a combination of factors, including the characteristics of each business' products and services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates. Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred but not paid, cost of removal, AFUDC related to equity funds, and the capitalized portions of pension and PBOP expense or income.

The Regulated companies' segments include the electric distribution segment, the natural gas distribution segment and the electric transmission segment. The electric distribution segment includes the generation activities of PSNH and WMECO. The Regulated companies' segments represented substantially all of NU's total consolidated revenues for the three and six month periods ended June 30, 2012 and 2011.

Other operations in the tables below primarily consists of 1) the results of NU parent and NSTAR LLC, which includes other income related to the equity in earnings of NU parent and NSTAR LLC's subsidiaries, respectively, and interest income from the NU Money Pool, which are eliminated in consolidation, and interest income and expense related to the cash and debt of NU parent and NSTAR LLC, respectively, 2) the revenues and expenses of NU's service companies, most of which are eliminated in consolidation, 3) the operations of CYAPC and YAEC,and 4) the results of other subsidiaries, which are comprised of NU Enterprises, NSTAR Communications, Inc., RRR (a real estate subsidiary), the non-energy-related subsidiaries of Yankee and the remaining operations of HWP.

Regulated companies' revenues from the sale of electricity and natural gas primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer.

As discussed in Note 1A, "Summary of Significant Accounting Policies – Basis of Presentation," certain reclassifications of prior period data were made in the accompanying unaudited condensed consolidated statements of income for NU. Accordingly, the corresponding items of segment information have been recast for all prior periods for comparative purposes.

NU's segment information for the three and six months ended June 30, 2012 and 2011, with the distribution segment segregated between electric and natural gas, is as follows:

		For the Three Months Ended June 30, 2012
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	1,229.9	$	133.5	$	228.7	$	230.2	$	(193.6)	$	1,628.7
Depreciation and Amortization			(153.3)		(12.4)		(28.6)		(17.7)		1.2		(210.8)
Other Operating Expenses			(1,004.8)		(115.8)		(65.5)		(263.0)		190.7		(1,258.4)
Operating Income/(Loss)			71.8		5.3		134.6		(50.5)		(1.7)		159.5
Interest Expense			(44.8)		(8.8)		(26.2)		(11.1)		1.9		(89.0)
Interest Income			1.0		-		0.1		1.4		(1.4)		1.1
Other Income/(Loss), Net			(0.2)		0.1		0.7		117.9		(117.8)		0.7
Income Tax (Expense)/Benefit			(6.9)		1.3		(44.8)		25.0		(0.7)		(26.1)
Net Income/(Loss)			20.9		(2.1)		64.4		82.7		(119.7)		46.2
Net Income Attributable
	to Noncontrolling Interests		(1.2)		-		(0.7)		-		-		(1.9)
Net Income/(Loss) Attributable
	to Controlling Interest	$	19.7	$	(2.1)	$	63.7	$	82.7	$	(119.7)	$	44.3

		For the Six Months Ended June 30, 2012
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	2,016.0	$	272.5	$	391.6	$	363.4	$	(315.2)	$	2,728.3
Depreciation and Amortization			(225.4)		(20.1)		(49.8)		(21.6)		1.5		(315.4)
Other Operating Expenses			(1,627.0)		(218.0)		(113.2)		(397.8)		317.0		(2,039.0)
Operating Income/(Loss)			163.6		34.4		228.6		(56.0)		3.3		373.9
Interest Expense			(77.9)		(14.3)		(45.8)		(20.4)		2.9		(155.5)
Interest Income			2.1		-		0.3		2.6		(2.7)		2.3
Other Income, Net			4.2		0.1		3.9		240.5		(240.4)		8.3
Income Tax (Expense)/Benefit			(28.3)		(7.6)		(75.6)		31.0		(1.5)		(82.0)
Net Income			63.7		12.6		111.4		197.7		(238.4)		147.0
Net Income Attributable
	to Noncontrolling Interests		(2.0)		-		(1.4)		-		-		(3.4)
Net Income Attributable
	to Controlling Interest	$	61.7	$	12.6	$	110.0	$	197.7	$	(238.4)	$	143.6
Cash Flows for Total
	Investments in Plant	$	305.7	$	59.7	$	297.2	$	27.8	$	-	$	690.4

