10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

(Mark One)

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934   For the quarterly period ended March 31, 2013

OR

o 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	IRS Employer Identification No.
0-30512	CH Energy Group, Inc.(Incorporated in New York)284 South AvenuePoughkeepsie, New York 12601-4839 (845) 452-2000	14-1804460
1-3268	Central Hudson Gas & Electric Corporation(Incorporated in New York)284 South AvenuePoughkeepsie, New York 12601-4839 (845) 452-2000	14-0555980

Indicate by check mark whether the registrant (1) has 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) has been subject to such filing requirements for the past 90 days.

CH Energy Group, Inc.	Yes  þ	No  o
Central Hudson Gas & Electric Corporation	Yes  þ	No  o

Indicate by check mark whether the registrant has 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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

CH Energy Group, Inc.	Yes  þ	No  o
Central Hudson Gas & Electric Corporation	Yes  þ	No  o

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

CH Energy Group, Inc.	Central Hudson Gas & Electric Corporation
Large Accelerated Filer þ	Large Accelerated Filer o
Accelerated Filer o	Accelerated Filer o
Non-Accelerated Filer o	Non-Accelerated Filer þ
Smaller Reporting Company o	Smaller Reporting Company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act):

CH Energy Group, Inc.	Yes  o	No  þ
Central Hudson Gas & Electric Corporation	Yes  o	No  þ

As of the close of business on April 30, 2013 (i) CH Energy Group, Inc. had outstanding 14,973,794 shares of Common Stock ($0.10 per share par value) and (ii) all of the outstanding 16,862,087 shares of Common Stock ($5 per share par value) of Central Hudson Gas & Electric Corporation were held by CH Energy Group, Inc.

CENTRAL HUDSON GAS & ELECTRIC CORPORATION MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTIONS (H)(1)(a) AND (b) OF FORM 10-Q AND IS THEREFORE FILING THIS FORM WITH THE REDUCED DISCLOSURE FORMAT PURSUANT TO GENERAL INSTRUCTIONS (H)(2)(a), (b) AND (c).

FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2013

TABLE OF CONTENTS

 

CH Energy Group, Inc.		PAGE
	Consolidated Statement of Income –
	Three Months Ended March 31, 2013 and 2012	1
	Consolidated Statement of Comprehensive Income –
	Three Months Ended March 31, 2013 and 2012	2
	Consolidated Statement of Cash Flows –
	Three Months Ended March 31, 2013 and 2012	3
	Consolidated Balance Sheet –
	March 31, 2013, December 31, 2012 and March 31, 2012	4
	Consolidated Statement of Equity –
	Three Months Ended March 31, 2013 and 2012	6

Central Hudson Gas & Electric Corporation
	Statement of Income –
	Three Months Ended March 31, 2013 and 2012	7
	Statement of Comprehensive Income –
	Three Months Ended March 31, 2013 and 2012	7
	Statement of Cash Flows –
	Three Months Ended March 31, 2013 and 2012	8
	Balance Sheet –
	March 31, 2013, December 31, 2012 and March 31, 2012	9
	Statement of Equity –
	Three Months Ended March 31, 2013 and 2012	11

NOTES TO FINANCIAL STATEMENTS (UNAUDITED) 12

	TABLE OF CONTENTS
		PAGE
ITEM 2	Management's Discussion and Analysis of Financial Condition and Results of Operations	52
ITEM 3	Quantitative and Qualitative Disclosure About Market Risk	79
ITEM 4	Controls and Procedures	79

ITEM 1	Legal Proceedings	80
ITEM 1A	Risk Factors	80
ITEM 2	Unregistered Sales of Equity Securities and Use of Proceeds	81
ITEM 4	Mine Safety Disclosures	81
ITEM 6	Exhibits	81
SIGNATURES		82
EXHIBIT INDEX		83

_______________________________________________

FILING FORMAT

This Quarterly Report on Form 10-Q is a combined quarterly report being filed by two different registrants:  CH Energy Group, Inc. ("CH Energy Group") and Central Hudson Gas & Electric Corporation ("Central Hudson"), a wholly owned subsidiary of CH Energy Group.  Except where the content clearly indicates otherwise, any reference in this report to CH Energy Group includes all subsidiaries of CH Energy Group, including Central Hudson.  Central Hudson makes no representation as to the information contained in this report in relation to CH Energy Group and its subsidiaries other than Central Hudson.

PART I – FINANCIAL INFORMATION

ITEM 1 – Financial Statements (Unaudited)

CH ENERGY GROUP CONSOLIDATED STATEMENT OF INCOME (UNAUDITED)

(In Thousands, except per share amounts)

	Three Months Ended March 31,
	2013		2012
Operating Revenues
Electric	$	138,163	$	129,272
Natural gas		56,300		55,850
Competitive business subsidiaries:
Petroleum products		99,019		84,632
Other		4,892		4,318
Total Operating Revenues		298,374		274,072
Operating Expenses
Operation:
Purchased electricity and fuel used in electric generation		50,409		45,059
Purchased natural gas		23,399		24,614
Purchased petroleum		81,529		70,305
Other expenses of operation - regulated activities		66,792		59,886
Other expenses of operation - competitive business subsidiaries		13,303		12,422
Merger related costs		387		5,219
Depreciation and amortization		11,187		10,624
Taxes, other than income tax		14,947		13,730
Total Operating Expenses		261,953		241,859
Operating Income		36,421		32,213
Other Income and Deductions
Income from unconsolidated affiliates		199		52
Interest on regulatory assets and other interest income		1,385		1,719
Regulatory adjustments for interest costs		324		319
Other - net		127		(9	)
Total Other Income (Deductions)		2,035		2,081
Interest Charges
Interest on long-term debt		6,430		6,218
Interest on regulatory liabilities and other interest		1,915		1,584
Total Interest Charges		8,345		7,802
Income before income taxes, non-controlling interest and preferred dividends of subsidiary		30,111		26,492
Income Taxes		11,165		11,669
Net Income		18,946		14,823
Net Income attributable to non-controlling interest:
Dividends declared on Preferred Stock of subsidiary		92		242
Preferred Stock Redemption Premium		764		-
Net Income Attributable to CH Energy Group		18,090		14,581
Dividends declared on Common Stock		8,310		8,279
Change in Retained Earnings	$	9,780	$	6,302

The Notes to Financial Statements are an integral part hereof.

-1-

CH ENERGY GROUP CONSOLIDATED STATEMENT OF INCOME (CONT'D) (UNAUDITED)

(In Thousands, except per share amounts)

	Three Months Ended March 31,
	2013		2012
Common Stock:
Average shares outstanding - Basic		14,942		14,882
Average shares outstanding - Diluted		15,156		15,143
Amounts attributable to CH Energy Group common shareholders:
Earnings per share - Basic	$	1.21	$	0.98
Earnings per share - Diluted	$	1.19	$	0.96
Dividends Declared per Share	$	0.555	$	0.555

CH ENERGY GROUP CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

(In Thousands)

	Three Months Ended March 31,
	2013			2012
Net Income	$	18,946		$	14,823
Other Comprehensive Income:
Net unrealized losses on investments held by equity method investees - net of tax of $8 and $38, respectively		(12	)		(58	)
Other comprehensive loss		(12	)		(58	)
Comprehensive Income		18,934			14,765
Comprehensive income attributable to non-controlling interest		856			242
Comprehensive income attributable to CH Energy Group	$	18,078		$	14,523

The Notes to Financial Statements are an integral part hereof.

-2-

CH ENERGY GROUP CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

(In Thousands)

	Three Months Ended March 31,
	2013			2012
Operating Activities:
Net income	$	18,946		$	14,823
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation		9,940			9,499
Amortization		1,247			1,125
Deferred income taxes - net		3,156			11,598
Bad debt expense		964			2,500
Undistributed equity in earnings of unconsolidated affiliates		(199	)		(52	)
Pension expense		6,022			7,233
Other post-employment benefits ("OPEB") expense		1,989			1,996
Regulatory liability - rate moderation		-			(1,033	)
Revenue decoupling mechanism recorded		4,203			(950	)
Regulatory asset amortization		1,682			1,722
Regulatory asset storm deferral adjustment		4,000			-
Gain on sale of assets		(22	)		(79	)
Changes in operating assets and liabilities - net of business acquisitions:
Accounts receivable, unbilled revenues and other receivables		(28,872	)		(7,932	)
Fuel, materials and supplies		6,842			5,425
Special deposits and prepayments		(5,100	)		(4,407	)
Income and other taxes		5,657			17
Accounts payable		(3,369	)		(2,144	)
Accrued interest		2,944			997
Customer advances		(12,587	)		(5,212	)
Pension plan contribution		(26,165	)		(28,165	)
Revenue decoupling mechanism collected (refunded)		1,485			(1,310	)
Regulatory asset - storm deferral		(2,813	)		(3,042	)
Regulatory asset - manufactured gas plant ("MGP") site remediation		(2,214	)		951
Regulatory asset - Temporary State Assessment		(2,526	)		(3,332	)
Deferred natural gas and electric costs		(4,376	)		7,883
Other - net		14,231			4,500
Net cash (used in) provided by operating activities		(4,935	)		12,611
Investing Activities:
Proceeds from sale of assets		26			96
Additions to utility and other property and plant		(28,478	)		(25,887	)
Other - net		38			(637	)
Net cash used in investing activities		(28,414	)		(26,428	)
Financing Activities:
Redemption of long-term debt		-			(36,000	)
Proceeds from issuance of long-term debt		-			48,000
Borrowings of short-term debt - net		36,500			64,500
Dividends paid on Common Stock		(8,301	)		(8,269	)
Redemption of Preferred Stock		(9,625	)		-
Dividends paid on Preferred Stock of subsidiary		(92	)		(242	)
Shares repurchased		-			(2,993	)
Other - net		(95	)		(593	)
Net cash provided by financing activities		18,387			64,403
Net Change in Cash and Cash Equivalents		(14,962	)		50,586
Cash and Cash Equivalents at Beginning of Period		30,508			15,281
Cash and Cash Equivalents at End of Period	$	15,546		$	65,867
Supplemental Disclosure of Cash Flow Information:
Interest paid	$	3,667		$	5,351
Federal and state income taxes paid	$	-		$	16
Additions to plant included in liabilities	$	3,783		$	4,126

The Notes to Financial Statements are an integral part hereof.

-3-

CH ENERGY GROUP CONSOLIDATED BALANCE SHEET (UNAUDITED)

(In Thousands)

	March 31,		December 31,		March 31,
	2013		2012		2012
ASSETS
Utility Plant
Electric	$	1,074,858	$	1,067,352	$	1,017,986
Natural gas		326,061		320,258		301,609
Common		163,993		162,352		151,086
Gross Utility Plant		1,564,912		1,549,962		1,470,681
Less: Accumulated depreciation		420,696		414,137		400,894
Net		1,144,216		1,135,825		1,069,787
Construction work in progress		61,367		58,053		66,518
Net Utility Plant		1,205,583		1,193,878		1,136,305
Non-Utility Property & Plant
Griffith non-utility property & plant		33,808		33,574		31,456
Other non-utility property & plant		524		524		524
Gross Non-Utility Property & Plant		34,332		34,098		31,980
Less:  Accumulated depreciation - Griffith		23,223		23,001		22,220
Net Non-Utility Property & Plant		11,109		11,097		9,760
Current Assets
Cash and cash equivalents		15,546		30,508		65,867
Accounts receivable from customers - net of allowance for doubtful accounts of $6.0 million, $6.5 million and $7.0 million, respectively		120,237		91,457		96,574
Accrued unbilled utility revenues		16,428		17,155		14,283
Other receivables		8,331		9,582		9,096
Fuel, materials and supplies		17,654		24,496		19,689
Regulatory assets		35,165		32,329		49,683
Fair value of derivative instruments		2,944		121		9
Unamortized debt expense		428		344		407
Special deposits and prepayments		26,559		21,362		25,777
Accumulated deferred income tax		8,182		12,205		8,456
Total Current Assets		251,474		239,559		289,841
Deferred Charges and Other Assets
Regulatory assets - pension plan		140,349		146,935		151,737
Regulatory assets - other		109,710		109,779		119,559
Fair value of derivative instruments		2,881		693		-
Goodwill		38,981		38,981		37,752
Other intangible assets - net		11,663		12,324		12,564
Unamortized debt expense		4,682		4,764		4,628
Investments in unconsolidated affiliates		2,241		2,536		2,559
Other investments		18,240		17,847		15,212
Other		5,478		6,556		5,884
Total Deferred Charges and Other Assets		334,225		340,415		349,895
Total Assets	$	1,802,391	$	1,784,949	$	1,785,801

The Notes to Financial Statements are an integral part hereof.

-4-

CH ENERGY GROUP CONSOLIDATED BALANCE SHEET (CONT'D) (UNAUDITED)

(In Thousands, except share amounts)

	March 31,			December 31,			March 31,
	2013			2012			2012
CAPITALIZATION AND LIABILITIES
Capitalization
CH Energy Group Common Shareholders' Equity
Common Stock (30,000,000 shares authorized: $0.10 par value; 16,862,087 shares issued) 14,960,976 shares, 14,954,884 shares and 14,914,853 shares, respectively	$	1,686		$	1,686		$	1,686
Paid-in capital		349,514			349,428			348,306
Retained earnings		257,883			248,103			248,693
Treasury stock - 1,901,111 shares, 1,907,203 shares and 1,947,234 shares, respectively		(89,891	)		(90,141	)		(91,978	)
Accumulated other comprehensive income		368			380			296
Capital stock expense		-			(166	)		(328	)
Total Equity		519,560			509,290			506,675
Preferred Stock of subsidiary		-			9,027			21,027
Long-term debt		479,926			486,926			494,002
Total Capitalization		999,486			1,005,243			1,021,704
Current Liabilities
Current maturities of long-term debt		38,076			31,076			1,006
Notes payable		56,000			19,500			71,000
Accounts payable		39,155			52,812			36,183
Accrued interest		8,875			5,931			7,330
Dividends payable		8,310			8,301			8,521
Accrued vacation and payroll		8,187			7,984			7,291
Customer advances		15,722			28,309			17,315
Customer deposits		7,115			7,135			7,235
Regulatory liabilities		14,568			10,736			8,959
Fair value of derivative instruments		517			1,259			22,118
Accrued environmental remediation costs		4,267			7,117			7,064
Accrued income and other taxes		6,146			635			817
Deferred revenues		3,936			4,801			3,853
Other		21,170			15,105			16,200
Total Current Liabilities		232,044			200,701			214,892
Deferred Credits and Other Liabilities
Regulatory liabilities - OPEB		9,696			7,975			8,974
Regulatory liabilities - other		108,704			97,485			101,535
Operating reserves		3,456			3,827			3,181
Fair value of derivative instruments		93			218			1,688
Accrued environmental remediation costs		8,250			8,324			10,559
Accrued OPEB costs		58,730			58,412			53,757
Accrued pension costs		88,170			113,227			95,896
Tax reserve		2,047			2,000			3,174
Other		21,028			20,643			20,520
Total Deferred Credits and Other Liabilities		300,174			312,111			299,284
Accumulated Deferred Income Tax		270,687			266,894			249,921
Commitments and Contingencies
Total Capitalization and Liabilities	$	1,802,391		$	1,784,949		$	1,785,801

The Notes to Financial Statements are an integral part hereof.

-5-

CH ENERGY GROUP CONSOLIDATED STATEMENT OF EQUITY (UNAUDITED)

(In Thousands, except share amounts)

	CH Energy Group Common Shareholders
	Common Stock				Treasury Stock
	Shares Issued		Amount		Shares (Repurchased) / Issued			Amount			Paid-In Capital			Capital Stock Expense			Retained Earnings			Accumulated Other Comprehensive Income / (Loss)			Non-controlling Interest		Total Equity
Balance at December 31, 2011		16,862,087	$	1,686		(1,967,123	)	$	(92,908	)	$	351,053		$	(328	)	$	242,391		$	354		$	-	$	502,248
Comprehensive income:
Net income																		14,823								14,823
Dividends declared on Preferred Stock of subsidiary																		(242	)							(242	)
Change in fair value:
Investments																					(58	)				(58	)
Dividends declared on common stock																		(8,279	)							(8,279	)
Treasury shares activity - net						19,889			930			(2,747	)													(1,817	)
Balance at March 31, 2012		16,862,087	$	1,686		(1,947,234	)	$	(91,978	)	$	348,306		$	(328	)	$	248,693		$	296		$	-	$	506,675
Balance at December 31, 2012		16,862,087	$	1,686		(1,907,203	)	$	(90,141	)	$	349,428		$	(166	)	$	248,103		$	380		$	-	$	509,290
Comprehensive income:
Net income																		18,946								18,946
Preferred Stock Redemption												(28	)		166			(764	)							(626	)
Dividends declared on Preferred Stock of subsidiary																		(92	)							(92	)
Change in fair value:
Investments																					(12	)				(12	)
Dividends declared on common stock																		(8,310	)							(8,310	)
Treasury shares activity - net						6,092			250			114														364
Balance at March 31, 2013		16,862,087	$	1,686		(1,901,111	)	$	(89,891	)	$	349,514		$	-		$	257,883		$	368		$	-	$	519,560

The Notes to Financial Statements are an integral part hereof.

-6-

CENTRAL HUDSON STATEMENT OF INCOME (UNAUDITED)

(In Thousands)

	Three Months Ended March 31,
	2013		2012
Operating Revenues
Electric	$	138,163	$	129,272
Natural gas		56,300		55,850
Total Operating Revenues		194,463		185,122
Operating Expenses
Operation:
Purchased electricity and fuel used in electric generation		50,409		45,059
Purchased natural gas		23,399		24,614
Other expenses of operation		66,792		59,886
Depreciation and amortization		9,955		9,468
Taxes, other than income tax		14,750		13,491
Total Operating Expenses		165,305		152,518
Operating Income		29,158		32,604
Other Income and Deductions
Interest on regulatory assets and other interest income		1,373		1,706
Regulatory adjustments for interest costs		324		319
Other - net		99		112
Total Other Income		1,796		2,137
Interest Charges
Interest on long-term debt		5,956		5,728
Interest on regulatory liabilities and other interest		1,845		1,527
Total Interest Charges		7,801		7,255
Income Before Income Taxes		23,153		27,486
Income Taxes		8,784		10,753
Net Income		14,369		16,733
Preferred Stock Redemption Premium		764		-
Dividends Declared on Cumulative Preferred Stock		92		242
Income Available for Common Stock	$	13,513	$	16,491

CENTRAL HUDSON STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

(In Thousands)

	Three Months Ended March 31,
	2013		2012
Net Income	$	14,369	$	16,733
Other Comprehensive Income		-		-
Comprehensive Income	$	14,369	$	16,733

The Notes to Financial Statements are an integral part hereof.