		For the Three Months Ended June 30, 2011
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	794.4	$	78.4	$	152.1	$	130.8	$	(108.2)	$	1,047.5
Depreciation and Amortization			(76.5)		(6.3)		(21.4)		(3.9)		0.4		(107.7)
Other Operating Expenses			(633.2)		(65.7)		(44.2)		(126.8)		108.2		(761.7)
Operating Income			84.7		6.4		86.5		0.1		0.4		178.1
Interest Expense			(31.0)		(5.2)		(19.1)		(8.5)		1.6		(62.2)
Interest Income			0.6		-		0.1		1.5		(1.5)		0.7
Other Income, Net			2.8		0.4		3.3		85.4		(85.3)		6.6
Income Tax (Expense)/Benefit			(17.2)		(0.4)		(28.0)		2.0		(0.9)		(44.5)
Net Income			39.9		1.2		42.8		80.5		(85.7)		78.7
Net Income Attributable
	to Noncontrolling Interests		(0.8)		-		(0.6)		-		-		(1.4)
Net Income Attributable
	to Controlling Interest	$	39.1	$	1.2	$	42.2	$	80.5	$	(85.7)	$	77.3

		For the Six Months Ended June 30, 2011
		Regulated Companies
		Distribution
(Millions of Dollars)		Electric		Natural Gas		Transmission		Other		Eliminations		Total
Operating Revenues		$	1,686.0	$	258.6	$	310.3	$	261.2	$	(233.4)	$	2,282.7
Depreciation and Amortization			(167.5)		(13.1)		(44.8)		(8.3)		1.3		(232.4)
Other Operating Expenses			(1,326.3)		(199.2)		(92.5)		(261.7)		234.9		(1,644.8)
Operating Income/(Loss)			192.2		46.3		173.0		(8.8)		2.8		405.5
Interest Expense			(60.6)		(10.4)		(35.4)		(17.1)		2.7		(120.8)
Interest Income			1.9		-		0.3		2.7		(2.8)		2.1
Other Income, Net			6.6		0.8		8.1		234.9		(234.8)		15.6
Income Tax (Expense)/Benefit			(43.6)		(13.0)		(57.9)		7.8		(1.4)		(108.1)
Net Income			96.5		23.7		88.1		219.5		(233.5)		194.3
Net Income Attributable
	to Noncontrolling Interests		(1.7)		-		(1.2)		-		-		(2.9)
Net Income Attributable
	to Controlling Interest	$	94.8	$	23.7	$	86.9	$	219.5	$	(233.5)	$	191.4
Cash Flows Used for
	Investments in Plant	$	251.1	$	45.4	$	146.0	$	26.0	$	-	$	468.5

The information related to the distribution and transmission segments for CL&P, PSNH and WMECO for the three and six months
ended June 30, 2012 and 2011 is as follows:
	For the Three Months Ended
	June 30, 2012						June 30, 2011
(Millions of Dollars)	Distribution		Transmission		Total		Distribution		Transmission		Total
CL&P
Operating Revenues	$	442.2	$	119.9	$	562.1	$	489.9	$	118.1	$	608.0
Net Income/(Loss)		(27.2)		34.1		6.9		19.8		32.8		52.6
PSNH
Operating Revenues		229.4		25.7		255.1		219.1		21.1		240.2
Net Income		14.7		6.5		21.2		16.0		5.7		21.7
WMECO
Operating Revenues		81.6		25.2		106.8		85.4		13.0		98.4
Net Income		1.4		9.7		11.1		4.0		4.2		8.2

	For the Six Months Ended
	June 30, 2012						June 30, 2011
(Millions of Dollars)	Distribution		Transmission		Total		Distribution		Transmission		Total
CL&P
Operating Revenues	$	916.9	$	237.2	$	1,154.1	$	1,039.8	$	241.9	$	1,281.7
Net Income/(Loss)		(5.5)		66.4		60.9		49.2		67.8		117.0
PSNH
Operating Revenues		448.9		49.2		498.1		467.0		42.7		509.7
Net Income		29.9		12.6		42.5		37.5		11.6		49.1
WMECO
Operating Revenues		173.6		47.3		220.9		179.3		25.8		205.1
Net Income		7.5		17.8		25.3		9.7		8.4		18.1

The following tables summarize NU, CL&P, PSNH and WMECO's segmented total assets:

	Regulated Companies
NU	Distribution
(Millions of Dollars)	Electric		Natural Gas		Transmission		Other		Eliminations		Total
As of June 30, 2012	$	15,161.3	$	2,432.7	$	5,327.7	$	20,614.1	$	(16,029.5)	$	27,506.3
As of December 31, 2011		9,653.1		1,511.3		3,792.9		6,618.0		(5,928.2)		15,647.1
	As of June 30, 2012						As of December 31, 2011
(Millions of Dollars)	Distribution		Transmission		Total		Distribution		Transmission		Total
CL&P	$	6,137.5	$	2,697.9	$	8,835.4	$	6,161.0	$	2,630.4	$	8,791.4
PSNH		2,451.5		585.3		3,036.8		2,551.3		565.2		3,116.5
WMECO		943.3		690.2		1,633.5		942.6		560.3		1,502.9

XML

Provision for Uncollectible Accounts (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Accounts Notes Loans And Financing Receivable Text Block

(Millions of Dollars)	As of June 30, 2012		As of December 31, 2011(1)
NU	$	93.1	$	34.9
CL&P		11.8		14.8
NSTAR Electric		44.7		27.1
PSNH		7.9		7.2
WMECO		3.7		4.6

XML

Supplemental Cash Flow Information (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011
Capital Expenditures Incurred But Not Yet Paid	$ 166.3	$ 109.4
The Connecticut Light And Power Company [Member]
Capital Expenditures Incurred But Not Yet Paid	45.1	19.4
Storm Reserve Credits Paid To Customers	27.0
Public Service Company Of New Hampshire [Member]
Capital Expenditures Incurred But Not Yet Paid	25.7	29.6
Western Massachusetts Electric Company [Member]
Capital Expenditures Incurred But Not Yet Paid	56.5	39.7
NSTAR Electric Company [Member]
Capital Expenditures Incurred But Not Yet Paid	$ 22.7	$ 18.8

XML

COMMON SHARESHOLDERS' EQUITY AND NONCONTROLLING INTERESTS (NU) (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Minority Interest Disclosure Text Block