-7-

CENTRAL HUDSON STATEMENT OF CASH FLOWS (UNAUDITED)

(In Thousands)

	Three Months Ended March 31,
	2013			2012
Operating Activities:
Net income	$	14,369		$	16,733
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation		9,369			8,977
Amortization		586			491
Deferred income taxes - net		3,466			12,071
Bad debt expense		589			2,125
Pension expense		6,022			7,233
OPEB expense		1,989			1,996
Regulatory liability - rate moderation		-			(1,033	)
Revenue decoupling mechanism recorded		4,203			(950	)
Regulatory asset amortization		1,682			1,722
Regulatory asset storm deferral adjustment		4,000			-
Changes in operating assets and liabilities - net:
Accounts receivable, unbilled revenues and other receivables		(17,846	)		(7,437	)
Fuel, materials and supplies		5,069			4,648
Special deposits and prepayments		(3,926	)		(3,203	)
Income and other taxes		5,492			(942	)
Accounts payable		(5,075	)		(2,855	)
Accrued interest		2,466			504
Customer advances		(7,841	)		(3,374	)
Pension plan contribution		(26,165	)		(28,165	)
Revenue decoupling mechanism collected (refunded)		1,485			(1,310	)
Regulatory asset - storm deferral		(2,813	)		(3,042	)
Regulatory asset - MGP site remediation		(2,214	)		951
Regulatory asset - Temporary State Assessment		(2,526	)		(3,332	)
Deferred natural gas and electric costs		(4,376	)		7,883
Other - net		10,909			1,478
Net cash (used in) provided by operating activities		(1,086	)		11,169
Investing Activities:
Additions to utility plant		(27,890	)		(25,783	)
Other - net		(408	)		(777	)
Net cash used in investing activities		(28,298	)		(26,560	)
Financing Activities:
Redemption of long-term debt		-			(36,000	)
Proceeds from issuance of long-term debt		-			48,000
Borrowings of short-term debt - net		27,000			57,500
Redemption of Preferred Stock		(9,653	)		-
Dividends paid to parent - CH Energy Group		(5,000	)		-
Dividends paid on cumulative Preferred Stock		(92	)		(242	)
Other - net		(108	)		(602	)
Net cash provided by financing activities		12,147			68,656
Net Change in Cash and Cash Equivalents		(17,237	)		53,265
Cash and Cash Equivalents - Beginning of Period		24,352			2,521
Cash and Cash Equivalents - End of Period	$	7,115		$	55,786
Supplemental Disclosure of Cash Flow Information:
Interest paid	$	3,601		$	5,312
Federal and state income taxes paid	$	-		$	-
Additions to plant included in liabilities	$	3,783		$	4,126

The Notes to Financial Statements are an integral part hereof.

-8-

CENTRAL HUDSON BALANCE SHEET (UNAUDITED)

(In Thousands)

	March 31,		December 31,		March 31,
	2013		2012		2012
ASSETS
Utility Plant
Electric	$	1,074,858	$	1,067,352	$	1,017,986
Natural gas		326,061		320,258		301,609
Common		163,993		162,352		151,086
Gross Utility Plant		1,564,912		1,549,962		1,470,681
Less: Accumulated depreciation		420,696		414,137		400,894
Net		1,144,216		1,135,825		1,069,787
Construction work in progress		61,367		58,053		66,518
Net Utility Plant		1,205,583		1,193,878		1,136,305
Non-Utility Property and Plant		524		524		524
Net Non-Utility Property and Plant		524		524		524
Current Assets
Cash and cash equivalents		7,115		24,352		55,786
Accounts receivable from customers - net of allowance for doubtful accounts of $4.2 million, $4.6 million and $5.4 million, respectively		77,609		60,155		65,922
Accrued unbilled utility revenues		16,428		17,155		14,283
Other receivables		4,630		5,206		6,086
Fuel, materials and supplies - at average cost		14,194		19,264		16,389
Regulatory assets		35,165		32,329		49,683
Fair value of derivative instruments		2,941		95		-
Unamortized debt expense		428		344		407
Special deposits and prepayments		22,496		18,473		21,311
Accumulated deferred income tax		1,256		5,313		2,019
Total Current Assets		182,262		182,686		231,886
Deferred Charges and Other Assets
Regulatory assets - pension plan		140,349		146,935		151,737
Regulatory assets - other		109,710		109,779		119,559
Fair value of derivative instruments		2,881		693		-
Unamortized debt expense		4,682		4,764		4,628
Other investments		17,743		17,368		14,745
Other		2,734		3,740		2,218
Total Deferred Charges and Other Assets		278,099		283,279		292,887
Total Assets	$	1,666,468	$	1,660,367	$	1,661,602

The Notes to Financial Statements are an integral part hereof.

-9-

CENTRAL HUDSON BALANCE SHEET (CONT'D) (UNAUDITED)

(In Thousands, except share amounts)

	March 31,			December 31,			March 31,
	2013			2012			2012
CAPITALIZATION AND LIABILITIES
Capitalization
Common Stock (30,000,000 shares authorized: $5 par value; 16,862,087 shares issued and outstanding)	$	84,311		$	84,311		$	84,311
Paid-in capital		199,952			199,980			199,980
Retained earnings		198,682			190,169			182,456
Capital stock expense		(4,633	)		(4,799	)		(4,961	)
Total Equity		478,312			469,661			461,786
Cumulative Preferred Stock not subject to mandatory redemption		-			9,027			21,027
Long-term debt		452,950			459,950			465,950
Total Capitalization		931,262			938,638			948,763
Current Liabilities
Current maturities of long-term debt		37,000			30,000			-
Notes payable		27,000			-			59,000
Accounts payable		29,639			45,002			27,299
Accrued interest		8,249			5,782			6,686
Dividends payable - Preferred Stock		-			-			242
Accrued vacation and payroll		6,424			6,708			5,671
Customer advances		10,243			18,084			11,231
Customer deposits		7,042			7,069			7,170
Regulatory liabilities		14,568			10,736			8,959
Fair value of derivative instruments		517			1,259			22,118
Accrued environmental remediation costs		3,838			6,660			6,562
Accrued income and other taxes		8,635			3,142			1,564
Other		14,549			12,095			10,764
Total Current Liabilities		167,704			146,537			167,266
Deferred Credits and Other Liabilities
Regulatory liabilities - OPEB		9,696			7,975			8,974
Regulatory liabilities - other		108,704			97,485			101,535
Operating reserves		2,647			2,696			2,148
Fair value of derivative instruments		93			218			1,688
Accrued environmental remediation costs		7,240			7,293			9,407
Accrued OPEB costs		58,730			58,412			53,757
Accrued pension costs		88,170			113,227			95,896
Tax reserve		2,047			2,000			3,174
Other		20,071			19,705			19,564
Total Deferred Credits and Other Liabilities		297,398			309,011			296,143
Accumulated Deferred Income Tax		270,104			266,181			249,430
Commitments and Contingencies
Total Capitalization and Liabilities	$	1,666,468		$	1,660,367		$	1,661,602

The Notes to Financial Statements are an integral part hereof.

-10-

CENTRAL HUDSON STATEMENT OF EQUITY (UNAUDITED)

(In Thousands, except share amounts)

	Central Hudson Common Shareholders
	Common Stock				Treasury Stock
	Shares Issued		Amount		Shares Repurchased		Amount		Paid-In Capital			Capital Stock Expense			Retained Earnings			Accumulated Other Comprehensive Income / (Loss)		Total Equity
Balance at December 31, 2011		16,862,087	$	84,311		-	$	-	$	199,980		$	(4,961	)	$	165,965		$	-	$	445,295
Net income																16,733					16,733
Dividends declared:
On cumulative Preferred Stock																(242	)				(242	)
Balance at March 31, 2012		16,862,087	$	84,311		-	$	-	$	199,980		$	(4,961	)	$	182,456		$	-	$	461,786
Balance at December 31, 2012		16,862,087	$	84,311		-	$	-	$	199,980		$	(4,799	)	$	190,169		$	-	$	469,661
Net income																14,369					14,369
Preferred Stock Redemption										(28	)		166			(764	)				(626	)
Dividends declared:
On cumulative Preferred Stock																(92	)				(92	)
On Common Stock to parent - CH Energy Group																(5,000	)				(5,000	)
Balance at March 31, 2013		16,862,087	$	84,311		-	$	-	$	199,952		$	(4,633	)	$	198,682		$	-	$	478,312

The Notes to Financial Statements are an integral part hereof.

-11-

NOTES TO FINANCIAL STATEMENTS (UNAUDITED)

NOTE 1 – Summary of Significant Accounting Policies

The Financial Statements were prepared in conformity with accounting principles generally accepted in the United States of America ("GAAP"), which for regulated public utilities, includes specific accounting guidance for regulated operations.  For additional information regarding regulatory accounting, see Note 2 – "Regulatory Matters."

Pending Acquisition by Fortis Inc.

On February 21, 2012, CH Energy Group announced that it had entered into an agreement and plan of merger under which it agreed, subject to shareholder approval and the approval of applicable regulatory authorities, to be acquired by Fortis Inc. ("Fortis") for $65 per share of common stock in cash.  On June 19, 2012, shareholders of CH Energy Group approved the proposed acquisition of the Company by Fortis.  On July 3, 2012, the Federal Energy Regulatory Commission ("FERC") approved the acquisition of CH Energy Group by Fortis.  On July 17, 2012, the Committee on Foreign Investment in the United States approved the acquisition of CH Energy Group by Fortis.  On October 2, 2012, the Federal Trade Commission permitted the 30-day waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 with respect to the acquisition of the Company by Fortis to expire.  On April 20, 2012, CH Energy Group, Central Hudson, Fortis, FortisUS Inc. ("FortisUS"), and Cascade Acquisition Sub Inc. ("Petitioners"), submitted a joint petition to the New York State Public Service Commission ("PSC" or "Commission") for approval of the proposed transaction under Section 70 of the Public Service Law.  Pursuant to a procedure schedule established by the Administrative Law Judges, the PSC Staff and other parties to the proceeding filed testimony and comments on October 12, 2012.  On January 25, 2013, a Joint Proposal with the Company, Fortis, PSC Staff, Multiple Intervenors, the Department of State Utility Intervention Unit, and Dutchess, Orange and Ulster counties as signatories, was submitted to the PSC.  The signatory parties have concluded that, based on the terms of the Joint Proposal, the acquisition is in the public interest pursuant to New York State Public Service Law, Section 70, and recommend approval by the Commission.  The deadline for submission of public comments in the proceeding was extended to May 1, 2013 by the Commission in a notice issued March 22, 2013.  On April 24, 2013, the Commission issued a notice stating that the Administrative Law Judges ("ALJs") assigned to this matter would prepare a Recommended Decision ("RD") for the Commission.  On May 3, 2013 the Recommended Decision of the two Administrative Law Judges – an advisory document – was issued by the PSC.  The RD states that, in its current form, the Joint Proposal does not meet the public interest test as required by New York State Public Service Law, Section 70, but also states that the ALJs recommend the Commission consider adopting the Joint Proposal subject to modifications that would alter the transaction's balance of risks and benefits.  Briefs on exceptions to the RD are due May 17, 2013 and briefs opposing exceptions are due on May 24, 2013.  While no assurance regarding the closing can be given until a final PSC Order is issued, the Company continues to anticipate that the Commission will review and approve the merger in the second quarter of 2013.  Under the terms of the merger agreement, Fortis must close the transaction if all conditions precedent are met, including PSC approval, and a material adverse effect has not occurred.  Closing of the transaction would follow shortly after issuance of the final PSC Order approving the merger.  Management believes this will occur in the second quarter of 2013.

Unaudited Financial Statements

The accompanying Consolidated Financial Statements of CH Energy Group and Financial Statements of Central Hudson are unaudited but, in the opinion of management, reflect adjustments (which include normal recurring adjustments) necessary for a fair statement of the results for the interim periods presented.  These unaudited quarterly Financial Statements do not contain all footnote disclosures concerning accounting policies and other matters which would be included in annual Financial Statements and, accordingly, should be read in conjunction with the audited Financial Statements (including the Notes thereto) included in the combined CH Energy Group/Central Hudson Annual Report on Form 10-K for the year ended December 31, 2012 (the "Corporations' 10-K Annual Report").

-12-

CH Energy Group's and Central Hudson's balance sheets as of March 31, 2012 are not required to be included in this Quarterly Report on Form 10-Q; however, these balance sheets are included for supplemental analysis purposes.

Reclassification

Certain amounts in the 2012 Financial Statements have been reclassified to conform to the 2013 presentation.

The Company reclassified amounts related to in-process work for cost of removal of plant assets from accumulated depreciation to deferred costs, regulatory liabilities. This reclassification resulted in a reduction to the March 31, 2012 balance of $10.6 million.

Revenue Recognition

CH Energy Group's deferred revenue balances as of March 31, 2013, December 31, 2012 and March 31, 2012 were $3.9 million, $4.8 million and $3.9 million, respectively.  The deferred revenue balance will be recognized in CH Energy Group's operating revenues over the 12-month term of the respective customer contract.

As required by the PSC, Central Hudson records gross receipts tax revenues and expenses on a gross income statement presentation basis (i.e., included in both revenue and expenses).  Sales and use taxes for both Central Hudson and Griffith are accounted for on a net basis (excluded from revenue).

Fuel, Materials & Supplies

The following is a summary of CH Energy Group's and Central Hudson's inventories (In Thousands):

	CH Energy Group						Central Hudson
	March 31,		December 31,		March 31,		March 31,		December 31,		March 31,
	2013		2012		2012		2013		2012		2012
Natural gas	$	2,759	$	7,638	$	7,322	$	2,759	$	7,638	$	7,322
Petroleum products and propane		2,098		3,942		2,115		-		-		-
Fuel used in electric generation		293		295		286		293		295		286
Materials and supplies		12,504		12,621		9,966		11,142		11,331		8,781
Total	$	17,654	$	24,496	$	19,689	$	14,194	$	19,264	$	16,389

-13-

Depreciation and Amortization

Current accounting guidance related to asset retirements precludes the recognition of expected future retirement obligations as a component of depreciation expense or accumulated depreciation.  Central Hudson, however, is required to use depreciation methods and rates approved by the PSC under regulatory accounting.  These depreciation rates include a charge for the cost of future removal and retirement of fixed assets.  In accordance with current accounting guidance for regulated operations, Central Hudson continues to accrue for the future cost of removal for its rate-regulated natural gas and electric utility assets.  In accordance with current accounting guidance related to asset retirements, Central Hudson has classified $44.8 million, $43.4 million, and $42.7 million of cost of removal as regulatory liabilities as of March 31, 2013, December 31, 2012, and March 31, 2012, respectively.  This liability represents the portion of the cost of removal charge in excess of the amount reported as an Asset Retirement Obligation under GAAP.

See Note 6 - "Goodwill and Other Intangible Assets" for further discussion of amortization of intangibles (other than goodwill).

Earnings Per Share

In the calculation of earnings per share (basic and diluted) of CH Energy Group's Common Stock, earnings for CH Energy Group are reduced by the Preferred Stock dividends of Central Hudson.

The average dilutive effect of CH Energy Group's stock options, performance shares and restricted shares are as follows:

	Three Months Ended
	March 31,
	2013		2012
Shares		213,908		260,259

Certain stock options can be excluded from the calculation of diluted earnings per share because the exercise prices of those options were greater than the average market price per share of Common Stock.  As of December 31, 2012, no stock options are outstanding.  There were no options excluded during the three months ended March 31, 2012.

-14-

Parental Guarantees

CH Energy Group and CHEC have issued guaranteesto counterparties to assure the payment, when due, of certain obligations incurred by CH Energy Group subsidiaries, in physical and financial transactions.

	March 31, 2013
Transaction Description	Maximum Potential Payments		Outstanding Liabilities(1)
Heating oil, propane, other petroleum products, weather and commodity hedges (In Thousands)	$	30,650	$	8,555

(1) Balance included in CH Energy Group's Consolidated Balance Sheet.

Management is not aware of any existing condition that would require payment under the guarantees.

Common Stock Dividends

On March 27, 2013, the Board of Directors of CH Energy Group declared a quarterly dividend of 55.5 cents per share payable May 1, 2013, to shareholders of record as of April 10, 2013.

CH Energy Group's ability to pay dividends is affected by the ability of its subsidiaries to pay dividends.  The Federal Power Act limits the payment of dividends by Central Hudson to its retained earnings.  More restrictive is the PSC's limit on the dividends Central Hudson may pay to CH Energy Group which is 100% of the average annual income available for common stock, calculated on a two-year rolling average basis.  Based on this calculation, Central Hudson was restricted to a maximum payment of $45.1 million in dividends to CH Energy Group for the year ended December 31, 2012.  Central Hudson's dividend would be reduced to 75% of its average annual income in the event of a downgrade of its senior debt rating below "BBB+" by more than one rating agency if the stated reason for the downgrade is related to any of CH Energy Group's or Central Hudson's affiliates.  Further restrictions are imposed for any downgrades below this level.  During the three months ended March 31, 2013, Central Hudson had declared and paid dividends of $5.0 million to parent CH Energy Group.  CH Energy Group's other subsidiaries do not have express restrictions on their ability to pay dividends.

-15-

NOTE 2 – Regulatory Matters

Summary of Regulatory Assets and Liabilities

The following table sets forth Central Hudson's regulatory assets and liabilities (In Thousands):

	March 31,		December 31,		March 31,
	2013		2012		2012
Regulatory Assets (Debits):
Current:
Deferred purchased electric and natural gas costs (Note 1)	$	15,743	$	11,367	$	2,892
Deferred unrealized losses on derivatives (Note 14)		517		1,259		22,118
PSC General and Temporary State Assessment and carrying charges		8,854		6,260		11,547
RDM and carrying charges		-		3,393		3,068
Residual natural gas deferred balances		4,554		4,554		4,554
Deferred debt expense on re-acquired debt		601		601		628
Deferred and accrued costs - MGP site remediation and carrying charges (Note 12)		4,605		4,605		4,586
Other		291		290		290
		35,165		32,329		49,683
Long-term:
Deferred pension costs (Note 10)		140,349		146,935		151,737
Deferred unrealized losses on derivatives (Note 14)		93		218		1,688
Carrying charges - pension reserve		10,303		9,182		6,158
Deferred and accrued costs - MGP site remediation and carrying charges (Note 12)		10,109		10,739		13,459
Deferred debt expense on re-acquired debt		4,586		4,737		5,172
Deferred Medicare Subsidy taxes		7,933		7,808		7,450
Residual natural gas deferred balances and carrying charges		3,809		5,443		8,168
Income taxes recoverable through future rates		37,119		29,908		47,820
Energy efficiency incentives		2,719		2,719		2,719
Deferred storm costs and carrying charges		19,717		23,274		15,178
Other		13,322		15,751		11,747
		250,059		256,714		271,296
Total Regulatory Assets	$	285,224	$	289,043	$	320,979
Regulatory Liabilities (Credits):
Current:
Excess electric depreciation reserve	$	-	$	-	$	74
RDM and carrying charges		2,330		-		-
Deferred unrealized gains on derivatives (Note 14)		2,941		95		-
Income taxes refundable through future rates		4,431		4,669		5,120
Deferred unbilled gas revenues		4,866		5,972		3,765
		14,568		10,736		8,959
Long-term:
Customer benefit fund		2,419		2,390		2,566
Deferred cost of removal (Note 1)		44,795		43,392		42,748
Rate Base impact of tax repair project and carrying charges		9,159		9,099		8,083
Excess electric depreciation reserve carrying charges		1,586		1,586		2,688
Deferred unrealized gains on derivatives (Note 14)		2,881		693		-
Income taxes refundable through future rates		24,194		21,062		33,769
Deferred OPEB costs		9,696		7,975		8,974
Carrying charges - OPEB reserve		11,222		9,949		6,482
Other		12,448		9,314		5,199
		118,400		105,460		110,509
Total Regulatory Liabilities	$	132,968	$	116,196	$	119,468
Net Regulatory Assets	$	152,256	$	172,847	$	201,511

-16-

2010 Rate Order

From July 1, 2010 through June 30, 2013, Central Hudson is operating under the terms of the 2010 Rate Order, which provides for the following:

Description	2010 Rate Order
Electric delivery revenue increases	$11.8 million(1) 7/1/10 $9.3 million(1)  7/1/11 $9.1 million 7/1/12
Natural gas delivery revenue increases	$5.7 million 7/1/10 $2.4 million 7/1/11 $1.6 million 7/1/12
ROE	10.0%
Earnings sharing	Yes(2)
Capital structure – common equity	48%
Targets with true-up provisions - % of revenue requirement to defer for shortfalls
Net plant balances	100%
Transmission and distribution ROW maintenance	100%
RDMs – electric and natural gas(3)	Yes
New deferral accounting for full recovery
Fixed debt costs	Yes(4)
Transmission sag mitigation	Yes
New York State Temporary Assessment	Yes
Material regulatory actions(5)	Yes(5)
Property taxes – Deferral for 90% of excess/deficiency relative to revenue requirement	Yes(6)

(1) Moderated by $12 million and $4 million bill credits, respectively.

(2) ROE > 10.5%, 50% to customers, > 11.0%, 80% to customers, > 11.5%, 90% to customers.