		For the Three Months Ended
		June 30, 2012								June 30, 2011
								Noncontrolling								Noncontrolling
		Common						Interest -		Common						Interest -
		Shareholders'		Noncontrolling		Total		Preferred Stock		Shareholders'		Noncontrolling		Total		Preferred Stock
(Millions of Dollars)		Equity		Interest		Equity		of Subsidiaries		Equity		Interest		Equity		of Subsidiaries
Balance as of Beginning
	of Period	$	4,068.3	$	3.4	$	4,071.7	$	116.2	$	3,885.3	$	1.5	$	3,886.8	$	116.2
Net Income			46.2		-		46.2		-		78.7		-		78.7		-
Purchase Price of NSTAR(1)			5,038.3		-		5,038.3		-		-		-		-		-
Other Impacts of Merger with
	NSTAR(2)		3.4		(3.4)		-		39.4		-		-		-		-
Dividends on Common Shares			(107.6)		-		(107.6)		-		(48.9)		-		(48.9)		-
Dividends on Preferred Stock			(1.9)		-		(1.9)		(1.9)		(1.4)		-		(1.4)		(1.4)
Issuance of Common Shares			5.2		-		5.2		-		-		-		-		-
Contributions to NPT			-		-		-		-		-		0.3		0.3		-
Other Transactions, Net			13.3		-		13.3		-		6.0		-		6.0		-
Net Income Attributable to
	Noncontrolling Interests		-		-		-		1.9		-		-		-		1.4
Other Comprehensive Income			2.4		-		2.4		-		(4.6)		-		(4.6)		-
Balance as of End of Period		$	9,067.6	$	-	$	9,067.6	$	155.6	$	3,915.1	$	1.8	$	3,916.9	$	116.2
		For the Six Months Ended
		June 30, 2012								June 30, 2011
								Noncontrolling								Noncontrolling
		Common						Interest -		Common						Interest -
		Shareholders'		Noncontrolling		Total		Preferred Stock		Shareholders'		Noncontrolling		Total		Preferred Stock
(Millions of Dollars)		Equity		Interest		Equity		of Subsidiaries		Equity		Interest		Equity		of Subsidiaries
Balance as of Beginning
	of Period	$	4,012.7	$	3.0	$	4,015.7	$	116.2	$	3,811.2	$	1.5	$	3,812.7	$	116.2
Net Income			147.0		-		147.0		-		194.3		-		194.3		-
Purchase Price of NSTAR(1)			5,038.3		-		5,038.3		-		-		-		-		-
Other Impacts of Merger with
	NSTAR(2)		3.4		(3.4)		-		39.4		-		-		-		-
Dividends on Common Shares			(160.2)		-		(160.2)		-		(97.7)		-		(97.7)		-
Dividends on Preferred Stock			(3.3)		-		(3.3)		(3.3)		(2.8)		-		(2.8)		(2.8)
Issuance of Common Shares			11.4		-		11.4		-		4.2		-		4.2		-
Contributions to NPT			-		0.3		0.3		-		-		0.3		0.3		-
Other Transactions, Net			14.1		-		14.1		-		8.3		-		8.3		-
Net Income Attributable to
	Noncontrolling Interests		(0.1)		0.1		-		3.3		-		-		-		2.8
Other Comprehensive Income			4.3		-		4.3		-		(2.4)		-		(2.4)		-
Balance as of End of Period		$	9,067.6	$	0.0	$	9,067.6	$	155.6	$	3,915.1	$	1.8	$	3,916.9	$	116.2

XML

CONSOLIDATED STATEMENT OF CASH FLOWS (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011
Operating Activities:
Net Income	$ 146,974	$ 194,303
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Bad Debt Expense	13,384	9,374
Depreciation	225,324	147,588
Deferred Income Tax Expense (Benefit)	59,509	95,293
Pension, SERP, and PBOP Expense, Net of PBOP Contributions	97,378	69,654
Pension and PBOP Contributions	(164,294)	(37,530)
Regulatory (Underrecoveries)/Overrecoveries, Net	(54,491)	41,612
Amortization of Regulatory Assets/(Liabilities), Net	31,016	50,491
Amortization of Rate Reduction Bonds	59,100	34,367
Changes in Derivative Assets and Liabilities	(5,090)	(9,272)
Other Noncash Income (Expense)	11,226	(7,192)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	83,395	80,696
Inventory	40,695	12,992
Taxes Receivable/(Accrued)	17,709	48,933
Change in Accounts Payable	(176,533)	(23,981)
Other Current Assets and Liabilities	(64,899)	(20,633)
Net Cash Flows (Used in)/ Provided by Operating Activities	320,403	686,695
Investing Activities:
Investments in Property, Plant and Equipment	(690,376)	(468,526)
Proceeds from Sales of Marketable Securities	132,580	72,369
Purchases of Marketable Securities	(143,225)	(73,564)
Proceeds From Sale Of Property Plant And Equipment	0	46,841
Other Investing Activities	11,274	(4,828)
Net Cash Flows Used in Investing Activities	(689,747)	(427,708)
Financing Activities:
Cash Dividends on Common Stock	(159,708)	(97,207)
Cash Dividends on Preferred Stock	(3,269)	(2,779)
Increase/(Decrease) in Short-Term Debt	558,500	(130,000)
Issuance of Long-Term Debt	300,000	122,000
Retirements of Long-Term Debt	(267,699)	(124,086)
Retirements of Rate Reduction Bonds	(36,439)	(34,320)
Other Financing Activities	(117)	(883)
Net Cash Flows Provided by/(Used in) Financing Activities	391,268	(267,275)
Net Increase/(Decrease) in Cash	21,924	(8,288)
Cash - Beginning of Year	6,559	23,395
Cash - End of Year	28,483	15,107
The Connecticut Light And Power Company [Member]
Operating Activities:
Net Income	60,918	116,972
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Bad Debt Expense	743	2,252
Depreciation	82,588	77,917
Deferred Income Tax Expense (Benefit)	30,874	60,425
Pension, SERP, and PBOP Expense, Net of PBOP Contributions	12,030	9,868
Regulatory (Underrecoveries)/Overrecoveries, Net	(19,596)	24,852
Amortization of Regulatory Assets/(Liabilities), Net	11,257	32,339
Other Noncash Income (Expense)	(12,821)	(17,752)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	38,253	34,192
Inventory	(2,457)	(11,761)
Taxes Receivable/(Accrued)	39,985	31,797
Change in Accounts Payable	(170,151)	(12,078)
Other Current Assets and Liabilities	(24,122)	9,968
Net Cash Flows (Used in)/ Provided by Operating Activities	47,501	358,991
Investing Activities:
Investments in Property, Plant and Equipment	(220,712)	(201,966)
Decrease/(Increase) in NU Money Pool Lending	0	(24,125)
Proceeds From Sale Of Property Plant And Equipment	0	46,841
Other Investing Activities	3,460	(6,489)
Net Cash Flows Used in Investing Activities	(217,252)	(185,739)
Financing Activities:
Cash Dividends on Common Stock	(66,991)	(168,744)
Cash Dividends on Preferred Stock	(2,779)	(2,779)
Increase/(Decrease) in Short-Term Debt	299,000	0
Increase/(Decrease) in NU Money Pool Borrowings	(53,525)	(6,225)
Other Financing Activities	(1,432)	(188)
Net Cash Flows Provided by/(Used in) Financing Activities	174,273	(177,936)
Net Increase/(Decrease) in Cash	4,522	(4,684)
Cash - Beginning of Year	1	9,762
Cash - End of Year	4,523	5,078
Public Service Company Of New Hampshire [Member]
Operating Activities:
Net Income	42,494	49,129
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Bad Debt Expense	3,378	3,303
Depreciation	43,018	36,030
Deferred Income Tax Expense (Benefit)	17,885	20,773
Pension, SERP, and PBOP Expense, Net of PBOP Contributions	13,168	14,406
Pension and PBOP Contributions	(91,990)	(18,469)
Regulatory (Underrecoveries)/Overrecoveries, Net	3,625	726
Amortization of Regulatory Assets/(Liabilities), Net	177	18,032
Amortization of Rate Reduction Bonds	27,743	26,139
Other Noncash Income (Expense)	13,165	(2,545)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	3,283	12,844