(3) Electric is based on revenue dollars; gas is based on usage per customer.

(4) Deferral authorization in RY2 and RY3 only.

(5) Legislative, governmental or regulatory actions with individual impacts greater than or equal to 2% of net income of the applicable department.

(6) The Company's pre-tax gain or loss limited to $0.7 million per rate year.

Other PSC Proceedings

On April 20, 2012, CH Energy Group, Central Hudson, Fortis, FortisUS, and Cascade Acquisition Sub Inc., submitted a joint petition to the PSC for approval of the acquisition of CH Energy Group by Fortis and related transactions.  The petition describes how the acquisition of Central Hudson by Fortis will produce benefits for constituencies that include customers, employees and communities in Central Hudson's service territory as well as positive public benefits.  The petition categorizes the public benefits into three major areas: 1) FortisUS' commitments and intention to preserve and build on the existing strength of Central Hudson, 2) mitigation of any potential negative aspects of the merger consistent with the PSC's disposition of specific issues that have arisen in prior utility merger proceedings in New York State and 3) identifiable monetary benefits resulting from assignment of costs to shareholders and cost savings made possible by the merger.  The petition includes proposals and commitments that effectively mitigate any potential risks to Central Hudson's customers from foreign holding company ownership and excess rate risk.  On January 25, 2013, a Joint Proposal with the Company, Fortis, PSC Staff, Multiple Intervenors, the Department of State Utility Intervention Unit, and Dutchess, Orange and Ulster counties as signatories, was submitted to the PSC.  The signatory parties have concluded that, based on the terms of the Joint Proposal, the acquisition is in the public interest pursuant to the New York State Public Service Law, Section 70, and recommended approval by the Commission.  On May 3, 2013 the Recommended Decision of the two Administrative Law Judges – an advisory document – was issued by the PSC.  The RD states that, in its current form, the Joint Proposal does not meet the public interest test as required by New York State Public Service Law, Section 70, but also states that the ALJs recommend the Commission consider adopting the Joint Proposal subject to modifications that would alter the transaction's balance of risks and benefits.  Briefs on exceptions to the RD are due May 17, 2013 and briefs opposing exceptions are due on May 24, 2013.  While no assurance regarding the closing can be given until a PSC Order is issued by the Commission, a decision from the PSC regarding the Joint Proposal and a subsequent closing is expected in the second quarter of 2013.See Item 7 - "Management's Discussion and Analysis of Financial Condition and Results of Operations" under the caption "Regulatory Matters – PSC Proceedings" for further discussion regarding the terms of the Joint Proposal and schedule.

-17-

On October 29, 2012, Central Hudson's service territory was impacted by Superstorm Sandy, and approximately 103,000 electric customers were affected.  The Sandy storm costs were included in the estimate of $22 million storm costs identified in the $35 million of regulatory liabilities to be funded by Fortis. Consistent with the Joint Proposal, on February 6, 2013, Central Hudson filed a petition with the PSC seeking expedited Commission approval to recover $9.7 million of incremental electric storm restoration expense, with carrying charges. These storm costs represent the amount Central Hudson deferred on its books as of December 31, 2012 based on actual costs incurred, bills received and an estimate for bills outstanding and are above the respective rate allowance during the twelve months ended June 30, 2013, which is the third rate year established by the PSC in its approval of a Joint Proposal in Case 09-E-0588. The Company believes the incremental costs associated with this storm meet the PSC's criteria for deferral: 1) the amount is incremental to the amount in rates; 2) the incremental amount is material and extraordinary in nature and 3) the utility's earnings are below the authorized rate of return on common equity.  As of March 31, 2013, the deferred balance related to this storm event was $9.8 million.

On October 29, 2011, Central Hudson experienced an unusual fall storm with snow accumulations of up to 20 inches in the service territory, resulting in electric service outages to over 150,000 customers, extensive damage to the electric system and significant restoration costs.  Following Tropical Storm Irene, the October snowstorm represented the second extraordinary storm event that occurred within the rate year.  Central Hudson filed a petition with the PSC to defer for future recovery with carrying charges the $8.6 million of total incremental electric storm restoration expense.  However, because the petition requested the PSC to deviate from its prior precedents, the Company was aware that the amount the PSC granted could have been lower.  Accordingly, management deferred only the portion of the incremental costs that strictly follows Commission practice used in the Company's previous requests to defer incremental storm costs.  Approximately $3.7 million and $3.3 million of incremental restoration expense associated with this storm was expensed in 2011 and 2012, respectively, so that the return on common equity for the twelve months ending June 30, 2012 did not exceed the authorized rate of return of 10%.

-18-

In late August 2011, Central Hudson's service territory was affected by Tropical Storm Irene, disrupting service to approximately 180,000 customers.  On November 28, 2011 Central Hudson filed a petition with the PSC seeking to defer for future recovery with carrying charges for the estimated $11.4 million of incremental electric storm restoration expense above the respective rate allowance during the twelve months ended June 30, 2012.  The Company believes the incremental costs associated with this storm meet the PSC's criteria for deferral.

On April 22, 2013, the Commission issued Orders approving deferral of $8.9 million and denying deferral of $3.7 million of the incremental electric storm restoration expense related to Tropical Storm Irene and the October snowstorm.  Regarding the majority of the disallowed costs, the PSC's decision stated that the Company did not meet the third prong requirement which requires the Company not be in an over earnings position.  The Commission adopted a staff recommendation to exclude ratemaking normalization adjustments for purposes of calculating authorized electric regulatory earnings, and therefore denied a portion of these petitioned deferrals based on this third prong criterion.  In addition, the PSC's Order stated that approximately $0.6 million of the costs related to Tropical Storm Irene should have been allocated to a separate storm, Tropical Storm Lee, and that this separate amount did not meet the materiality threshold for recovery.  Central Hudson expects to file a petition for reconsideration and rehearing on the PSC's April 22, 2013 Orders challenging the exclusion of the Company's normalization adjustments used to measure earnings.  The petition will seek rehearing for reconsideration and recovery of $3.7 million of costs denied by the Commission for deferral accounting treatment.  The Company believes that it is entitled to fully recover all of these incremental electric storm restoration expenses; however Central Hudson cannot predict the final outcome of this proceeding.

-19-

NOTE 3 - New Accounting Guidance

Newly adopted and soon to be adopted accounting guidance is summarized below, including explanations for any new guidance issued in 2013 (except that which is not currently applicable) and the expected impact on CH Energy Group and its subsidiaries.

Impact	Category	Accounting Reference	Title	Issued Date	Effective Date
1	Balance Sheet (Topic 210)	ASU No. 2011-11	Disclosures about Offsetting Assets and Liabilities	Dec-11	Jan-13
1	Balance Sheet (Topic 210)	ASU No. 2013-01	Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities	Jan-13	Jan-13
1	Comprehensive Income (Topic 220)	ASU No. 2013-02	Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income	Feb-13	Dec-12
2	Liabilities (Topic 405)	ASU No. 2013-04	Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date	Feb-13	Dec-13

Impact Key:
(1)	No current impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries when adopted on the effective date noted.  Additional disclosures have been added or presentation of information modified where required.
(2)	No anticipated impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries upon future adoption.

-20-

NOTE 4 – Income Tax

In September of 2010, Central Hudson filed a request with the Internal Revenue Service ("IRS") to change the Company's tax accounting method related to costs to repair and maintain utility assets.  The change was effective for the tax year ending December 31, 2009.  This change allows Central Hudson to take a current tax deduction for a significant amount of repair costs that were previously capitalized for tax purposes.

In September 2012, Central Hudson filed corporate income tax returns for the year ended December 31, 2011.  With that filing, the Company included an election to adopt the provisions of Revenue Procedure 2011-43 ("Rev Proc"), which provided IRS guidance related to the repair deduction previously taken on electric transmission and distribution property. Adoption of the provisions of the Rev Proc resulted in reduced federal and state net operating income tax loss ("NOL") carryforwards. The Company believes the remaining electric repair deduction meets and complies with the requirements included in the Rev Proc. As such, tax reserves related to the electric transmission and distribution repair deductions have been reclassified to deferred tax liability accounts.

IRS guidance with respect to repairs taken on Gas Transmission and Distribution repairs is still pending. Therefore, remaining reserves related to the gas repair deduction continue to be shown as "Tax Reserve" under the Deferred Credits and Other Liabilities section of the Central Hudson Balance Sheet.

Other than the uncertain tax position related to the Company's accounting method change for gas transmission and distribution repairs, there are no other uncertain tax positions.  The following is a summary of activity related to uncertain tax positions (In Thousands):

	Three Months Ended March 31,
	2013		2012
Balance at the beginning of the period	$	2,000	$	3,172
Adjustments related to tax accounting method change		47		2
Balance at the end of the period	$	2,047	$	3,174

Jurisdiction	Tax Years Open for Audit
Federal(1)	2007 - 2012
New York State	2009 - 2012

(1)   Federal tax filings for the years 2007 - 2011 are currently under audit.

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Reconciliation - CH Energy Group

The following is a reconciliation between the amount of federal income tax computed on income before taxes at the statutory rate and the amount reported in CH Energy Group's Consolidated Statement of Income (In Thousands):

	Three Months Ended March 31,
	2013			2012
Net income attributable to CH Energy Group	$	18,090		$	14,581
Preferred Stock dividends of Central Hudson		92			242
Preferred Stock Redemption Premium		764			-
Federal income tax		7,465			-
State income tax		544			408
Deferred federal income tax		2,833			10,452
Deferred state income tax		323			809
Income before taxes	$	30,111		$	26,492
Computed federal tax at 35% statutory rate	$	10,539		$	9,272
State income tax net of federal tax benefit		879			1,293
Depreciation flow-through		891			797
Cost of Removal		(616	)		(596	)
Merger Transaction Costs		84			1,705
Other		(612	)		(802	)
Total income tax	$	11,165		$	11,669
Effective tax rate - federal		34.2	%		39.4	%
Effective tax rate - state		2.9	%		4.6	%
Effective tax rate - combined		37.1	%		44.0	%

The decrease in the effective tax rate for the three months ended March 31, 2013 as compared to 2012 was primarily driven by the decrease in merger related costs.  Merger related transaction costs that are facilitative in nature are considered nondeductible for tax purposes. Merger related transaction costs incurred for the three months ended March 31, 2013 were $0.2 million and for the three months ended March 31, 2012 were $4.3 million which have been determined to be facilitative and therefore nondeductible.

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Reconciliation - Central Hudson

The following is a reconciliation between the amount of federal income tax computed on income before taxes at the statutory rate and the amount reported in Central Hudson's Statement of Income (In Thousands):

	Three Months Ended March 31,
	2013			2012
Net income	$	14,369		$	16,733
Federal income tax		5,318			-
Deferred federal income tax		2,565			9,320
Deferred state income tax		901			1,433
Income before taxes	$	23,153		$	27,486
Computed federal tax at 35% statutory rate	$	8,104		$	9,620
State income tax net of federal tax benefit		901			1,433
Depreciation flow-through		891			797
Cost of Removal		(616	)		(596	)
Other		(496	)		(501	)
Total income tax	$	8,784		$	10,753
Effective tax rate - federal		34.0	%		33.9	%
Effective tax rate - state		3.9	%		5.2	%
Effective tax rate - combined		37.9	%		39.1	%

NOTE 5 – Acquisitions and Investments

Acquisitions

During the three months ended March 31, 2013, CH Energy Group or Central Hudson made no acquisitions.

Investments

The value of CHEC's investments as of March 31, 2013 is as follows  (In Thousands):

CHEC Investment	Description	Intercompany Debt		Equity Investment		Total
Griffith Energy Services	100% controlling interest in a fuel distribution business	$	40,000	$	40,682	$	80,682
CH-Community Wind	50% equity interest in a joint venture that owns 18% interest in two operating wind projects		-		-		-
Other	Partnerships and an energy sector venture capital fund		-		2,241		2,241
		$	40,000	$	42,923	$	82,923

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The remaining investments identified as CH-Community Wind and Other are not considered a part of the core business; however, management intends to retain these investments at this time.

NOTE 6 – Goodwill and Other Intangible Assets

Goodwill, customer relationships, trademarks and covenants not to compete associated with acquisitions are included in intangible assets.  In accordance with current accounting guidance related to goodwill and other intangible assets, goodwill and other intangible assets that have indefinite useful lives are not amortized, but instead are periodically reviewed for impairment.

In the fourth quarter of 2012, management performed a qualitative assessment of any potential impairment of Griffith's goodwill.  The last quantitative analysis of impairment was performed as of September 30, 2010, which reflected that the fair value of Griffith exceeded its carrying value by approximately $34.2 million.  Additionally, management believes that no event has occurred which would trigger impairment since the last quantitative test performed.  Based on these factors and other factors considered in its qualitative analysis, management believes that it is more likely than not that the fair market value of Griffith is more than the carrying value and, therefore, the first and second steps of the impairment test prescribed in guidance were not necessary.

The components of amortizable intangible assets of CH Energy Group are summarized as follows (In Thousands):

	March 31, 2013				December 31, 2012				March 31, 2012
	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
Customer relationships	$	37,709	$	26,645	$	37,709	$	26,017	$	36,526	$	24,188
Trademarks		318		8		318		-		-		-
Covenants not to compete		411		122		411		97		377		151
Total Amortizable Intangibles	$	38,438	$	26,775	$	38,438	$	26,114	$	36,903	$	24,339

	Three Months Ended March 31,
	2013		2012
Intangibles Amortization Expense (In Thousands)	$	661	$	634

The estimated annual amortization expense for the remainder of the current year and for each of the next four years, assuming no new acquisitions or divestitures, is as follows (In Thousands):

	2013		2014		2015		2016		2017
Estimated Amortization Expense	$	1,984	$	2,636	$	2,374	$	988	$	683

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NOTE 7 – Short-Term Borrowing Arrangements

CH Energy Group and Central Hudson borrowings under its committed and uncommitted short-term borrowing arrangements are as follows (In Thousands):

	March 31, 2013			December 31, 2012			March 31, 2012
CH Energy Group Holding Company Short-term borrowings	$	29,000		$	19,500		$	32,000
Central Hudson Short-term borrowings		27,000			-			59,000
Intercompany Borrowing		-			-			(20,000	)
Total CH Energy Group	$	56,000		$	19,500		$	71,000
Total CH Energy Group Weighted Average Interest Rate		0.97	%		1.08	%		1.12	%

NOTE 8 – Capitalization – Common and Preferred Stock

For a schedule of activity related to common stock, paid-in capital and capital stock, see the Consolidated Statement of Equity for CH Energy Group and Central Hudson.

Effective July 31, 2007, the Board of Directors of CH Energy Group extended and amended the Common Stock Repurchase Program of the Company (the "Repurchase Program"), which was authorized in 2002.  As amended, the Repurchase Program authorized the repurchase of up to 2 million shares (excluding shares purchased before July 31, 2007) or approximately 13% of the CH Energy Group's outstanding Common Stock, from time to time, through July 31, 2012.  In accordance with the merger agreement with Fortis, which prohibited CH Energy Group from repurchasing additional shares subsequent to February 21, 2012, the Repurchase Program was not renewed.  As of December 31, 2012, CH Energy Group had purchased 948,676 shares under the Repurchase Program, which were not retired or cancelled, and the repurchases accordingly have been presented as an increase to treasury stock in CH Energy Group's Consolidated Balance Sheet.

Effective July 1, 2011, employer matching contributions to an eligible employee's Savings Incentive Plan ("SIP") account could be paid in either cash or in CH Energy Group Common Stock, and CH Energy Group initially chose to meet its matching obligation in Common Stock.  Since March 1, 2012, the Company has been contributing cash for all of its matching obligations, except for matching contributions associated with classified employees of Central Hudson.  The classified employees will continue to receive matching contributions in CH Energy Group Common Stock.  As of March 31, 2013, 44,786 shares had been issued from treasury related to employer matching contributions, of which 3,425 shares were issued in 2013.

On March 21, 2013, Central Hudson redeemed its two outstanding series of preferred stock.  Registered holders of 4 1/2% Cumulative Preferred Stock received $107.00 per share plus accrued and unpaid dividends to the redemption date in the amount of $1.00 per share, for a total redemption price of $108.00 per share.  Registered holders of 4.75% Cumulative Preferred Stock received $106.75 per share plus accrued and unpaid dividends to the redemption date in the amount of $1.056 per share, for a total redemption price of $107.806 per share.  The premium paid in connection with the redemption of the preferred stock was recorded as a reduction of Retained Earnings on Central Hudson's Balance Sheet and as Premium on Preferred Stock Redemption on Central Hudson's Income Statement.

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Through March 31, 2013, Central Hudson made $5.0 million of dividend payments in 2013 to parent CH Energy Group.  In the prior year, Central Hudson made no dividend payments to parent CH Energy Group in the three months ended March 31, 2012.

NOTE 9 – Capitalization – Long-Term Debt

NYSERDA

Central Hudson's outstanding Series B NYSERDA Bonds total $33.7 million at March 31, 2013.  These bonds are tax-exempt multi-modal bonds that are currently in a variable rate mode.  In its Orders, the PSC has authorized deferral accounting treatment for variations in the interest costs from these bonds.  As such, variations between the actual interest rates on these bonds and the interest rate included in the current delivery rate structure for these bonds are deferred for future recovery from or refund to customers and therefore do not impact earnings.

To mitigate the potential cash flow impact from unexpected increases in short-term interest rates on Series B NYSERDA Bonds, on March 28, 2012, Central Hudson purchased an interest rate cap based on an index of short-term tax-exempt debt.  The rate cap is two years in length with a notional amount aligned with Series B and will expire on April 1, 2014.  The cap is based on the monthly weighted average of an index of tax-exempt variable rate debt, multiplied by 175%.  Central Hudson would receive a payout if the adjusted index exceeds 5.0% for a given month.  The rate cap replaced an expiring rate cap with substantially similar terms. See Note 14 – "Accounting for Derivative Instruments and Hedging Activities" for fair value disclosures related to this instrument.

Central Hudson is currently evaluating what actions, if any, it may take in the future in connection with its Series B NYSERDA Bonds.  Potential actions may include converting the debt to another interest rate mode or refinancing with taxable bonds.

NOTE 10 – Post-Employment Benefits

Central Hudson provides certain health care and life insurance benefits for retired employees through its post-retirement benefit plans.  Central Hudson pension benefits include a Retirement Income Plan ("RIP") and a non-qualified Supplemental Executive Retirement Plan ("SERP").

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In its Orders, the PSC has authorized deferral accounting treatment for any variations between actual pension and other post-employment benefits ("OPEB") expense and the amount included in the current delivery rate structure.  As a result, post-retirement benefit plans at Central Hudson do not have any impact on earnings.  The following information is provided in accordance with current accounting requirements.

The following are the components of Central Hudson's net periodic benefit costs for its pension and OPEB plans for the three months ended March 31, 2013 and 2012 (In Thousands):

	Pension Benefits						OPEB(1)
	Three Months Ended March 31,						Three Months Ended March 31,
	2013			2012			2013			2012
Service cost	$	3,073		$	2,741		$	760		$	644
Interest cost		5,732			6,177			1,382			1,662
Expected return on plan assets		(7,698	)		(6,768	)		(1,723	)		(1,734	)
Amortization of:
Prior service cost (credit)		433			501			(1,465	)		(1,466	)
Transitional obligation		-			-			2			641
Recognized actuarial loss		4,840			5,788			1,582			2,326
Net Periodic Benefit Cost	$	6,380		$	8,439		$	538		$	2,073

(1) The OPEB amounts for all periods presented reflect the effect of the Medicare Prescription Drug Improvement and Modernization Act of 2003.

The balance of Central Hudson's accrued pension costs (i.e., the under-funded status) is as follows (In Thousands):

	March 31,		December 31,		March 31,
	2013		2012		2012
Accrued pension costs	$	88,828	$	113,885	$	96,547

These balances include the difference between the projected benefit obligation ("PBO") for pensions and the market value of the pension assets, and the liability for the non-qualified Supplemental Executive Retirement Plan ("SERP").