Inventory	17,365	11,915
Taxes Receivable/(Accrued)	(3,776)	9,767
Change in Accounts Payable	(14,171)	(8,611)
Other Current Assets and Liabilities	(5,231)	(16,885)
Net Cash Flows (Used in)/ Provided by Operating Activities	70,133	156,554
Investing Activities:
Investments in Property, Plant and Equipment	(120,792)	(111,459)
Decrease/(Increase) in NU Money Pool Lending	55,900	0
Other Investing Activities	3,045	1,928
Net Cash Flows Used in Investing Activities	(61,847)	(109,531)
Financing Activities:
Cash Dividends on Common Stock	(58,783)	(29,414)
Increase/(Decrease) in Short-Term Debt	65,000	(8,000)
Issuance of Long-Term Debt	0	122,000
Increase/(Decrease) in NU Money Pool Borrowings	13,500	(4,100)
Retirements of Long-Term Debt	0	(119,800)
Retirements of Rate Reduction Bonds	(27,626)	(26,052)
Capital Contributions from NU Parent	0	20,000
Other Financing Activities	(230)	(1,803)
Net Cash Flows Provided by/(Used in) Financing Activities	(8,139)	(47,169)
Net Increase/(Decrease) in Cash	147	(146)
Cash - Beginning of Year	56	2,559
Cash - End of Year	203	2,413
Western Massachusetts Electric Company [Member]
Operating Activities:
Net Income	25,324	18,137
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Bad Debt Expense	790	1,860
Depreciation	14,691	12,963
Deferred Income Tax Expense (Benefit)	17,708	7,004
Regulatory (Underrecoveries)/Overrecoveries, Net	(17,645)	9,222
Amortization of Regulatory Assets/(Liabilities), Net	(387)	728
Amortization of Rate Reduction Bonds	8,776	8,228
Other Noncash Income (Expense)	1,127	(2,034)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	694	405
Inventory	(2,793)	(398)
Taxes Receivable/(Accrued)	533	9,523
Change in Accounts Payable	(433)	1,021
Other Current Assets and Liabilities	(4,541)	(281)
Net Cash Flows (Used in)/ Provided by Operating Activities	43,844	66,378
Investing Activities:
Investments in Property, Plant and Equipment	(152,687)	(76,898)
Proceeds from Sales of Marketable Securities	45,516	57,746
Purchases of Marketable Securities	(45,889)	(57,888)
Decrease/(Increase) in NU Money Pool Lending	11,000	0
Other Investing Activities	1,096	(792)
Net Cash Flows Used in Investing Activities	(140,964)	(77,832)
Financing Activities:
Cash Dividends on Common Stock	(9,432)	(13,153)
Increase/(Decrease) in Short-Term Debt	110,000	20,000
Increase/(Decrease) in NU Money Pool Borrowings	5,400	7,700
Retirements of Rate Reduction Bonds	(8,813)	(8,268)
Capital Contributions from NU Parent	0	5,186
Other Financing Activities	(35)	(11)
Net Cash Flows Provided by/(Used in) Financing Activities	97,120	11,454
Net Increase/(Decrease) in Cash	0	0
Cash - Beginning of Year	1	1
Cash - End of Year	1	1
NSTAR Electric Company [Member]
Operating Activities:
Net Income	49,422	103,547
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Bad Debt Expense	46,726	8,284
Depreciation	85,198	83,157
Deferred Income Tax Expense (Benefit)	(17,069)	3,413
Pension, SERP, and PBOP Expense, Net of PBOP Contributions	16,822	(31,298)
Regulatory (Underrecoveries)/Overrecoveries, Net	16,371	70,319
Amortization of Regulatory Assets/(Liabilities), Net	46,024	29,669
Amortization of Rate Reduction Bonds	45,161	45,161
Other Noncash Income (Expense)	(24,559)	8,807
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(19,555)	(33,830)
Inventory	10,387	(4,673)
Taxes Receivable/(Accrued)	(29,978)	174,103
Change in Accounts Payable	(64,317)	(100,840)
Other Current Assets and Liabilities	(1,222)	4,125
Net Cash Flows (Used in)/ Provided by Operating Activities	159,411	359,944
Investing Activities:
Investments in Property, Plant and Equipment	(189,229)	(156,842)
Other Investing Activities	7,242	20,641
Net Cash Flows Used in Investing Activities	(181,987)	(136,201)
Financing Activities:
Cash Dividends on Common Stock	(135,400)	(113,300)
Cash Dividends on Preferred Stock	(980)	(980)
Increase/(Decrease) in Short-Term Debt	203,000	(64,500)
Retirements of Long-Term Debt	(825)	(825)
Retirements of Rate Reduction Bonds	(43,548)	(43,581)
Net Cash Flows Provided by/(Used in) Financing Activities	22,247	(223,186)
Net Increase/(Decrease) in Cash	(329)	557
Cash - Beginning of Year	9,373	8,964
Cash - End of Year	$ 9,044	$ 9,521

XML

PROPERTY, PLANT AND ACCUMULATED DEPRECIATION

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule of Public Utility Property, Plant, and Equipment [Text Block]

4.PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

The following tables summarize the NU, CL&P, NSTAR Electric, PSNH and WMECO investments in utility property, plant and equipment:

		As of June 30, 2012		As of December 31, 2011
(Millions of Dollars)		NU		NU
Distribution - Electric		$	11,168.1	$	6,540.4
Distribution - Natural Gas			2,160.1		1,247.6
Transmission			5,061.1		3,541.9
Generation			1,147.3		1,096.0
Electric and Natural Gas Utility			19,536.6		12,425.9
Other (1)			420.2		305.1
Property, Plant and Equipment, Gross			19,956.8		12,731.0
Less: Accumulated Depreciation
	Electric and Natural Gas Utility		(4,910.2)		(3,035.5)
	Other		(160.8)		(120.2)
Total Accumulated Depreciation			(5,071.0)		(3,155.7)
Property, Plant and Equipment, Net			14,885.8		9,575.3
Construction Work in Progress			1,169.1		827.8
Total Property, Plant and Equipment, Net		$	16,054.9	$	10,403.1

(1)These assets are primarily comprised of building improvements at RRR and software and equipment at NUSCO as of June 30, 2012 and December 31, 2011, and telecommunications equipment at NSTAR Communications, Inc.as of June 30, 2012.

		As of June 30, 2012								As of December 31, 2011
				NSTAR								NSTAR
(Millions of Dollars)		CL&P		Electric		PSNH		WMECO		CL&P		Electric(1)		PSNH		WMECO
Distribution		$	4,590.2	$	4,418.7	$	1,481.6	$	713.8	$	4,419.6	$	4,334.4	$	1,451.6	$	704.3
Transmission			2,707.5		1,424.8		558.2		352.6		2,689.1		1,386.9		546.4		297.4
Generation			-		-		1,126.1		21.2		-		-		1,074.8		21.2
Property, Plant and
	Equipment, Gross		7,297.7		5,843.5		3,165.9		1,087.6		7,108.7		5,721.3		3,072.8		1,022.9
Less: Accumulated Depreciation			(1,640.8)		(1,498.8)		(916.7)		(247.3)		(1,596.7)		(1,436.0)		(893.6)		(240.5)
Property, Plant and Equipment, Net			5,656.9		4,344.7		2,249.2		840.3		5,512.0		4,285.3		2,179.2		782.4
Construction Work in Progress			343.9		210.8		66.8		376.1		315.4		162.0		77.5		295.4
Total Property, Plant and
	Equipment, Net	$	6,000.8	$	4,555.5	$	2,316.0	$	1,216.4	$	5,827.4	$	4,447.3	$	2,256.7	$	1,077.8

• NSTAR Electric amounts are not included in NU consolidated as of December 31, 2011.

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SHORT TERM DEBT (Details) (The Connecticut Light And Power Company [Member], USD $) In Millions, unless otherwise specified	6 Months Ended
	Jun. 30, 2012
The Connecticut Light And Power Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amount Outstanding	$ 300.0
Short-term Debt, Terms	CL&P Credit Agreement: On March 26, 2012, CL&P entered into a five-year unsecured revolving credit facility in the amount of $300 million, which expires on March 26, 2017. Under this facility, CL&P can borrow either on a short-term or a long-term basis subject to regulatory approval. As of June 30, 2012, CL&P had $300 million in short-term borrowings outstanding under this credit facility, which was recorded in Notes Payable to Banks on the accompanying unaudited condensed consolidated balance sheet. Under this facility, CL&P may borrow at prime rates or LIBOR-based rates, plus an applicable margin based on the higher of S&P’s or Moody’s credit ratings. The weighted-average interest rate on the borrowings outstanding under this facility as of June 30, 2012 was 1.59 percent. In addition, CL&P must comply with certain financial and non-financial covenants, including a consolidated debt to total capitalization ratio. CL&P was in compliance with these covenants as of June 30, 2012. If CL&P was not in compliance with these covenants, an event of default would occur requiring all outstanding borrowings to be repaid and additional borrowings would not be permitted under this credit facility.
Short Term Debt Regulatory Limits	Limits: The amount of short-term borrowings that may be incurred by CL&P are subject to periodic approval by the FERC. On November 30, 2011, the FERC granted authorization to allow CL&P to incur total short-term borrowings up to a maximum of $450 million effective January 1, 2012 through December 31, 2013. On March 22, 2012, FERC approved CL&P's application requesting to increase its total short-term borrowing capacity from a maximum of $450 million to a maximum of $600 million for the authorization period through December 31, 2013.