The following reflects the impact of the recording of funding status adjustments on the Balance Sheets of CH Energy Group and Central Hudson (In Thousands):

	March 31,			December 31,			March 31,
	2013			2012			2012
Prefunded pension costs prior to funding status adjustment	$	44,956		$	25,172		$	49,996
Additional liability required		(133,784	)		(139,057	)		(146,543	)
Total accrued pension costs	$	(88,828	)	$	(113,885	)	$	(96,547	)
Total offset to additional liability - Regulatory assets - Pension Plan	$	133,784		$	139,057		$	146,543

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Gains or losses and prior service costs or credits that arise during the period but that are not recognized as components of net periodic pension cost would typically be recognized as a component of other comprehensive income, net of tax.  However, Central Hudson has PSC approval to record regulatory assets rather than adjusting comprehensive income to offset the additional liability.

Contribution levels for the RIP and OPEB plans are determined by various factors including the discount rate, expected return on plan assets, benefit changes, and corporate resources.  In addition, OPEB plan contribution levels are also impacted by medical claims assumptions used and mortality assumptions used.

Contributions for the three months ended March 31, 2013 and 2012 were as follows (In Thousands):

	Retirement Income Plan				OPEB
	Three Months Ended				Three Months Ended
	March 31,				March 31,
	2013		2012		2013		2012
Contributions	$	26,000	$	28,000	$	-	$	-

Retirement Plan Policy and Strategy

Central Hudson's Retirement Plan investment policy seeks to achieve long-term growth and income to match the long-term nature of its funding obligations. Management has transitioned to a liability-driven investment ("LDI") strategy for its pension plan assets.  Management's objective is to reduce the volatility of the plan's funded status and the level of contributions by more closely aligning the characteristics of plan assets with liabilities.

Asset allocation targets in effect for the three months ended March 31, 2013 as well as actual asset allocations as of March 31, 2013 and December 31, 2012 expressed as a percentage of the market value of the Retirement Plan's assets, are summarized in the table below:

Asset Class	December 31, 2012			Minimum			Target Average			Maximum			March 31, 2013
Equity Securities		50.5	%		45	%		50	%		55	%		51.2	%
Debt Securities		47.4	%		45	%		50	%		55	%		47.4	%
Other(1)		2.1	%		-	%		-	%		-	%		1.4	%

(1) Consists of temporary cash investments, as well as receivables for investments sold and interest, and payables for investments purchased, which have not settled as of that date.

The above asset allocations as of December 31, 2012 and March 31, 2013 reflect the transition to a LDI strategy resulting in an asset allocation of approximately 50% equity and 50% long duration fixed income assets. Due to market value fluctuations, RIP assets will require rebalancing from time to time to maintain the asset allocation within target ranges.  Management is currently monitoring ongoing market activity and the impact on the pension plan asset allocations to determine if a rebalancing will be necessary.

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Central Hudson cannot assure that the RIP's return objectives or funded status objectives will be achieved.

NOTE 11 – Equity-Based Compensation

CH Energy Group has adopted the CH Energy Group, Inc. 2011 Long-Term Equity Incentive Plan (the "2011 Plan").  The 2011 Plan reserves for awards to be granted up to a maximum of 400,000 shares of Common Stock plus any shares remaining available under the 2006 Long-Term Equity Incentive Plan (the "2006 Plan") as of April 26, 2011 and any shares that are subject to awards granted under the 2006 Plan that are forfeited, cancelled, surrendered or otherwise terminated without the issuance of shares on or after that date.  Awards may consist of incentive stock options, nonqualified stock options, stock appreciation rights, restricted shares, restricted share units, performance shares, dividend equivalents and other awards that CH Energy Group may authorize. 

The 2011 Plan will continue in effect until February 9, 2021, unless sooner terminated by the Board of Directors.  Termination will not affect grants and awards then outstanding.

In December 2012, the board approved the non-refundable accelerated payment of 80% of earned performance shares for certain executive officers for the February 8, 2010 grant and the acceleration of the vesting of 80% of restricted shares outstanding for certain executive officers issued under the February 10, 2010 grant award.  In accordance with accounting rules, the modification of the restricted share grant is treated as a cancellation of the original award and issue of a new award with the new grant date fair value and incremental expense recognized.  The incremental expense resulting from this modification was not material.

Performance Shares

A summary of the status of outstanding performance shares granted to executives under the 2006 and 2011 Plans are as follows:

Grant Date	Grant Date Fair Value		Performance Shares Granted	Performance Shares Outstanding at March 31, 2013
February 8, 2010	$	38.62	48,740	37,348	(1)
February 7, 2011	$	49.77	40,320	40,320
February 6, 2012	$	58.15	39,440	39,440
February 5, 2013	$	65.02	35,780	35,780

(1) CH Energy Group treasury stock of 613 shares in 2011 and 4,128 in 2012 were issued in satisfaction of the pro-rated payout of an officer who retired in 2011 and the accelerated payment to certain executive officers in 2012, respectively.

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The ultimate number of shares earned under the awards is based on metrics established by the Compensation Committee at the beginning of the award cycle.  Participants may elect to defer receipt of shares earned in accordance with terms and subject to conditions of the Directors and Executives Deferred Compensation Plan.  Ultimate payouts from the Directors and Executives Deferred Compensation Plan are made in the form of cash or shares.  Accordingly, these awards are classified as liabilities and are adjusted to fair value as of the end of each reporting period.

Performance shares granted February 8, 2010 and shown as outstanding as of March 31, 2013 in the table above, were paid out in April 2013.  Those recipients electing not to defer this compensation under the CH Energy Group Directors and Executives Deferred Compensation Plan received shares issued from CH Energy Group's treasury stock totaling 11,354 shares.

Restricted Shares and Restricted Stock Units

The following table summarizes information concerning restricted shares and stock units outstanding as of March 31, 2013:

Grant Date	Type of Award	Shares or Stock Units Granted	Grant Date Fair Value		Vesting Terms	Unvested Shares Outstanding at March 31, 2013
October 1, 2009	Shares	14,375	$	43.86	Ratably over 5 years	5,750
November 20, 2009	Stock Units	13,900	$	41.43	1/3 each year in Years 5, 6 and 7	13,900
February 8, 2010	Shares	3,060	$	38.62	End of 3 years	-	(1)
February 10, 2010	Shares	5,200	$	38.89	End of 3 years	-	(2)
November 15, 2010	Shares	3,000	$	46.53	Ratably over 3 years	1,000
February 7, 2011	Shares	1,500	$	49.77	1/3 each year in Years 3, 4 and 5	1,500
February 7, 2011	Shares	2,230	$	49.77	End of 3 years	2,230
February 6, 2012	Shares	2,170	$	58.15	End of 3 years	2,170
February 5, 2013	Shares	2,035	$	65.02	End of 3 years	2,035

(1)	The vesting of 405 shares was accelerated as approved by the Board of Directors.  The remaining 2,655 shares vested on February 8, 2013.
(2)	The vesting of 3,520 shares was accelerated as approved by the Board of Directors.  The remaining 1,680 shares vested on February 8, 2013.

Compensation Expense

The following table summarizes expense for equity-based compensation by award type for the three months ended March 31, 2013 and 2012 (In Thousands):

	CH Energy Group						Central Hudson
	Three Months Ended March 31,						Three Months Ended March 31,
	2013			2012			2013			2012
Performance shares		$	617		$	1,538		$	502		$	525
Restricted shares and stock units		$	105		$	114		$	72		$	65
Recognized tax benefit of restricted shares and stock units		$	41		$	46		$	29		$	26

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Compensation expense for performance shares is recognized over the three year performance period based on the fair value of the awards at the end of each reporting period and the time elapsed within each grant's performance period.  The fair value of performance shares is determined based on the shares' current market value at the end of each reporting period, estimated forfeitures for each grant, and expected payout based on management's best estimate including analysis of historical performance in accordance with the defined metrics of each grant.  Compensation expense is recorded as performance shares are earned over the relevant three-year life of the performance share grant prior to its award.  The portion of the compensation expense related to an employee who retires during the performance period is the amount recognized up to the date of retirement.

Compensation expense for restricted shares is recognized over the defined vesting periods based on the grant date fair value of the awards.  As of December 31, 2012, there are no stock options outstanding.  Stock option expense recognized over the three months ended March 31, 2012 was not material.

The market price of CH Energy Group stock increased approximately $8 per share immediately following the February 21, 2012 announcement that CH Energy Group had entered into a merger agreement with Fortis.  CH Energy Group's equity-based compensation expense for the three months ended March 31, 2013 and 2012 included approximately $0.1 million and $1.0 million attributable to the increase in stock price on outstanding performance share awards, which has been recognized at the holding company as a transaction cost resulting from the proposed acquisition of CH Energy Group by Fortis and not allocated to its subsidiaries.

NOTE 12 – Commitments and Contingencies

Electricity Purchase Commitments

On June 30, 2010and September 9, 2010,Central Hudson entered into agreements with Entergy Nuclear Power Marketing, LLC to purchase electricity (but not capacity) on a unit-contingent basis at defined prices from January 1, 2011 through December 31, 2013.  For the three months ended March 31, 2012, energy supplied under these agreements cost approximately $5.2 million.  For the three months ended March 31, 2013, energy supplied under these agreements cost approximately $4.3 million, which represents approximately 14% of Central Hudson's full-service customer requirements on an annual basis.

These contracts meet the definition of a normal purchase and are therefore excluded from current accounting requirements related to derivatives.  In the event the above noted counterparty is unable to fulfill its commitment to deliver under the terms of the agreements, Central Hudson would obtain the supply from the New York Independent System Operator ("NYISO") market, and under Central Hudson's current ratemaking treatment, recover the full cost from customers.  As such, there would be no impact on earnings.

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Central Hudson must also acquire sufficient peak load capacity to meet the peak load requirements of its full service customers.  This capacity is made up of contracts with capacity providers, purchases from the NYISO capacity market and its own generating capacity.

Environmental Matters

Central Hudson

· Air

There has been no change to this matter in 2013, however, the relevant disclosure is provided as required.  In 1999, the New York State Attorney General ("Attorney General") alleged that Central Hudson "may have constructed, and continues to operate, major modifications to the Danskammer Point Steam Electric Generating Station ("Danskammer Plant") without obtaining certain requisite preconstruction permits."  In March 2000, the Environmental Protection Agency ("EPA") assumed responsibility for the investigation.  Central Hudson believes any permits required for these projects were obtained in a timely manner.  Central Hudson sold the Danskammer Plant to Dynegy in January 2001.  While Central Hudson could have retained liability after the sale, depending on the type of remedy, Central Hudson believes that the statutes of limitation relating to any alleged violation of air emissions rules have lapsed. 

· Former Manufactured Gas Plant Facilities

Central Hudson and its predecessors owned and operated manufactured gas plants ("MGPs") to serve their customers' heating and lighting needs. These plants manufactured gas from coal and oil beginning in the mid to late 1800s with all sites ceasing operations by the 1950s. This process produced certain by-products that may pose risks to human health and the environment.

The New York State Department of Environmental Conservation ("DEC"), which regulates the timing and extent of remediation of MGP sites in New York State, has notified Central Hudson that it believes Central Hudson or its predecessors at one time owned and/or operated MGPs at seven sites in Central Hudson's franchise territory.  The DEC has further requested that Central Hudson investigate and, if necessary, remediate these sites under a Consent Order, Voluntary Cleanup Agreement, or Brownfield Cleanup Agreement.  The DEC has placed all seven of these sites on the New York State Environmental Site Remediation Database.  As authorized by the PSC, Central Hudson is currently permitted to defer for future recovery the differences between actual costs for MGP site investigation and remediation and the associated rate allowances, with carrying charges to be accrued on the deferred balances at the authorized pre-tax rate of return.

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MGP site investigation and remediation can be divided into various stages of completion based on the milestones of activities completed and reports reviewed.  Central Hudson accrues for remediation costs based on the amounts that can be reasonably estimated at a point in time.  These stages, the types of costs accrued during various stages and the sites currently in each stage, include:

· Investigation – Begins with preliminary investigations and is completed upon filing and approval by DEC of a Remedial Investigation ("RI") Report.  Central Hudson accrues for estimated investigation costs, Remediation Alternative Analysis ("RAA"), and Remedial Design costs.

Ø Site #6 – Kingston (NY) – Remedial Investigation in Progress

- The revised RI report was submitted to the DEC for review and approval in November 2012.  The DEC provided general and specific comments to the revised RI report in a letter dated February 27, 2013. Central Hudson submitted a comment response letter to the DEC on March 28, 2013.

- Amounts accrued represent an estimate of costs to complete the RAA and the Remedial Design.

· Remedial Alternative Analysis – Engineering analysis of alternatives for remediation based on the RI is compiled into a RAA Report.  Upon completion of the RAA and the filing with the DEC, management accrues for an estimate of remediation costs developed and quantified in the RAA based on DEC approved methods, as well as an estimate of post-remediation operation, maintenance and monitoring costs ("OM&M").  These amounts represent a significant portion of the total costs to remediate and are subject to change based on further investigations, final remedial design and associated engineering estimates, regulatory comments and requests, remedial design changes/negotiations, and changed or unforeseen conditions during the remediation or additional requirements following the remediation. Prior to the completion of the RAA, management cannot reasonably estimate what cost will be incurred for remediation or post-remediation activities.

Ø Site #5 – North Water Street (Poughkeepsie,NY) – Remedial Alternatives Analysis in progress

- DEC approved an Interim Remedial Measure ("IRM") associated with the southern portion of this site.  The IRM activities were completed in 2012.  The IRM Construction Completion Report ("CCR") and Interim Site Management Plan ("SMP") were submitted to the DEC for review and approval in December 2012 and February 2013, respectively.

- In addition, Central Hudson has recently retired and removed propane air facilities formerly located on site. The DEC approved a work plan to investigate the former propane tank area on February 7, 2013.  The investigation is tentatively planned to commence in the spring of 2013.  Depending on the results of this investigation some level of future remediation may be required in this area.

- Amounts accrued represent an estimate for completion of the RAA and Remedial Design.

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· Remedial Design - Upon approval of the RAA and final decision of remediation approach based on alternatives presented, a Remedial Design is developed and filed with the DEC for approval.

· Remediation – Completion of the work plan as defined in the approved Remedial Design.  Upon completion, final reports are filed with the DEC for approval and may include a CCR, Final Engineering Report ("FER"), or other reports required by the DEC based on the work performed.

Ø Site #4 – Catskill (NY) – Remediation in Progress

- Remediation activities commenced in September 2012 and are anticipated to be completed in the summer of 2013.

- Amounts accrued represent an estimate of costs to complete the remediation and OM&M.

· Post-Remediation Monitoring – Entails the OM&M as directed by the DEC based on the approved final report of remediation.  The activities are typically defined in a SMP, which is approved by the DEC.  The extent of activities during this phase may increase or decrease based on the results of ongoing monitoring being performed and future potential usage of the property.

Ø Site #1 – Beacon (NY) – Post-Remediation Monitoring Complete

- SMP submitted to the DEC and release letter for the site was received under a March 26, 2013 cover letter.

- No further costs expected and no amounts accrued as of March 31, 2013 related to this site.

- If the building at this site were to be removed, further investigation and testing would be required related to the soil under the building, which may require additional remediation.  Management cannot currently estimate the costs that may be incurred related to this.

Ø Site #2 – Newburgh (NY) – Post-Remediation In Progress

- Amounts accrued represent an estimate of costs for OM&M and execution of the draft SMP.

- Central Hudson has recently retired and removed propane air facilities located on Area A.  A draft figure associated with a future work plan to investigate the former propane tank area was submitted to the DEC in February 2013.   Additionally, draft figures proposing recovery well installation in Area A and B and a proposal to expand the recovery well system near NMW-46 (Area B) were also submitted to the DEC for approval.  Depending on the results from the former propane tank area investigation some level of future remediation may be required in this area. Management cannot currently estimate the costs that may be incurred related to potential remediation of the former propane tank area.

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Ø Site #3 – Laurel Street (Poughkeepsie, NY) – Post-Remediation In Progress

- The results of the sampling event completed in January 2013 were submitted to the DEC on February 19, 2013.  The DEC approved a request from Central Hudson to reduce the frequency of sampling from a quarterly to semi-annual frequency on February 20, 2013.

- Central Hudson continues to work with the DEC to complete an Environmental Easement for the portion of the site owned by Central Hudson.

- Amounts accrued represent an estimate of costs for OM&M.

· No Action Required

Ø  Site #7 – Bayeaux Street (Poughkeepsie, NY) – No further investigation or remedial action is currently required.  However, per the DEC this site still remains on the list for potential future investigation.

A summary of amounts accrued and spent are detailed in the chart below (In Thousands):

Site #	Liability Recorded as of 12/31/12		Amounts Spent in 2013(1)		Liability Adjustment			Liability Recorded as of 3/31/13		Current Portion of Liability at 3/31/13		Long-Term Portion of Liability at 3/31/13
1, 2, 3, 4	$	12,210	$	3,628	$	883		$	9,465	$	2,916	$	6,549
5, 6		1,743		68		(62	)		1,613		922		691
	$	13,953	$	3,696	$	821		$	11,078	$	3,838	$	7,240

(1) Amounts spent in 2013 as shown above do not include legal fees of approximately $8 thousand.

Based on a cost model analysis completed in 2012 of possible remediation and future operating, maintenance, and monitoring costs for sites #2 through #6, Central Hudson believes there is a 90% confidence level that the total costs to remediate these sites will not exceed $152.0 million over the next 30 years.  The cost model involves assumptions relating to investigation expenses, results of investigations, remediation costs, potential future liabilities, and post-remedial operating, maintenance and monitoring costs, and is based on a variety of factors including projections regarding the amount and extent of contamination, the location, size and use of the sites, proximity to sensitive resources, status of regulatory investigations, and information regarding remediation activities at other MGP sites in New York State.  The cost model also assumes that proposed or anticipated remediation techniques are technically feasible and that proposed remediation plans receive DEC and New York State Department of Health ("NYSDOH") approval.

Future remediation activities, including OM&M and related costs may vary significantly from the assumptions used in Central Hudson's current cost estimates, and these costs could have a material adverse effect (the extent of which cannot be reasonably determined) on the financial condition, results of operations and cash flows of CH Energy Group and Central Hudson if Central Hudson were unable to recover all or a substantial portion of these costs via collection in rates from customers and/or through insurance.

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Central Hudson expects to recover its remediation costs from its customers.  The current components of this recovery include:

- Current Rate Order includes cash recovery from customers of $13.6 million spread equally over the three year settlement period ending June 30, 2013;

- As part of the 2010 Rate Order, Central Hudson maintained previously granted deferral authority and subsequent recovery for amounts spent over the rate allowance.

- Total MGP Site Investigation and Remediation costs recovered through rates and other regulatory mechanisms from July 1, 2007 through March 31, 2013 was approximately $25.6 million, with $1.2 million recovered in the three months ended March 31, 2013.

- The total spent in the three months ended March 31, 2013 related to site investigation and remediation was approximately $3.7 million.

- The regulatory asset balance as of March 31, 2013 was $14.7 million, which represents the difference between amounts spent or currently accrued as a liability and the amounts recovered through rate allowance, as well as carrying charges accrued. Upon completion of investigation at sites #5 and #6, when remediation and post-remediation costs will be able to be reasonably estimated and therefore will be recorded as a liability, this regulatory asset balance will likely increase significantly.  Management projects that the investigation at these sites will likely be completed within the next two years.

Central Hudson has put its insurers on notice and intends to seek reimbursement from its insurers for its costs.  Certain of these insurers have denied coverage.  In addition to the rate allowance amounts noted above, Central Hudson recovered approximately $2.3 million from insurance. There were no insurance recoveries in the first quarter of 2013.  However, we do not expect insurance recoveries to offset a meaningful portion of total costs.