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EARNINGS PER SHARE (Details) (USD $) In Thousands, except Share data, unless otherwise specified	0 Months Ended	3 Months Ended				6 Months Ended
	Apr. 09, 2012	Jun. 30, 2012	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2011
Earnings Per Share Basic And Diluted [Line Items]
Net Income Attributable to Controlling Interests			$ 44,339		$ 77,278		$ 143,601		$ 191,433
Basic		301,047,753	301,047,753	177,347,374	177,347,374	239,551,735	239,551,735	177,267,791	177,267,791
Weighted Average Number Diluted Shares Outstanding Adjustment		769,131	769,131	279,618	279,618	575,434	575,434	286,204	286,204
Diluted		301,816,884	301,816,884	177,626,992	177,626,992	240,127,169	240,127,169	177,553,995	177,553,995
Earnings Per Share Basic And Diluted		0.15	0.15	0.44	0.44	0.60	0.60	1.08	1.08
Antidilutive Securities Excluded From Computation Of Earnings Per Share Amount		17,065	17,065			8,533	8,533
Common Stock Issuance, Merger with NSTAR [Abstract]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	136,049,000

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Other Taxes (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

State Of Connecticut Gross Earnings Taxes [Table Text Block]

	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
NU	$	30.5	$	32.0	$	65.5	$	70.7
CL&P		27.7		28.8		57.1		60.2

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Guarantees (Tables)

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Guarantee Obligations Text Block

		Maximum
		Exposure
Subsidiary	Description	(in millions)			Expiration Dates
Various	Surety Bonds	$	35.0		July 2012 - Nov 2015 (1)
Various	Letters of Credit	$	19.5		Oct 2012 - Dec 2012
Various	NE Hydro Companies' Long-Term Debt	$	6.6		Unspecified
NUSCO and RRR	Lease Payments for Vehicles and Real Estate	$	21.9		2019 and 2024
NU Enterprises	Surety Bonds, Insurance Bonds and Performance Guarantees	$	109.4	(2)	(2)

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EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2012

Notes To Consolidated Financial Statements [Abstract]

Earnings Per Share [Text Block]

14.       EARNINGS PER SHARE (NU)

Basic EPS is computed based upon the monthly weighted average number of common shares outstanding during each period. Diluted EPS is computed on the basis of the monthly weighted average number of common shares outstanding plus the potential dilutive effect if certain securities are converted into common shares. For the three and six months ended June 30, 2012, there were 17,065 and 8,533, respectively, share awards excluded from the computation as these awards were antidilutive. There were no antidilutive share awards outstanding for the three and six months ended June 30, 2011.

The following table sets forth the components of basic and diluted EPS:
		For the Three Months Ended				For the Six Months Ended
(Millions of Dollars, except share information)		June 30, 2012		June 30, 2011		June 30, 2012		June 30, 2011
Net Income Attributable to Controlling Interest		$	44.3	$	77.3	$	143.6	$	191.4
Weighted Average Common Shares Outstanding:
	Basic		301,047,753		177,347,374		239,551,735		177,267,791
	Dilutive Effect		769,131		279,618		575,434		286,204
	Diluted		301,816,884		177,626,992		240,127,169		177,553,995
Basic and Diluted EPS		$	0.15	$	0.44	$	0.60	$	1.08

On April 10, 2012, NU issued approximately 136 million common shares as a result of the merger with NSTAR, which are reflected in weighted average common shares outstanding as of June 30, 2012.

RSUs and performance shares are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. The dilutive effect of unvested RSUs and performance shares is calculated using the treasury stock method. Assumed proceeds of the units under the treasury stock method consist of the remaining compensation cost to be recognized and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the units (the difference between the market value of the average units outstanding for the period, using the average market price during the period, and the grant date market value).

The dilutive effect of stock options to purchase common shares is also calculated using the treasury stock method. Assumed proceeds for stock options consist of cash proceeds that would be received upon exercise, and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the stock options (the difference between the market value of the average stock options outstanding for the period, using the average market price during the period, and the exercise price).