· Little Britain Road property owned by Central Hudson

In 2000, Central Hudson and the DEC entered into a Voluntary Cleanup Agreement ("VCA") whereby Central Hudson removed approximately 3,100 tons of soil and conducted groundwater sampling.  Central Hudson believes that it has fulfilled its obligations under the VCA and should receive the release provided for in the VCA, but the DEC has proposed that additional groundwater work be done to address groundwater sampling results that showed the presence of certain contaminants at levels exceeding the DEC criteria.  Central Hudson believes that such work is not necessary and has completed a soil vapor intrusion study showing that indoor air at the facility met Occupational Safety and Health Administration ("OSHA") and NYSDOH standards. In October 2011, the DEC requested a 'non-committal' meeting with Central Hudson to discuss the site and possible next steps. At the annual MGP meeting with Central Hudson in October 2012, the DEC discussed the Little Britain Road property requesting an upcoming meeting to discuss the site and possible next steps. Central Hudson responded that we are available for such a meeting.  A meeting date has yet to be established.

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At this time Central Hudson does not have sufficient information to estimate the need for additional remediation or potential remediation costs.  Central Hudson has put its insurers on notice regarding this matter and intends to seek reimbursement from its insurers for amounts, if any, for which it may become liable.  Central Hudson cannot predict the outcome of this matter.

· Eltings Corners

Central Hudson owns and operates a maintenance and warehouse facility.  In the course of Central Hudson's hazardous waste permit renewal process for this facility, sediment contamination was discovered within the wetland area across the street from the main property.  In cooperation with the DEC, Central Hudson continues to investigate the nature and extent of the contamination.  Additional off-site sediment and on-site groundwater sampling was performed during 2012 in accordance with a supplemental work plan approved by the DEC.  Results from the on-site groundwater sampling activities were submitted to the DEC in January of 2013.  Following their review, the DEC issued a letter dated March 28, 2013 relieving Central Hudson from any further on-site groundwater sampling.  The sediment sampling results are expected to be submitted to the DEC in the spring of 2013.  Further sediment investigation is expected to take place in 2013.  The extent of the contamination as well as the timing and costs for any future remediation efforts cannot be reasonably estimated at this time.

CHEC

During the three months ended March 31, 2013, the amount spent by Griffith on remediation efforts in Maryland, Virginia and Connecticut were immaterial.

Griffith's reserve for environmental remediation is $1.4 million as of March 31, 2013, of which $0.4 million is expected to be spent in the next twelve months.

In connection with the 2009 sale of operations in certain geographic locations, Griffith agreed to indemnify the purchaser for certain claims, losses and expenses arising out of any breach by Griffith of the representations, warranties and covenants Griffith made in the sale agreement, certain environmental matters and all liabilities retained by Griffith.  Griffith's indemnification obligation is subject to a number of limitations, including a five-year limitation within which certain claims must be brought, an aggregate deductible of $0.8 million applicable to certain types of non-environmental claims and other deductibles applicable to certain specific environmental claims, and caps on Griffith's liability with respect to certain of the indemnification obligations.  The sale agreement includes an aggregate cap of $5.7 million on Griffith's obligation to indemnify the purchaser for breaches of many of Griffith's representations and warranties and for certain environmental liabilities.  In 2009, the Company reserved $2.6 million for environmental remediation costs it may be obligated to pay based on its indemnification obligations under the sale agreement.  To date, Griffith has paid approximately $1.2 million under its environmental remediation cost obligation.  In the first quarter of 2011, Griffith reduced the reserve by $0.6 million based on the completion of an environmental study.  The balance as of March 31, 2013 related to the divestiture is $0.8 million.  Management believes this is the most likely amount Griffith would pay with respect to its indemnification obligations under the sale agreement.

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Certain Litigation Related to the Fortis Transaction

Following the announcement of the proposed acquisition of CH Energy Group by Fortis on February 21, 2012, several complaints were filed by purported CH Energy Group shareholders in the Supreme Court of the State of New York, County of New York (the "New York County Court") and the Supreme Court of the State of New York, County of Dutchess, challenging the proposed merger. The Dutchess County actions have been transferred to the New York County Court, and all actions have been joined under the master caption In re CH Energy Group, Inc. Shareholder Litigation, Index No. 775,000/2012.

On April 9, 2012, a master amended complaint was filed in the joined litigation related to the proposed acquisition of CH Energy Group by Fortis.  The master amended complaint, which was filed on behalf of a putative class of CH Energy Group public shareholders, names as defendants CH Energy Group, its directors, Fortis, FortisUS, and Cascade Acquisition Sub, Inc. and generally alleges that the individual defendants breached their fiduciary duties in connection with the proposed transaction and that the entity defendants aided and abetted that breach.  The master amended complaint further alleges that the preliminary proxy filed in connection with the proposed transaction with Fortis contains material misstatements and omissions.  The master complaint seeks, among other things, an order preliminarily and permanently enjoining the proposed transaction with Fortis, damages, and plaintiffs' fees and expenses.

On May 9, 2012, the parties executed a memorandum of understanding that embodies their agreement in principle on the structure of a proposed settlement. The proposed settlement, which is subject to certain conditions, including court approval following notice to a proposed settlement class consisting of all CH Energy Group shareholders during the period from February 19, 2012 through the date of the consummation of the proposed merger (the "Class"), would, among other things, dismiss all causes of action asserted in the master amended complaint and release all claims that members of the Class may have arising out of or relating in any manner to the proposed merger. Pursuant to the terms of the proposed settlement, defendants agreed to make certain disclosures to shareholders.  In the meantime, the plaintiffs and their counsel have agreed, among other things, to stay the litigation and not to initiate any proceedings (including, but not limited to, a motion for a preliminary injunction) other than those incident to effecting the settlement.

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Absent court approval of the proposed settlement, the defendants intend to vigorously defend themselves against the action.

Other Matters

Asbestos Litigation

As of March 31, 2013, of the 3,338 asbestos cases brought against Central Hudson, 1,166 remain pending.  Of the cases no longer pending against Central Hudson, 2,017 have been dismissed or discontinued without payment by Central Hudson, and Central Hudson has settled 155 cases.  Central Hudson is presently unable to assess the validity of the remaining asbestos lawsuits; however, based on information known to Central Hudson at this time, including Central Hudson's experience in settling asbestos cases and in obtaining dismissals of asbestos cases, Central Hudson believes that the costs which may be incurred in connection with the remaining lawsuits will not have a material adverse effect on the financial position, results of operations or cash flows of either CH Energy Group or Central Hudson.

Central Hudson and Griffith are involved in various other legal and administrative proceedings incidental to their businesses, which are in various stages.  While these matters collectively could involve substantial amounts, based on the facts currently known, it is the opinion of management that their ultimate resolution will not have a material adverse effect on either of CH Energy Group's or the individual segment's financial positions, results of operations or cash flows.

CH Energy Group and Central Hudson expense legal costs as incurred.

NOTE 13 – Segments and Related Information

CH Energy Group's reportable operating segments are the regulated electric utility business and regulated natural gas utility business of Central Hudson and the unregulated fuel distribution business of Griffith.  Other activities of CH Energy Group, which do not constitute a business segment, include CHEC's renewable energy investments and the holding company's activities, which consist primarily of financing its subsidiaries, and are reported under the heading "Other Businesses and Investments."

Certain additional information regarding these segments is set forth in the following tables.  General corporate expenses and Central Hudson's property common to both electric and natural gas segments have been allocated in accordance with practices established for regulatory purposes.

Central Hudson's and Griffith's operations are seasonal in nature and weather-sensitive and, as a result, financial results for interim periods are not necessarily indicative of trends for a twelve-month period.  Demand for electricity typically peaks during the summer, while demand for natural gas and heating oil typically peaks during the winter.

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CH Energy Group Segment Disclosure

(In Thousands)

	Three Months Ended March 31, 2013
	Segments						Other
	Central Hudson						Businesses
			Natural				and
	Electric		Gas		Griffith		Investments			Eliminations			Total
Revenues from external customers	$	138,163	$	56,300	$	103,911	$	-		$	-		$	298,374
Intersegment revenues		2		116		-		-			(118	)		-
Total revenues		138,165		56,416		103,911		-			(118	)		298,374
Operating income (loss)		16,967		12,191		7,791		(528	)		-			36,421
Interest and investment income		1,182		191		-		656			(644	)(1)		1,385
Interest charges		6,166		1,635		644		544			(644	)(1)		8,345
Income (Loss) before income taxes		12,306		10,847		7,233		(275	)		-			30,111
Net Income Attributable to CH Energy Group		7,263		6,250		4,268		309			-			18,090
Segment assets at March 31		1,296,078		370,390		122,695		13,928			(700	)		1,802,391

(1) This represents the elimination of inter-company interest income (expense) generated from lending activities between CH Energy Group (the holding company), and its subsidiaries (CHEC and Griffith).

CH Energy Group Segment Disclosure

(In Thousands)

	Three Months Ended March 31, 2012
	Segments						Other
	Central Hudson						Businesses
			Natural				and
	Electric		Gas		Griffith		Investments			Eliminations			Total
Revenues from external customers	$	129,272	$	55,850	$	88,950	$	-		$	-		$	274,072
Intersegment revenues		3		90		-		-			(93	)		-
Total revenues		129,275		55,940		88,950		-			(93	)		274,072
Operating income (loss)		20,125		12,479		4,947		(5,338	)		-			32,213
Interest and investment income		1,436		270		-		697			(684	)(1)		1,719
Interest charges		5,716		1,539		696		535			(684	)(1)		7,802
Income (Loss) before income taxes		16,224		11,262		4,268		(5,262	)		-			26,492
Net Income (Loss) Attributable to CH Energy Group		10,278		6,213		2,518		(4,428	)		-			14,581
Segment assets at March 31		1,284,078		377,524		109,457		16,417			(1,675	)		1,785,801

(1) This represents the elimination of inter-company interest income (expense) generated from lending activities between CH Energy Group (the holding company), and its subsidiaries (CHEC and Griffith).

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NOTE 14 - Accounting for Derivative Instruments and Hedging Activities

Accounting for Derivatives

Central Hudson has been authorized to fully recover risk management costs through its natural gas and electricity cost adjustment charge clauses.  Risk management costs are defined by the PSC as "costs associated with transactions that are intended to reduce price volatility or reduce overall costs to customers.  These costs include transaction costs, and gains and losses associated with risk management instruments."  The related gains and losses associated with Central Hudson's derivatives are included as part of Central Hudson's commodity cost and/or price-reconciled in its natural gas and electricity cost adjustment charge clauses, and are not designated as hedges.  Additionally, Central Hudson has been authorized to fully recover the interest costs associated with its variable rate debt, which includes costs and gains or losses associated with its interest rate cap contracts.  As a result, these derivative activities at Central Hudson do not impact earnings.

Derivative activity related to Griffith's heating oil contracts is not material.

The percentage of Central Hudson's electric and gas requirements covered with fixed price forward purchases is as follows:

Central Hudson	% of Requirement Hedged (1)
Electric Derivative Contracts:
April 2013 – December 2013		34.0	%
2014		28.8	%
2015		21.7	%
2016		7.2	%
2017		7.1	%
Natural Gas Derivative Contracts:
November 2013 – March 2014		2.3	%

(1) Projected coverage as of March 31, 2013.

Derivative Risks

The basic types of risks associated with derivatives are market risk (that the value of the derivative will be adversely impacted by changes in the market, primarily the change in interest and exchange rates) and credit risk (that the counterparty will not perform according to the terms of the contract).  The market risk of the derivatives generally offset the market risk associated with the hedged commodity.

The majority of Central Hudson and Griffith's derivative instruments contain provisions that require the Company to maintain specified issuer credit ratings and financial strength ratings.  Should the company's ratings fall below these specified levels, it would be in violation of the provisions, and the derivatives' counterparties could terminate the contracts and request immediate payment.

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To help limit the credit exposure of their derivatives, both Central Hudson and Griffith have entered into master netting agreements with counterparties whereby contracts in a gain position can be offset against contracts in a loss position.  Of the nineteen total agreements held by both companies, eleven contain credit-risk related contingent features. As of March 31, 2013, the amount that would be required to settle these instruments if the contingent features were triggered is immaterial.

CH Energy Group and Central Hudson have elected gross presentation for their derivative contracts under master netting agreements and collateral positions.  On March 31, 2013, neither Central Hudson nor Griffith had collateral posted against the fair value amount of derivatives.

The net presentation for CH Energy Group's and Central Hudson's derivative assets and liabilities as of March 31, 2013, December 31, 2012 and March 31, 2012 are as follows (In Thousands):

							Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Financial Position		Net Amount of Assets Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
As of March 31, 2013
Derivative Contracts:
Central Hudson - electric	$	5,822	$	-	$	5,822	$	608	$	-	$	5,214
Total Central Hudson Assets	$	5,822	$	-	$	5,822	$	608	$	-	$	5,214
Griffith - heating oil	$	3	$	-	$	3	$	-	$	-	$	3
Total CH Energy Group Assets	$	5,825	$	-	$	5,825	$	608	$	-	$	5,217
As of December 31, 2012
Derivative Contracts:
Central Hudson - electric	$	693	$	-	$	693	$	664	$	-	$	29
Central Hudson - gas		95		-		95		18		-		77
Total Central Hudson Assets	$	788	$	-	$	788	$	682	$	-	$	106
Griffith - heating oil	$	26	$	-	$	26	$	-	$	-	$	26
Total CH Energy Group Assets	$	814	$	-	$	814	$	682	$	-	$	132
As of March 31, 2012
Derivative Contracts:
Central Hudson - electric	$	-	$	-	$	-	$	-	$	-	$	-
Total Central Hudson Assets	$	-	$	-	$	-	$	-	$	-	$	-
Griffith - heating oil	$	9	$	-	$	9	$	-	$	-	$	9
Total CH Energy Group Assets	$	9	$	-	$	9	$	-	$	-	$	9

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							Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Financial Position		Net Amount of Assets Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
As of March 31, 2013
Derivative Contracts:
Central Hudson - electric	$	608	$	-	$	608	$	608	$	-	$	-
Central Hudson - gas		2		-		2		-		-		2
Total Central Hudson Liabilities	$	610	$	-	$	610	$	608	$	-	$	2
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	610	$	-	$	610	$	608	$	-	$	2
As of December 31, 2012
Derivative Contracts:
Central Hudson - electric	$	1,367	$	-	$	1,367	$	664	$	-	$	703
Central Hudson - gas		110		-		110		18		-		92
Total Central Hudson Liabilities	$	1,477	$	-	$	1,477	$	682	$	-	$	795
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	1,477	$	-	$	1,477	$	682	$	-	$	795
As of March 31, 2012
Derivative Contracts:
Central Hudson - electric	$	23,792	$	-	$	23,792	$	-	$	-	$	23,792
Central Hudson - gas		14		-		14		-		-		14
Total Central Hudson Liabilities	$	23,806	$	-	$	23,806	$	-	$	-	$	23,806
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	23,806	$	-	$	23,806	$	-	$	-	$	23,806

The fair value of CH Energy Group's and Central Hudson's derivative instruments and their location in the respective Balance Sheets are summarized in the table below, followed by a summarization of their effect on the respective Statements of Income.  For additional information regarding Central Hudson's physical hedges, see the discussion following the caption "Electricity Purchase Commitments" in Note 12 - "Commitments and Contingencies."

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Gross Fair Value of Derivative Instruments

Derivative contracts are measured at fair value on a recurring basis.  As of March 31, 2013, December 31, 2012, and March 31, 2012, CH Energy Group's and Central Hudson's derivative assets and liabilities by category and hierarchy level are as follows (In Thousands):

Asset or Liability Category	Fair Value			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
As of March 31, 2013(1)
Assets:
Derivative Contracts:
Central Hudson - electric	$	5,822		$	-		$	-	$	5,822
Total Central Hudson Assets	$	5,822		$	-		$	-	$	5,822
Griffith - heating oil	$	3		$	3		$	-	$	-
Total CH Energy Group Assets	$	5,825		$	3		$	-	$	5,822
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(608	)	$	-		$	-	$	(608	)
Central Hudson - natural gas		(2	)		(2	)		-		-
Total CH Energy Group and Central Hudson Liabilities	$	(610	)	$	(2	)	$	-	$	(608	)
As of December 31, 2012(1)
Assets:
Derivative Contracts:
Central Hudson - electric	$	693		$	-		$	-	$	693
Central Hudson - natural gas		95			95			-		-
Total Central Hudson Assets	$	788		$	95		$	-	$	693
Griffith - heating oil	$	26		$	26		$	-	$	-
Total CH Energy Group Assets	$	814		$	121		$	-	$	693
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(1,367	)	$	(110	)	$	-	$	(1,367	)
Central Hudson - natural gas		(110	)		-			-		-
Total CH Energy Group and Central Hudson Liabilities	$	(1,477	)	$	(110	)	$	-	$	(1,367	)
As of March 31, 2012(1)
Assets:
Derivative Contracts:
Griffith - heating oil	$	9		$	-		$	-	$	-
Total CH Energy Group Assets	$	9		$	-		$	-	$	-
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(23,792	)	$	-		$	-	$	(23,792	)
Central Hudson - natural gas		(14	)		(14	)		-		-
Total CH Energy Group and Central Hudson Liabilities	$	(23,806	)	$	(14	)	$	-	$	(23,792	)

(1) Interest rate cap agreement is not shown in the above table because the FMV at each period stated was zero.

Central Hudson obtains forward pricing for Level 3 derivatives from an independent third party provider of derivative pricing. Significant unobservable inputs utilized in their pricing model are bi-lateral contracts and projected activity of certain major participants. Generally, a change in any of the underlying assumptions would result in a positively correlated change in fair value measurement.

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The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value and classified as Level 3 in the fair value hierarchy (In Thousands):

	Three Months Ended
	March 31,
	2013			2012
Balance at Beginning of Period	$	(674	)	$	(16,830	)
Unrealized gains/(losses)		5,888			(6,962	)
Realized gains/(losses)		5,119			(7,654	)
Purchases		-			-
Issuances		-			-
Sales and settlements		(5,119	)		7,654
Transfers in and/or out of Level 3		-			-
Balance at End of Period	$	5,214		$	(23,792	)
The amount of total gains or losses for the period included in earnings attributable to the change in unrealized gains or losses relating to derivatives still held at end of period	$	-		$	-

The company did not have any transfers into or out of Levels 1 or 2.

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The Effect of Derivative Instruments on the Statements of Income

Realized gains and losses on Central Hudson's derivative instruments are conveyed to or recovered from customers through PSC authorized deferral accounting mechanisms, with no material impact on cash flows, results of operations or liquidity.  Realized gains and losses on Central Hudson's energy derivative instruments are reported as part of purchased electricity and fuel used in electric generation in Central Hudson's Consolidated Statement of Income as the corresponding amounts are either recovered from or returned to customers through electric cost adjustment clauses in revenues.

For the three months ended March 31, 2013 and 2012, neither CH Energy Group nor Central Hudson had derivatives designated as hedging instruments.  The following table summarizes the effects of CH Energy Group and Central Hudson derivatives on the statements of income (In Thousands):

	Amount of Gain (Loss) Recognized as Increase/(Decrease) in the Income Statement
	Three Months Ended March 31,
	2013			2012			Location of Gain (Loss)
Central Hudson:
Electricity swap contracts	$	5,119		$	(7,654	)	Regulatory (asset)/liability(1)
Natural gas swap contracts		(44	)		(2,406	)	Regulatory (asset)/liability(1)
Total return swap contracts		-			617		Other-net
Total Central Hudson	$	5,075		$	(9,443	)
Griffith:
Heating oil call option contracts	$	(2	)	$	30		Purchased petroleum
Griffith other derivative financial instrument		-			-		Purchased petroleum
Total Griffith	$	(2	)	$	30
Total CH Energy Group	$	5,073		$	(9,413	)

(1) Realized gains and losses on Central Hudson's derivative instruments are conveyed to or recovered from customers through PSC authorized deferral accounting mechanisms, with an offset in revenue and on the balance sheet, and no impact on results of operations.

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NOTE 15 – Other Fair Value Measurements

Other Assets Recorded at Fair Value

In addition to the derivatives reported at fair value discussed in Note 14 – "Accounting for Derivative Instruments and Hedging Activities", CH Energy Group reports certain other assets at fair value in the Consolidated Balance Sheets. The following table summarizes the amount reported at fair value related to these assets as of March 31, 2013, December 31, 2012, and March 31, 2012 (In Thousands):

Asset Category	Fair Value		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
As of March 31, 2013:
Other investments	$	1,636	$	1,636	$	-	$	-
As of December 31, 2012:
Other investments	$	1,603	$	1,603	$	-	$	-
As of March 31, 2012:
Other investments	$	2,438	$	2,438	$	-	$	-

As of March 31, 2013, December 31, 2012 and March 31, 2012, a portion of the trust assets for the funding of CH Energy Group's Directors and Executives Deferred Compensation Plan were invested in mutual funds, which are measured at fair value on a recurring basis.  These investments are valued at quoted market prices in active markets and as such are Level 1 investments as defined in the fair value hierarchy.  These amounts are included in the line titled "Other investments" within the Deferred Charges and Other Assets section of the CH Energy Group Consolidated and Central Hudson Balance Sheets.

In the third quarter of 2011, CHEC recorded an impairment loss for the full value of its investment in CH-Community Wind.  An impairment analysis was performed and based on this analysis, the present value of the after-tax projected cash flows using a market participant's expected return, is insufficient for CHEC to recover any of its investment.  This analysis used significant unobservable inputs including a discount rate and projected cash flows for the entity and as such this is a Level 3 investment. As of March 31, 2013, management believes the fair value of this investment remains at zero and is therefore appropriately reserved.

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Other Fair Value Disclosure

Financial instruments are recorded at carrying value in the financial statements, however, the fair value of these instruments is disclosed below in accordance with current accounting guidance related to financial instruments.

The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value:

Cash and Cash Equivalents:  Carrying amount (Level 1)

Long-term Debt:  Quoted market prices for the same or similar issues (Level 2)

Valuations were obtained for each issue using the observed Treasury market in conjunction with secondary market trading levels and recent new issuances of comparable companies.

Notes Payable:  Carrying amount (Level 2)

Due to the short-term nature (typically one month or less) of our Notes Payable borrowings, the carrying value is equivalent to the current FMV.

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Long-term Debt Maturities and Fair Value - CH Energy Group

(Dollars in Thousands)

		Fixed Rate				Variable Rate				Total Debt Outstanding
Expected Maturity Date		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate
As of March 31, 2013:
	2013	$	31,076	6.93	%	$	-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	2017		34,406	6.13	%		-	-	%
	Thereafter		386,625	5.13	%		33,700	0.20	%
	Total	$	484,302	5.31	%	$	33,700	0.20	%	$	518,002	5.02	%
	Fair Value	$	554,724			$	33,700			$	588,424
As of December 31, 2012:
	2013	$	31,076	6.93	%	$	-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	2017		34,406	6.13	%		-	-	%
	Thereafter		386,625	5.13	%		33,700	0.28	%
	Total	$	484,302	5.31	%	$	33,700	0.28	%	$	518,002	5.03	%
	Fair Value	$	562,855			$	33,700			$	596,555
As of March 31, 2012:
	2012	$	1,006	6.86	%	$	-	-	%
	2013		31,076	6.93	%		-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	Thereafter		397,031	5.29	%		33,700	0.37	%
	Total	$	461,308	5.38	%	$	33,700	0.37	%	$	495,008	5.07	%
	Fair Value	$	545,959			$	33,700			$	579,659

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Long-term Debt Maturities and Fair Value - Central Hudson

(Dollars in Thousands)

		Fixed Rate					Variable Rate				Total Debt Outstanding
Expected Maturity Date		Amount			Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate
As of March 31, 2013:
	2013	$	30,000		6.93	%	$	-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-	1	-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	2017		33,000		6.10	%		-	-	%
	Thereafter		371,250		5.06	%		33,700	0.20	%
	Total	$	456,250		5.22	%	$	33,700	0.20	%	$	489,950	4.92	%
	Fair Value	$	521,706				$	33,700			$	555,406
As of December 31, 2012:
	2013	$	30,000		6.93	%	$	-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-		-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	2017		33,000		6.10	%		-	-	%
	Thereafter		371,250		5.06	%		33,700	0.28	%
	Total	$	456,250		5.22	%	$	33,700	0.28	%	$	489,950	4.93	%
	Fair Value	$	529,710				$	33,700			$	563,410
As of March 31, 2012:
	2012	$	-		-	%	$	-	-	%
	2013		30,000		6.93	%		-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-		-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	Thereafter		380,250		5.22	%		33,700	0.37	%
	Total	$	432,250		5.28	%	$	33,700	0.37	%	$	465,950	4.96	%
	Fair Value	$	507,978				$	33,700			$	541,678

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NOTE 16 – Subsequent Events

In addition to items disclosed in the footnotes, CH Energy Group has performed an evaluation of events subsequent to March 31, 2013 through the date the financial statements were issued and noted two additional items to disclose.

On April 18, 2013, Central Hudson's Board of Directors approved a $5.0 million dividend payment to parent CH Energy Group that was paid on April 30, 2013.

On April 24, 2013, the Commission issued a notice stating that the Administrative Law Judges ("ALJs") assigned to this matter would prepare a Recommended Decision ("RD") for the Commission.  On May 3, 2013 the Recommended Decision of the two Administrative Law Judges – an advisory document – was issued by the PSC.  See Item 7 - "Management's Discussion and Analysis of Financial Condition and Results of Operations" under the caption "Regulatory Matters – PSC Proceedings" for further discussion regarding the terms of the Joint Proposal and schedule.

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ITEM 2 - Management's Discussion and Analysis of Financial Condition and Results of Operations

EXECUTIVE SUMMARY

This MD&A should be read in conjunction with the first quarter Financial Statements and the notes thereto and the MD&A in Item 7 of the Companies' combined Annual Report on Form 10-K for the year ended December 31, 2012.

Business Overview

CH Energy Group's objective is to deliver value to its shareholders through current income, in the form of quarterly dividend payments, and through share appreciation that is expected to result from earnings and dividend growth over the long term.

CH Energy Group is a holding company with four business units:

Business Segments:
	(1)	Central Hudson's regulated electric utility business;
	(2)	Central Hudson's regulated natural gas utility business;
	(3)	Griffith's fuel distribution business;
Other Businesses and Investments:
	(4)	CHEC's renewable energy investments and the holding company's activities, which consist primarily of financing its subsidiaries.

Information Regarding the Fortis Transaction

On February 21, 2012, CH Energy Group announced that it had entered into an agreement and plan of merger under which it agreed, subject to shareholder approval and the approval of applicable regulatory authorities, to be acquired by Fortis Inc. ("Fortis") for $65 per share of common stock in cash.  On April 20, 2012, CH Energy Group, Central Hudson, Fortis, FortisUS Inc. ("FortisUS"), and Cascade Acquisition Sub Inc. ("Petitioners"), submitted a joint petition to the PSC for approval of the proposed transaction under Section 70 of the Public Service Law.  On June 19, 2012, shareholders of CH Energy Group approved the proposed acquisition of the Company by Fortis.  As of December 31, 2012, the only outstanding approval needed for the transaction to close is from the New York State Public Service Commission ("PSC" or "Commission").  In January 2013, Fortis, Central Hudson, PSC Staff and other parties reached an agreement of terms related to the proposed transaction.  This joint proposal was filed with the PSC for its review and approval.  On April 24, 2013, the Commission issued a notice stating that the Administrative Law Judges ("ALJs") assigned to this matter would prepare a Recommended Decision ("RD") for the Commission.  On May 3, 2013 the Recommended Decision of the two Administrative Law Judges – an advisory document – was issued by the PSC.  The RD states that, in its current form, the Joint Proposal does not meet the public interest test as required by New York State Public Service Law, Section 70, but also states that the ALJs recommend the Commission consider adopting the Joint Proposal subject to modifications that would alter the transaction's balance of risks and benefits.  While no assurance regarding the closing can be given until a final PSC Order is issued, the Company continues to anticipate that the Commission will review and approve the merger in the second quarter of 2013.  Under the terms of the merger agreement, Fortis must close the transaction if all conditions precedent are met, including PSC approval, and a material adverse effect has not occurred.  Closing of the transaction would follow shortly after issuance of the final PSC Order approving the merger.  Management believes this will occur in the second quarter of 2013.  See Item 7 - "Management's Discussion and Analysis of Financial Condition and Results of Operations" under the caption "Regulatory Matters – PSC Proceedings" for further discussion regarding the terms of the Joint Proposal and schedule.

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Mission and Strategy

CH Energy Group's mission is to provide electricity, natural gas, petroleum and related services to an expanding customer base in a safe, reliable, courteous and affordable manner; to produce growing financial returns for shareholders; to foster a culture that encourages employees to reach their full potential; and to be a good corporate citizen.

CH Energy Group endeavors to fulfill its mission, providing an attractive risk adjusted return to CH Energy Group shareholders, by executing our plan to:

· Concentrate on energy distribution through Central Hudson in the Mid-Hudson Valley and through Griffith in the Mid-Atlantic region

· Invest primarily in utility electric and natural gas transmission and distribution

· Focus on risk management

- Limit commodity exposure

- Manage regulatory affairs effectively

- Maintain a financial profile that supports a credit rating in the "A" category

- Limit the impact of weather on Griffith's earnings

· Target stable and predictable earnings, with growth trend expectations of 5% or more per year

· Provide an annualized dividend that is approximately 65% to 70% of annual earnings

Strategy Execution

Based on the current investment and capital structure, CH Energy Group's management believes that it is well positioned to achieve its earnings growth and annualized dividend goals.

Management continues to focus on Central Hudson's electric and natural gas infrastructure as the core growth drivers of CH Energy Group.  Central Hudson's capital expenditure program is on course to achieve its targets under its three year rate plan.  Central Hudson's capital expenditure program is off to a strong start in 2013 as weather conditions have been favorable for construction and infrastructure projected and the five year forecast includes increasing annual capital investments.  The capital program provides for continued strengthening of electric and gas infrastructure, as well as prudent investment in technology that will improve reliability and customer satisfaction.  Central Hudson continues to effectively manage its operational challenges, including significant weather events in the past few years and the impact of a significant recession on its customers' ability to pay bills.

Griffith's high quality service and brand recognition enabled management to continue its history of increasing margins in an environment of contracting customer demand for petroleum products.  Additionally, Griffith continued its focus on cost management in an effort to reduce the impact of the lower volumes and higher commodity costs on its cost of doing business.

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Opportunities and Risks

In February 2013, Central Hudson experienced a cyber incident that may have exposed certain confidential customer information to an unauthorized third party.  Central Hudson commenced an investigation immediately upon becoming aware of the possible unauthorized access and began precautionary communications to Central Hudson customers as well as to the applicable regulatory agencies.  Central Hudson has also offered credit monitoring services to the potentially impacted customers free of charge.  During the three months ended March 31, 2013, cyber incident investigation costs were $0.6 million and the total financial impact of the costs associated with the communication efforts and credit monitoring services is currently estimated to be approximately $0.8 million.

EARNINGS PER SHARE AND OVERVIEW OF YEAR-TO-DATE RESULTS

The following discussion and analyses include explanations of significant changes in revenues and expenses between the three months ended March 31, 2013 and 2012 for Central Hudson's regulated electric and natural gas businesses, Griffith, and the Other Businesses and Investments.

-54-

The discussions and tables below present the change in earnings of CH Energy Group's business units in terms of earnings for each outstanding share of CH Energy Group's Common Stock.  Management believes that expressing the results in terms of the impact on shares of CH Energy Group is useful to investors because it shows the relative contribution of the various business units to CH Energy Group's earnings.  This information is considered a non-GAAP financial measure and not an alternative to earnings per share determined on a consolidated basis, which is the most directly comparable GAAP measure.  Additionally, management believes that the disclosure of Significant Events within each business unit provides investors with the context around the Company's results that is important in enabling them to ascertain the likelihood that past performance is indicative of future performance.  A reconciliation of each business unit's earnings per share to CH Energy Group's earnings per share, determined on a consolidated basis, is included in the table below.

CH Energy Group Consolidated

Earnings per Share (Basic)

	Three Months Ended March 31,
	2013			2012			Change
Central Hudson - Electric	$	0.48		$	0.70		$	(0.22	)
Central Hudson - Natural Gas		0.42			0.41			0.01
Griffith		0.29			0.17			0.12
Other Businesses and Investments		0.02			(0.30	)		0.32
Total CH Energy Group Consolidated Earnings, as reported	$	1.21		$	0.98		$	0.23
Significant Events:
Central Hudson	$	(0.15	)	$	(0.05	)	$	(0.10	)
Griffith		(0.01	)		(0.07	)		0.06
Other Businesses and Investments		(0.02	)		(0.33	)		0.31
Total Significant Events	$	(0.18	)	$	(0.45	)	$	0.27
CH Energy Group Consolidated Adjusted Earnings Per Share (non-GAAP):
Central Hudson	$	1.05		$	1.16		$	(0.11	)
Griffith		0.30			0.24			0.06
Other Businesses and Investments		0.04			0.03			0.01
Total CH Energy Group Consolidated Adjusted Earnings Per Share (non-GAAP)	$	1.39		$	1.43		$	(0.04	)

The Significant Events noted for each business unit above and further detailed below represent items impacting earnings during the respective quarters which Management does not consider representative of core earnings of each business unit.  Management considers core earnings to include the results of operations excluding the effect of unusual events or transactions not reflective of ongoing performance, such as the impacts of extreme weather or an incentive earned outside the normal course of business. Overall the Company believes that providing investors with a view of core earnings as described above provides increased transparency and clarity into the operational results of the business; improves visibility to management decisions and their impacts on operational performance; and allows the company to provide a long-term strategic view of the business going forward.

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Details by business unit were as follows:

Central Hudson

Earnings per Share (Basic)

	Three Months Ended March 31,
	2013			2012			Change
Central Hudson - Electric	$	0.48		$	0.70		$	(0.22	)
Central Hudson - Natural Gas		0.42			0.41			0.01
Total Central Hudson Earnings	$	0.90		$	1.11		$	(0.21	)
Significant Events:
Storm Deferral Adjustment	$	(0.15	)	$	(0.05	)	$	(0.10	)
Central Hudson Adjusted Earnings Per Share	$	1.05		$	1.16		$	(0.11	)
							Change
Delivery revenue							$	0.10
Higher trimming costs								(0.04	)
Higher depreciation								(0.04	)
Higher property and other taxes								(0.03	)
Higher operating expenses								(0.07	)
Cyber security incident								(0.03	)
							$	(0.11	)

(1) Amount represents incremental costs incurred for weather related service restoration, including costs for outside contractor assistance in restoration efforts and higher than average internal expenses (such as overtime and materials), which did not meet the PSC criteria for deferral and therefore have not been deferred for future recovery from customers.

Earnings from Central Hudson's electric and natural gas operation decreased in the three months ended March 31, 2013 compared to the same period in 2012.  In March 2013, Central Hudson recorded $3.7 million reversal of storm costs previously deferred for future recovery following the Commission's April 22, 2013 Orders denying recovery of incremental storm costs associated with Tropical Storm Irene and October 2011 Snowfall storm. In March 2012, Central Hudson reduced its deferred storm costs associated with the significant snow storm event in late October 2011 ("SnowFall") by $0.05.  After adjusting Central Hudson's earnings per share for this deferral adjustment, earnings were $0.11 per share lower quarter over quarter primarily as a result of higher trimming costs and cyber security incident costs.  The delays in trimming at the end of 2012 due to the redeployment of trimming crews to assist in the restoration effort of Central Hudson and other neighboring utilities following Superstorm Sandy combined with the requirement to meet the level of expenditures over the three year rate plan ending June 30, 2013 increased trimming costs during the first quarter of 2013.  In addition, Central Hudson incurred costs associated with the cyber security incident in the first quarter of 2013.  Also negatively impacting quarter over quarter earnings were higher operating expenses including higher compensation costs not included in rates, higher costs associated with environmental remediation, higher level of gas service retirements and new programs to expand the use of natural gas and to collect past due bills from customers.

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Griffith

Earnings per Share (Basic)

	Three Months Ended March 31,
	2013			2012			Change
Griffith - Fuel Distribution Earnings	$	0.29		$	0.17		$	0.12
Significant Events:
Weather impact on sales	$	(0.01	)	$	(0.07	)	$	0.06
Griffith Adjusted Earnings Per Share	$	0.30		$	0.24		$	0.06
							Change
Gross margin on petroleum sales							$	0.07
Gross margin on services								0.01
Weather-normalized sales (including conservation)								(0.01	)
Other								(0.01	)
							$	0.06

Griffith's earnings increased $0.12 per share in the three months ended March 31, 2013 compared to 2012 primarily as a result of first quarter 2012 earnings being negatively impacted due to unusually warm weather.  Griffith's core earnings, excluding the impacts of the significant event were favorable quarter over quarter as a result of higher margins.

Other Businesses and Investments

Earnings per Share (Basic)

	Three Months Ended March 31,
	2013			2012			Change
Other Businesses & Investments Earnings	$	0.02		$	(0.30	)	$	0.32
Significant Events:
Merger related costs	$	(0.02	)	$	(0.33	)	$	0.31
Other Businesses and Investments Adjusted Earnings Per Share	$	0.04		$	0.03		$	0.01
							Change
Other							$	0.01
							$	0.01

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The earnings of CH Energy Group (the holding company) and CHEC's partnerships and other investments increased in the three months ended March 31, 2013 compared to 2012 primarily due to the costs associated with the Fortis acquisition which impacted year-over-year earnings by $0.31 per share.

RESULTS OF OPERATIONS

A breakdown by business unit of CH Energy Group's operating revenues and net income for the three months ended March 31, 2013 and 2012 are illustrated below (Dollars in Thousands):

	Three Months Ended March 31, 2013								Three Months Ended March 31, 2012
Business Unit	Operating Revenues				Net Income Attributable to CH Energy Group				Operating Revenues				Net Income (Loss) Attributable to CH Energy Group
Electric(1)	$	138,163	46	%	$	7,263	40	%	$	129,272	47	%	$	10,278		70	%
Gas(1)		56,300	19			6,250	34			55,850	21			6,213		43
Total Central Hudson		194,463	65			13,513	74			185,122	68			16,491		113
Griffith(1)		103,911	35			4,268	24			88,950	32			2,518		17
Other Businesses and Investments		-	-			309	2			-	-			(4,428	)	(30	)
Total CH Energy Group	$	298,374	100	%	$	18,090	100	%	$	274,072	100	%	$	14,581		100	%

(1)	A portion of the revenues above represent amounts collected from customers for the recovery of purchased electric and natural gas costs at Central Hudson and the cost of purchased petroleum products at Griffith and therefore have no material impact on net income.  A breakout of these components is as follows:
	Electric 1st Quarter 2013: 17% cost recovery revenues + 29% other revenues = 46%
	Electric 1st Quarter 2012: 16% cost recovery revenues + 31% other revenues = 47%
	Natural gas 1st Quarter 2013: 8% cost recovery revenues + 11% other revenues = 19%
	Natural gas 1st Quarter 2012: 9% cost recovery revenues + 12% other revenues = 21%
	Griffith 1st Quarter 2013: 27% commodity costs + 8% other revenues = 35%
	Griffith 1st Quarter 2012: 25% commodity costs + 7% other revenues = 32%

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Central Hudson

The following discussion and analysis includes explanations of significant changes in operating revenues, operating expenses, volumes delivered, other income, interest charges, and income taxes between the three months ended March 31, 2013 and 2012 for Central Hudson's regulated electric and natural gas businesses.

Income Statement Variances

(Dollars In Thousands)

	Three Months Ended March 31,				Increase/(Decrease) in
	2013		2012		Amount		Percent
Operating Revenues	$	194,463	$	185,122	$	9,341	5.0	%
Operating Expenses:					1
Purchased electricity, fuel and natural gas		73,808		69,673		4,135	5.9
Depreciation and amortization		9,955		9,468		487	5.1
Other operating expenses		81,542		73,377		8,165	11.1
Total Operating Expenses		165,305		152,518		12,787	8.4
Operating Income		29,158		32,604		(3,446)	(10.6)
Other Income, net		1,796		2,137		(341)	(16.0)
Interest Charges		7,801		7,255		546	7.5
Income before income taxes		23,153		27,486		(4,333)	(15.8)
Income Taxes		8,784		10,753		(1,969)	(18.3)
Net income	$	14,369	$	16,733	$	(2,364)	(14.1)	%

Delivery Volumes

Delivery volumes for Central Hudson vary in response to weather conditions and customer behavior.  Electric deliveries peak in the summer and deliveries of natural gas used for heating purposes peak in the winter.  Delivery volumes also vary as customers respond to the price of the particular energy product and changes in local economic conditions.

The following chart reflects the change in the level of electric and natural gas deliveries for Central Hudson in the three months ended March 31, 2013 compared to the same period in 2012.  Deliveries of electricity and natural gas to residential and commercial customers have historically contributed the most to Central Hudson's earnings.  Industrial sales and interruptible sales have a negligible impact on earnings.  Central Hudson's delivery rate structure includes revenue decoupling mechanisms ("RDMs"), which provide the ability to record revenues equal to those forecasted in the development of current rates for most of Central Hudson's customers.  As a result, fluctuations in actual delivery volumes do not have a significant impact on Central Hudson's earnings.

-59-

Electric Deliveries

(In Gigawatt-Hours)

	Actual Deliveries					Weather Normalized Deliveries(1)
	Three Months Ended					Three Months Ended
	March 31,		Variation in			March 31,		Variation in
	2013	2012	Amount	Percent		2013	2012	Amount	Percent
Residential	589	548	41	7	%	602	586	16	3	%
Commercial	479	476	3	1		480	478	2	-
Industrial and other	256	254	2	1		255	256	(1)	-
Total Deliveries	1,324	1,278	46	4	%	1,337	1,320	17	1	%

(1) Central Hudson uses an internal analysis based on historical weather data to remove the estimated impacts of weather on delivery volumes.

Natural Gas Deliveries

(In Million Cubic Feet)

	Actual Deliveries					Weather Normalized Deliveries(1)
	Three Months Ended					Three Months Ended
	March 31,		Variation in			March 31,		Variation in
	2013	2012	Amount	Percent		2013	2012	Amount	Percent
Residential	2,481	2,094	387	18	%	2,653	2,547	106	4	%
Commercial	2,664	2,257	407	18		2,833	2,681	152	6
Industrial and other	175	148	27	18		186	177	9	5
Total Deliveries	5,320	4,499	821	18	%	5,672	5,405	267	5	%

(1) Central Hudson uses an internal analysis based on historical weather data to remove the estimated impacts of weather on delivery volumes.

Total electric deliveries to residential customers increased for the three months ended March 31, 2013 as compared to the same period in 2012 primarily as a result of the impacts of the warmer than normal winter heating season at the beginning of 2012.  In addition, higher sales per customer for residential non-heating customers and increases in the number of customers billed favorably impacted the year-over-year variation.

Total natural gas deliveries to residential and commercial customers increased during the three months ended March 31, 2013 as compared to the same period in 2012 primarily due to the warmer than normal winter heating season at the beginning of 2012 as compared to the normal 2013 winter heating season.  The higher level of billed customers and increased sales per customer also favorably impacted the year-over-year variation in gas deliveries.

Revenues

Central Hudson's revenues consist of two major categories: those that offset specific expenses in the current period (matching revenues), and those that impact earnings.  Matching revenues recover Central Hudson's actual costs for particular expenses.  Any difference between these revenues and the actual expenses incurred is deferred for future recovery from or refund to customers and therefore does not impact earnings.

-60-

Change in Central Hudson Revenues - Electric

(In Thousands)

	Three Months Ended
	March 31,					Increase /
	2013			2012		(Decrease)
Revenues with Matching Expense Offsets:(1)
Energy cost adjustment	$	49,144		$	43,920	$	5,224
Sales to others for resale		1,265			1,139		126
Other revenues with matching offsets		22,765			20,899		1,866
Subtotal		73,174			65,958		7,216
Revenues Impacting Earnings:
Customer sales		63,341			58,131		5,210
RDM and other regulatory mechanisms		(644	)		2,902		(3,546	)
Pole attachments and other rents		1,159			1,110		49
Finance charges		742			748		(6	)
Other revenues		391			423		(32	)
Subtotal		64,989			63,314		1,675
Total Electric Revenues	$	138,163		$	129,272	$	8,891

(1) Revenues with matching offsets do not affect earnings since they offset related costs, the most significant being energy cost adjustment revenues, which provide for the recovery of purchased electricity costs.  Other related costs include authorized business expenses recovered through rates and the cost of special programs authorized by the PSC and funded with certain available credits.  Changes in revenues from electric sales to other entities for resale also do not affect earnings since any related profits or losses are returned or charged, respectively, to customers.

Change in Central Hudson Revenues - Natural Gas

(In Thousands)

	Three Months Ended
	March 31,					Increase /
	2013			2012		(Decrease)
Revenues with Matching Expense Offsets:(1)
Energy cost adjustment	$	16,472		$	16,599	$	(127	)
Sales to others for resale		7,200			8,220		(1,020	)
Other revenues with matching offsets		8,286			7,522		764
Subtotal		31,958			32,341		(383	)
Revenues Impacting Earnings:
Customer sales		23,840			20,311		3,529
RDM and other regulatory mechanisms		(677	)		1,945		(2,622	)
Interruptible profits		646			663		(17	)
Finance charges		257			267		(10	)
Other revenues		276			323		(47	)
Subtotal		24,342			23,509		833
Total Natural Gas Revenues	$	56,300		$	55,850	$	450

(1) Revenues with matching offsets do not affect earnings since they offset related costs, the most significant being energy cost adjustment revenues, which provide for the recovery of purchased natural gas costs.  Other related costs include authorized business expenses recovered through rates and the cost of special programs authorized by the PSC and funded with certain available credits.  For natural gas sales to other entities for resale, 85% of such profits are returned to customers.

-61-

Electric revenues increased for the three months ended March 31, 2013 as compared to 2012, primarily due to higher energy cost adjustment revenues, increased customer sales and higher other revenues with matching offsets, partially reduced by lower RDM revenues.  The increase in the energy cost adjustment revenues was driven by higher wholesale prices partially reduced by lower purchased volumes and a decrease in revenues for the recovery of previously deferred costs.  The higher electric revenues were also driven by increased revenue from energy deliveries, which resulted primarily from the increase in delivery rates as prescribed in the 2010 Rate Order.

Natural gas revenues increased for the three months ended March 31, 2013 as compared to the same period in 2012, primarily due to higher customer sales partially offset by the impacts of lower RDM revenue. The higher gas revenues was the result of increased revenue from energy deliveries, which resulted primarily from the increase in delivery rates as prescribed in the 2010 Rate Order.

Regulatory adjustments to revenues for RDMs can fluctuate from year to year based on the actual sales volumes compared to those projected in the 2010 Rate Order.  Electric RDM targets are total class volume based while Gas RDM targets are based on a projected use per customer.  In general, positive RDMs are a result of actual delivery volumes that are below the levels projected in the PSC approved rates for that period.  Negative RDMs are a result of actual delivery volumes exceeding the levels projected in PSC approved rates.  These amounts are deferred for future recovery from or return to customers.

Other revenues with matching offsets for both electric and natural gas increased for the three months ended March 31, 2013 as compared to the prior period in 2012.  The fluctuations were primarily driven by an increase in rates related to NYS energy efficiency programs.

Operating Expenses

The most significant elements of Central Hudson's operating expenses are purchased electricity and purchased natural gas; however, changes in these costs do not affect earnings since they are offset by changes in related revenues recovered through Central Hudson's energy cost adjustment mechanisms.  Additionally, there are other costs that are matched to revenues largely from customer billings, notably the cost of pensions and OPEBs, the Temporary State Assessment, and NYS energy efficiency programs.

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Total utility operating expenses increased 8% in the three months ended March 31, 2013 compared to the same period in 2012.  The following table summarizes the change in operating expenses:

Change in Central Hudson Operating Expenses

(In Thousands)

	Three Months Ended
	March 31,						Increase /
	2013			2012			(Decrease)
Expenses Currently Matched to Revenues:(1)
Purchased electricity	$	50,409		$	45,059		$	5,350
Purchased natural gas		23,672			24,819			(1,147	)
Temporary State Assessment		6,163			5,760			403
Pension		5,923			7,067			(1,144	)
OPEB		1,978			1,953			25
NYS energy programs		9,307			6,511			2,796
MGP site remediations		1,241			1,232			9
Other matched expenses		6,439			5,898			541
Subtotal		105,132			98,299			6,833
Other Expense Variations:
Tree trimming		4,462			3,521			941
Other distribution maintenance		1,486			1,860			(374	)
Property and school taxes(2)		10,793			10,130			663
Weather related service restoration		4,497			1,439			3,058
Depreciation and amortization		9,955			9,468			487
Uncollectible expense		589			2,125			(1,536	)
Purchased natural gas incentive arrangements		(273	)		(205	)		(68	)
Cyber security incident		623			-			623
Other expenses		28,041			25,881			2,160
Subtotal		60,173			54,219			5,954
Total Operating Expenses	$	165,305		$	152,518		$	12,787

(1)	Includes expenses that, in accordance with the 2010 Rate Order, are adjusted in the current period to equal the revenues earned for the applicable expenses.
(2)	In accordance with the 2010 Rate Order, Central Hudson is authorized to defer 90% of any difference between actual property tax expense and the amounts provided in rates for each Rate Year.

In addition to the required adjustment to match revenues collected from customers, the increase in purchased electricity costs and decrease in purchased natural gas costs for the three months ended March 31, 2013 compared to the same period in the prior year was driven primarily by changes in wholesale prices, purchased volumes and changes in deferred purchased electricity and gas costs.  The increase in purchased electricity costs was driven primarily by the impacts of higher wholesale prices partially reduced by the lower volumes and the change in revenues collected for previously deferred purchased electric.  Purchased gas costs was primarily impacted by the lower revenues collected for the recovery of previously deferred gas costs partially offset by higher volumes and higher wholesale gas prices.

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Variations in costs associated with NYS energy programs, pension and other matched expenses were due to a change in the level of expenses recorded, with a corresponding change in revenues, resulting from the change in the amounts included in delivery rates as authorized in the 2010 Rate Order.  The costs associated with the Temporary State Assessment are adjusted to match revenues collected from customers over the applicable period.  Variations in the Temporary State Assessment year over year primarily relate to variations in delivery volumes to which the surcharge is applied.

Bad debt expense decreased in the three months ended March 31, 2013 as compared to the same period in 2012 primarily as a result of lower write-offs of customer receivables and a decrease in the amount recorded as a reserve for future uncollectible accounts.  Management believes this is primarily a result of enhanced collection efforts, including increased resources, improved planning, improvements in the business processes related to its customer payment agreements and lower gas prices during the winter heating season at the end of 2012 as compared to 2011.

Weather related service restoration costs can fluctuate from year to year based on changes in the number and severity of storms each year.  In March 2013, Central Hudson recorded a $3.7 million reversal of storm costs previously deferred for future recovery following the Commission's April 22, 2013 Orders denying recovery of incremental storm costs associated with Tropical Storm Irene and October 2011 Snowfall storm.  In March 2012, Central Hudson also recorded a $1.1 million reversal of storm costs previously deferred for future recovery.  For further information regarding PSC Orders, see "Regulatory Matters – PSC Proceedings".

Expenses associated with tree-trimming increased during the three months ended March 31, 2013 as compared to 2012 primarily as a result of tree trimming that was deferred during the fourth quarter of 2012 due to the redeployment of trimming crews to assist in the restoration effort for Central Hudson as well as providing mutual aid to other neighboring utilities following Superstorm Sandy.  Trimming delayed due to the storm will be incurred prior to June 30, 2013 to meet the level of expenditures required over the three year rate plan.  In addition, to complete the first cycle of distribution line clearance by December 31, 2011 as prescribed by the rate plan and to take advantage of crew availability and favorable contract pricing, trimming efforts were shifted to the end of calendar year 2011 from the first quarter of 2012, reducing expenditures during the first quarter of 2012. 

In February 2013, Central Hudson experienced a cyber incident that may have exposed certain confidential customer information to an unauthorized third party.  Central Hudson commenced an investigation immediately upon becoming aware of the possible unauthorized access and began precautionary communications to Central Hudson customers as well as to the applicable regulatory agencies.  Central Hudson has also offered credit monitoring services to the potentially impacted customers free of charge.  During the three months ended March 31, 2013, cyber security investigation costs were $0.6 million and the total financial impact of the costs associated with the communication efforts and credit monitoring services is currently estimated to be approximately $0.8 million.

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Other Income

Other income and deductions for Central Hudson for the three months ended March 31, 2013 compared to the same period in 2012 decreased $0.3 million primarily as a result of the reversal of $3.7 million of previously deferred storm costs associated with Tropical Storm Irene and the October 2011 Snowfall storm following the Commission's April 22, 2013 Orders.  As a result, approximately $0.3 million of regulatory carrying charges due from customers associated with the disallowed storm costs were reversed in March 2013.

Interest Charges

Central Hudson's interest charges increased $0.5 million during the three months ended March 31, 2013 compared to the same period in 2012.This increase was the result of the higher outstanding debt balance for the three months ended March 31, 2013 as compared to the prior period and an increase in carrying charges on regulatory liabilities primarily related to an increase in the underlying reserve balance for OPEBs and the impact of the tax repair project on rate base.

Income Taxes

Income taxes for Central Hudson decreased $2.0 million for the three months ended March 31, 2013 when compared to the same period in 2012 primarily due to a decrease in pre-tax book income and R&D credits recorded in 2013 that were not in effect in the first quarter of 2012.

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CH Energy Group

In addition to the impacts on Central Hudson discussed above, CH Energy Group's sales volumes, revenues and operating expenses, income taxes and other income were impacted by Griffith and the other businesses described below.  The results of Griffith and the other businesses described below exclude inter-company interest income and expense which are eliminated in consolidation.

Income Statement Variances

(Dollars In Thousands)

	Three Months Ended March 31,					Increase/(Decrease) in
	2013			2012		Amount		Percent
Operating Revenues	$	298,374	1	$	274,072	$	24,302	8.9	%
Operating Expenses:			1
Purchased electricity, fuel, natural gas and petroleum		155,337	1		139,978		15,359	11.0
Depreciation and amortization		11,187	1		10,624		563	5.3
Merger related costs		387	1		5,219		(4,832)	(92.6)
Other operating expenses		95,042	1		86,038		9,004	10.5
Total Operating Expenses		261,953	1		241,859		20,094	8.3
Operating Income		36,421	1		32,213		4,208	13.1
Other Income (Deductions), net		2,035	1		2,081		(46)	(2.2)
Interest Charges		8,345	1		7,802		543	7.0
Income before income taxes, non-controlling interest and preferred dividends of subsidiary		30,111	1		26,492		3,619	13.7
Income Taxes		11,165	1		11,669		(504)	(4.3)
Net income		18,946	1		14,823		4,123	27.8
Dividends declared on Preferred Stock of subsidiary		92			242		(150)	(62.0)
Preferred Stock Redemption Premium		764			-		764	N/A
Net income attributable to CH Energy Group	$	18,090		$	14,581	$	3,509	24.1	%

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Griffith

Sales Volumes

Delivery and sales volumes for Griffith vary in response to weather conditions, changes in our customer base and customer behavior.  Deliveries of petroleum products used for heating purposes peak in the winter.  Sales also vary as customers respond to the price of the particular energy product and changes in local economic conditions.

Changes in sales volumes of petroleum products, including the impact of acquisitions, are set forth below.

Actual & Weather Normalized Deliveries

(In Thousands of Gallons)

			Actual Deliveries					Weather Normalized Deliveries(1)
			Three Months Ended March 31,		Increase / (Decrease) in			Three Months Ended March 31,		Increase / (Decrease) in
			2013	2012	Amount	Percent		2013	2012	Amount	Percent
Heating Oil:
	Base company volume(2)		14,626	11,378	3,248	29	%	14,846	14,710	136	1	%
	Acquisitions volume		566	-	566	N/A		575	-	575	N/A
		Total Heating Oil	15,192	11,378	3,814	34		15,421	14,710	711	5
Motor Fuels:
	Base company volume(2)		10,453	10,436	17	-		10,453	10,436	17	-
	Acquisitions volume		136	-	136	N/A		136	-	136	N/A
		Total Motor Fuels	10,589	10,436	153	1		10,589	10,436	153	1
Propane and Other:
	Base company volume(2)		417	336	81	24		423	428	(5)	(1)
		Total Propane and Other	417	336	81	24		423	428	(5)	(1)
Total:
	Base company volume(2)		25,496	22,150	3,346	15		25,722	25,574	148	1
	Acquisitions volume		702	-	702	N/A		711	-	711	N/A
		Total	26,198	22,150	4,048	18	%	26,433	25,574	859	3	%

(1)	Griffith uses an internal analysis based on historical weather data to remove the estimated impacts of weather on delivery volumes.
(2)	For the purpose of this chart, "Base company" excludes any impact from acquisitions made by Griffith in 2013 and 2012.

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Actual and Weather Normalized Delivery Volumes as % of Total Volumes

	Three Months Ended March 31,
	2013						2012
	Actual			Weather Normalized			Actual			Weather Normalized
Heating Oil:
Base company		56	%		56	%		52	%		58	%
Acquisitions		2	%		2	%		-	%		-	%
Motor Fuels:
Base company		39	%		39	%		47	%		40	%
Acquisitions		1	%		1	%		-	%		-	%
Propane and Other:
Base company		2	%		2	%		1	%		2	%
Total		100	%		100	%		100	%		100	%

Sales of petroleum products increased 18% in the three months ended March 31, 2013 compared to the same period in 2012 due primarily to weather that was 29% colder in the three months ended March 31, 2013, compared to the same period in 2012, as measured by heating degree days. Additionally, volume increased due to acquisitions made in 2012.

Gross Profit

A breakdown of Griffith's gross profit by product and service line for the three months ended March 31, 2013 and 2012 are illustrated below (Dollars in Thousands):

	Three Months Ended March 31,
Product and Service Line	2013				2012
Heating oil - Base company	$	13,746	66	%	$	9,750	56	%
Heating oil - Acquisitions		374	2			-	-
Motor fuels - Base company		2,603	13			2,439	14
Motor fuels - Acquisitions		29	-			-	-
Propane and Other - Base company		649	3			491	3
Service and installations - Base company		3,214	15			3,026	17
Service and installations - Acquisitions		241	1			-	-
Other - Base company		89	-			1,647	10
Total	$	20,945	100	%	$	17,353	100	%

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Revenues

Change in Griffith Revenues

(In Thousands)

	Three Months Ended
	March 31,				Increase /
	2013		2012		(Decrease)
Revenues:
Heating oil(1)	$	59,886	$	46,064	$	13,822
Heating oil - Acquisitions		2,164		-		2,164
Motor Fuels(1)		35,293		35,901		(608	)
Motor Fuels - Acquisitions		457		-		457
Other(1)		1,219		2,667		(1,448	)
Service Revenues(1)		4,454		4,318		136
Service Revenues - Acquisitions		438		-		438
Total	$	103,911	$	88,950	$	14,961

(1)	These line items exclude the impact of acquisitions made by Griffith in 2013 and 2012 for the analysis which compares the three months ended March 31, 2013 to 2012.
	Note: The above chart reflects revenues net of weather hedging contracts.

Revenues increased in the three months ended March 31, 2013 compared to the same period in 2012, due primarily to an increase in sales volume.

Operating Expenses

For the three months ended March 31, 2013, operating expenses increased $12.1 million, or 14%, from $84.0 million in 2012 to $96.1 million in 2013, due primarily to an increase in the cost of petroleum products of $11.2 million, or 16%, driven by an increase in sales volume.

Other operating expenses increased $0.9 million for the three months ended March 31, 2013 when compared to the same period in 2012 due primarily to higher costs associated with the increased volumes delivered in 2013 compared to 2012.

Other Businesses and Investments

Operating expenses of other businesses and investments decreased $4.8 million for the three months ended March 31, 2013 as compared to the same period in 2012 as a result of costs related to the agreement and plan of merger entered into with Fortis.  These costs relate to professional services and the increase in the cost of outstanding performance share awards under CH Energy Group's equity-based compensation plans.  Professional services totaled $0.3 million and $4.3 million for the three months ended March 31, 2013 and 2012, respectively.  The increase in the cost of outstanding performance share awards was $0.1 million and $0.9 million, respectively, and has been recognized at the holding company as a merger-related transaction cost and not allocated to its subsidiaries.

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Other income and deductions and interest charges for the balance of CH Energy Group, primarily the holding company and CHEC's investments in partnerships and other investments (other than Griffith), for the three months ended March 31, 2013 were relatively unchanged as compared to the same period in 2012.

CH Energy Group – Income Taxes

Income before taxes during the three months ended March 31, 2013 increased by $3.6 million compared to the same period in 2012.  However, income tax expense decreased $0.5 million for the three months ended March 31, 2013.  This is a result of decreased costs related to the proposed acquisition of CH Energy Group by Fortis.  Acquisition costs incurred during the three months ended March 31, 2013 and 2012 were $0.2 million and $4.3 million, respectively.  These acquisition costs included certain professional fees that are being treated as non-deductible for tax purposes.  These non-deductible transaction costs result in higher tax expense as well as higher Federal and NY State effective tax rates for each period.

CAPITAL RESOURCES AND LIQUIDITY

The growth of CH Energy Group's retained earnings in the three months ended March 31, 2013, contributed to the increase in the book value per share of its Common Stock from $34.05 at December 31, 2012, to $34.73 at March 31, 2013.  Common equity comprised 47.5% of total capital (including short-term debt) at March 31, 2013, a decrease from 48.20% at December 31, 2012.  Book value per share at March 31, 2012 was $33.97 and the common equity ratio was 46.3%.

Cash Flow Summary - CH Energy Group and Central Hudson

Changes in CH Energy Group's and Central Hudson's cash and cash equivalents resulting from operating, investing, and financing activities are summarized in the following chart (In Millions):

	CH Energy Group						Central Hudson
	Three Months Ended March 31,						Three Months Ended March 31,
	2013			2012			2013			2012
Net Cash Provided By/(Used In):
Operating Activities	$	(4.9	)	$	12.6		$	(1.1	)	$	11.2
Investing Activities		(28.4	)		(26.4	)		(28.3	)		(26.6	)
Financing Activities		18.3			64.4			12.2			68.7
Net change for the period		(15.0	)		50.6			(17.2	)		53.3
Balance at beginning of period		30.5			15.3			24.3			2.5
Balance at end of period	$	15.5		$	65.9		$	7.1		$	55.8

Central Hudson's net cash used in operations was $(1.1) million for the three months ended March 31, 2013 and net cash provided by operations was $11.2 million for the three months ended March 31, 2012.  Excluding contributions to Central Hudson's pension and OPEB plans (which totaled $26.2 million and $28.2 million in the three months ended March 2013 and 2012, respectively), cash provided by sales exceeded the period's expenses and working capital needs.  Recovery of previously deferred electric and natural gas costs had a negative impact on net cash provided by operations during the first three months of 2013 compared to the positive impact in the first three months of 2012 driven by wholesale prices in the respective periods.  Costs spent for MGP remediation efforts in excess of amounts collected in rates during the three months ended March 31, 2013 negatively impacted the cash from operations compared to the three months ended March 31, 2012 when amounts collected in rates for MGP site remediation were greater than remediation costs due to the timing of project completion.

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Central Hudson's net cash used in investing activities of $28.3 million and $26.6 million in the three months ended March 31, 2013 and 2012, respectively, was primarily for investments in Central Hudson's electric and natural gas transmission and distribution systems.

Central Hudson's net cash provided by financing activities was $12.1 million and $68.7 million, respectively, for the three months ended March 31, 2013 and 2012.  At the end of the first quarter of 2012, Central Hudson undertook additional short-term borrowings of $36.0 million from uncommitted lines of credit to fund the repayment of maturing notes as well as issuing $48.0 million of its Series G Medium Term Notes.  The proceeds of the sale of the additional notes were used by Central Hudson to refinance short-term borrowings in April 2012 and to redeem preferred stock.  Also, in the first three months of 2013 Central Hudson paid dividends of $5.0 million to parent CH Energy Group while comparatively, no dividends were paid in to parent the first three months of 2012.  From time to time Central Hudson borrows from its parent CH Energy Group on an intercompany demand note and for the three months ended March 31, 2012 Central Hudson borrowed $20.0 million under this program with no comparable activity in the current year.  Central Hudson redeemed $9.7 million of preferred stock in the three months ended March 31, 2013 while no preferred stock was redeemed during the same period in 2012.  Finally, CH Energy Group's financing activities in the three months ended March 2012 included final settlement costs associated with the ASR program of $3.0 million.

Capitalization – Issuance of Treasury Stock

Effective July 1, 2011, employer matching contributions to an eligible employee's Savings Incentive Plan ("SIP") account could be paid in either cash or in CH Energy Group Common Stock, and CH Energy Group chose to meet its matching obligation in Common Stock.  Since March 1, 2012, the Company has been using cash for all of its matching obligations, except for matching associated with classified employees of Central Hudson.  The classified employees will continue to receive matching contributions in CH Energy Group Common Stock.  As of March 31, 2013, 44,786 shares had been issued from treasury related to employer matching contributions, of which 3,425 shares were issued in 2013.

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For information regarding equity compensation and the purchase of treasury shares, see Note 11 - "Equity Based Compensation" of this Quarterly Report on Form 10-Q.

Financing Program

CH Energy Group believes that it is well positioned with a strong balance sheet and strong liquidity.  Significant capacity is available on CH Energy Group's and Central Hudson's committed credit facilities.  Central Hudson's investment-grade credit ratings help facilitate access to long-term debt.  However, management can make no assurance in regards to the continued availability of financing or the terms and costs.

At March 31, 2013, CH Energy Group maintained a $100 million credit facility with JPMorgan Chase Bank, N.A., Bank of America, N.A., HSBC Bank USA, N.A. and KeyBank National Association as the participating banks. The credit facility has a term of up to three years.  The maximum borrowing amount reflects CH Energy Group's projected liquidity needs in accordance with its current business strategy.  If the participating lenders are unable to fulfill their commitments under this facility, funding may not be available as needed.

At March 31, 2013, Central Hudson maintained a $150 million committed revolving credit facility with JPMorgan Chase Bank, N.A., Bank of America, N.A., HSBC Bank USA, N.A., KeyBank National Association and RBS Citizens Bank, N.A. as the participating banks.  The credit facility has a term of up to five years.  If these lenders are unable to fulfill their commitments under these facilities, funding may not be available as needed.

Central Hudson's current senior unsecured debt rating/outlook is 'A'/CreditWatch negative by Standard & Poor's Rating Services ("Standard & Poor's"), 'A'/stable by Fitch Ratings and 'A3'/stable by Moody's Investors Service ("Moody's")¹.

On February 22, 2012, Standard & Poor's placed its ratings of Central Hudson on CreditWatch with negative implications, following the February 21, 2012 announcement that CH Energy Group had agreed to be acquired by Fortis. Standard & Poor's stated that they expect to resolve the CreditWatch listing as the merger nears completion and additional information is available.  CH Energy Group is unable to predict the outcome of that resolution.  The CreditWatch listing is not expected to have a material impact on Central Hudson's financial performance.

CH Energy Group and Central Hudson believe they will be able to meet their short-term and long-term cash requirements, assuming that Central Hudson's future rate plans reflect the costs of service, including a reasonable return on invested capital.

¹ These ratings reflect only the views of the rating agency issuing the rating, are not recommendations to buy, sell, or hold securities of Central Hudson and may be subject to revision or withdrawal at any time by the rating agency issuing the rating.  Each rating should be evaluated independently of any other rating.

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On March 21, 2013, Central Hudson redeemed its two outstanding series of preferred stock.  Registered holders of 4 1/2% Cumulative Preferred Stock received $107.00 per share plus accrued and unpaid dividends to the redemption date in the amount of $1.00 per share, for a total redemption price of $108.00 per share.  Registered holders of 4.75% Cumulative Preferred Stock received $106.75 per share plus accrued and unpaid dividends to the redemption date in the amount of $1.056 per share, for a total redemption price of $107.806 per share.  The premium paid in connection with the redemption of the preferred stock was recorded as a reduction of Retained Earnings on Central Hudson's Balance Sheet and as Premium on Preferred Stock Redemption on Central Hudson's Income Statement.

For additional information related to CH Energy Group's and Central Hudson's financing program, please see Note 7 – "Short-term Borrowing Arrangements," Note 8 – "Capitalization – Common and Preferred Stock" and Note 9 – "Capitalization – Long-term Debt" to the Financial Statements of the Corporations' 10-K Annual Report.

NYSERDA

Central Hudson's outstanding Series B NYSERDA Bonds total $33.7 million at March 31, 2013.  These bonds are tax-exempt multi-modal bonds that are currently in a variable rate mode.  In its Orders, the PSC has authorized deferral accounting treatment for variations in the interest costs from these bonds.  As such, variations between the actual interest rates on these bonds and the interest rate included in the current delivery rate structure for these bonds are deferred for future recovery from or refund to customers and do not have any impact on earnings.

To mitigate the potential cash flow impact from unexpected increases in short-term interest rates on Series B NYSERDA Bonds, on March 26, 2012, Central Hudson purchased an interest rate cap based on an index of short-term tax-exempt debt.  The rate cap is two years in length with a notional amount aligned with Series B and will expire on April 1, 2014.  The cap is based on the monthly weighted average of an index of tax-exempt variable rate debt, multiplied by 175%.  Central Hudson would receive a payout if the adjusted index exceeds 5.0% for a given month.  This rate cap replaces an expiring rate cap with substantially similar terms.

REGULATORY MATTERS – PSC PROCEEDINGS

Fortis – Central Hudson Gas & Electric Corporation Section 70 Joint Petition

(Case 12-M-0192 – Proceeding on the Joint Petition for Approval of the Acquisition of CH Energy Group, Inc. by Fortis Inc. and Related Transactions)

Background:  On April 20, 2012, CH Energy Group, Central Hudson, Fortis, FortisUS, and Cascade Acquisition Sub Inc., submitted a joint petition to the PSC for approval of the acquisition of CH Energy Group by Fortis and related transactions.  The petition describes how the acquisition of Central Hudson by Fortis will produce benefits for constituencies that include customers, employees and communities in Central Hudson's service territory as well as positive public benefits.  The petition categorizes the public benefits into three major areas: 1) FortisUS' commitments and intention to preserve and build on the existing strength of Central Hudson as a "stand-alone" company, 2) comprehensive financial protections to mitigate any potential financial risks of the merger consistent with the PSC's disposition of specific issues that have arisen in prior utility merger proceedings in New York State and 3) identifiable financial customer benefits resulting from avoidance of costs otherwise owed to customers by shareholders and cost savings made possible by the merger.  The petition includes proposals and commitments that effectively mitigate any potential risks to Central Hudson's customers from foreign holding company ownership and rate increase risk.

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Notable Activity:

Pursuant to the schedule adopted by the ALJs in the proceeding:

· On October 12, 2012, the PSC's Staff and other interested parties filed testimony and comments regarding the proposed acquisition.

· On November 5, 2012, the PSC Trial Staff filed Supplemental Testimony and Exhibits to correct errors related to their calculation of a Public Benefit Adjustment.

· On November 27, 2012, Petitioners submitted Reply Comments and Rebuttal Testimony and PSC Staff filed Rebuttal Testimony.

· On December 4, 2012, PSC filed surrebuttal testimony.

· Parties filed their lists of Disputed Issues of Material Fact on December 4, 2012.

· Pursuant to a Notice of Potential Settlement filed by the Petitioners on December 12, 2012, a series of settlement discussions were held between December 17, 2012 and January 11, 2013.

· On January 25, 2013, a Joint Proposal with the Company, Fortis, PSC Staff, Multiple Intervenors, the Department of State Utility Intervention Unit (consumer advocate), and Dutchess, Orange and Ulster counties as signatories, was submitted to the PSC.  The signatory parties have concluded that, based on the terms of the Settlement Agreement, the acquisition is in the public interest pursuant to the New York State Public Service Law, Section 70, and recommended approval by the Commission.

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The major components of the Joint Proposal include:

· Quantified benefits, in addition to a one-year rate freeze for the period July 1, 2013 through June 30, 2014 including:

- synergy savings/guaranteed future rate mitigation of $1.85 million per year for 5 years, totaling $9.25 million;

- $35 million to write off existing deferred regulatory assets and to provide additional future rate mitigation;

- establishment of a Community Benefit Fund of $5 million to be used for economic development and low income programs;

- earnings sharing was modified to reduce the threshold from 10.5% to 10% with 50/50 sharing beginning at 10%; and

- a provision that Central Hudson file a formal Superstorm Sandy deferral petition as soon as reasonably practicable for review by the Commission on an expedited basis.  This petition was filed on February 6, 2013.

The Joint Proposal also includes various governance, corporate and financial protection conditions.  These protections include goodwill and acquisition cost conditions, credit quality and dividend restriction conditions, money pooling conditions and establishing a special class of preferred stock.  In addition, the Joint Proposal established provisions for financial transparency and reporting, affiliate transactions, cost allocations and code of conduct.  Finally, the terms of the Joint Proposal provide additional customer service protections and benefits

· Statements in Support/Opposition to the Joint Proposal were filed February 8, 2013, with Statement Replies filed February 15, 2013.

· Public Statement Hearings were held in Poughkeepsie and Kingston on February 21, 2013.  On April 2, 2013, the Commission issued a notice of additional Public Statement Hearings to be held in Poughkeepsie on April 17, 2013 and in Kingston on April 18, 2013.

· The deadline for submission of public comments in the proceeding was extended to May 1, 2013 by the Commission in a notice issued March 22, 2013.

· On April 24, 2013, the PSC issued notice that a recommended decision will be issued.

On May 3, 2013 the Recommended Decision ("RD") of the two Administrative Law Judges ("ALJs") – an advisory document – was issued by the PSC.  The RD states that, in its current form, the Joint Proposal does not meet the public interest test as required by New York State Public Service Law, Section 70, but also states that the ALJs recommend the Commission consider adopting the Joint Proposal subject to modifications that would alter the transaction's balance of risks and benefits.  In the RD, the ALJs' statements included the following regarding the current terms of the Joint Proposal in relation to the public interest:

· Customer Benefits include:

- Synergy savings of $9.25 million;

- Rate mitigation of $35 million; and

- Economic development funding of $5 million.

· The RD's concerns include the following Residual Risks:

- Loss of local ownership and loss of goodwill toward the company, compromising management's ability to perform its service obligations to customers.

- Workforce uncertainty regarding job security beyond the 2-year employment commitment in the joint proposal.

- Complications in communications and data availability required for effective regulatory oversight due to foreign ownership.

- Lack of public confidence in the putative future benefits of the Joint Proposal.

Management believes that the concerns expressed in the RD can be resolved.

· Briefs on exceptions to the RD are due May 17, 2013 and briefs opposing exceptions are due on May 24, 2013.

· A PSC order regarding the Joint Proposal and closing of the merger are expected in the second quarter of 2013.

Potential Impacts:  Central Hudson believes the merger is in the public interest.  While no assurance regarding the closing can be given until a final PSC Order is issued, the Company continues to anticipate that the Commission will review and approve the merger in the second quarter of 2013 in time for the closing to occur in the second quarter of 2013.  Under the terms of the merger agreement, Fortis must close the transaction if all conditions precedent are met, including PSC approval, and a material adverse effect has not occurred.

Failure to complete the acquisition could negatively affect our share price, including by reducing it to a level at or below the trading range preceding the announcement of the Fortis transaction.

Petition of Central Hudson Gas & Electric Corporation for Commission Approval of Deferred Incremental Costs Associated with Superstorm Sandy

(Case 13-E-0048)

Background:  On October 29, 2012, Central Hudson's service territory was impacted by Superstorm Sandy, and approximately 103,000 electric customers were affected.  The Sandy storm costs were included in the estimate of $22 million storm costs identified in the $35 million of regulatory liabilities to be funded by Fortis. Consistent with the Joint Proposal, on February 6, 2013, Central Hudson filed a petition with the PSC seeking expedited Commission approval to recover $9.7 million of incremental electric storm restoration expense, with carrying charges.  These storm costs represent the amount Central Hudson deferred on its books as of December 31, 2012, based on actual costs incurred, bills received and an estimate for bills outstanding and are above the respective rate allowance during the twelve months ended June 30, 2013, which is the third rate year established by the PSC in its approval of a Joint Proposal in Case 09-E-0588. The Company believes the incremental costs associated with this storm meet the PSC's criteria for deferral: 1) the amount is incremental to the amount in rates; 2) the incremental amount is material and extraordinary in nature and 3) the utility's earnings are below the authorized rate of return on common equity.

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Potential Impacts:  If the PSC approves any amount less than the $9.7 million reflected in the petition, Central Hudson's expenses would increase by the unapproved amount.

Petition of Central Hudson Gas & Electric Corporation for Commission Approval of Deferred Incremental Costs Associated with Tropical Storm Irene

(Case 11-E-0651)

Petition of Central Hudson Gas & Electric Corporation for Commission Approval of Deferral of October 29, 2011 SnowFall Costs

(Case 12-M-0204)

Background:  On October 29, 2011, Central Hudson experienced an unusual fall storm with snow accumulations of up to 20 inches in the service territory, resulting in electric service outages to over 150,000 customers, extensive damage to the electric system and significant restoration costs.  Following Tropical Storm Irene, the October snowstorm represented the second extraordinary storm event that occurred within the rate year.  Central Hudson filed a petition with the PSC to defer for future recovery with carrying charges the $8.6 million of total incremental electric storm restoration expense.  However, because the petition requested the PSC to deviate from its prior precedents, the Company was aware that the amount the PSC granted could have been lower.  Accordingly, management deferred only the portion of the incremental costs that strictly follows Commission practice used in the Company's previous requests to defer incremental storm costs.  Approximately $3.7 million and $3.3 million of incremental restoration expense associated with this storm was expensed in 2011 and 2012, respectively, so that the return on common equity for the twelve months ending June 30, 2012 did not exceed the authorized rate of return of 10%.

Background:  In late August 2011, Central Hudson's service territory was affected by Tropical Storm Irene, disrupting service to approximately 180,000 customers.  On November 28, 2011 Central Hudson filed a petition with the PSC seeking to defer for future recovery with carrying charges for the estimated $11.4 million of incremental electric storm restoration expense above the respective rate allowance during the twelve months ended June 30, 2012.

PSC Orders:  On April 22, 2013, the Commission issued Orders approving deferral of $8.9 million and denying deferral of $3.7 million of the incremental electric storm restoration expense related to Tropical Storm Irene and the October snowstorm.  Regarding the majority of the disallowed costs, the PSC's decision stated that the Company did not meet the third prong requirement which requires the Company not being in an over earnings position.  The Commission adopted a staff recommendation to exclude ratemaking normalization adjustments for purposes of calculating authorized electric regulatory earnings, and therefore denied a portion of these petitioned deferrals based on this third prong criterion.  In addition, the PSC's Order stated that approximately $0.6 million of the costs related to Tropical Storm Irene should have been allocated to a separate storm, Tropical Storm Lee, and that this separate amount did not meet the materiality threshold for recovery.  Central Hudson expects to file a petition for reconsideration and rehearing on the PSC's April 22, 2013 Order challenging the exclusion of the Company's normalization adjustments used to measure earnings.  The petition will seek rehearing for reconsideration and recovery of $3.7 million of costs denied by the Commission for deferral accounting treatment.  The Company believes that it is entitled to fully recover all of these incremental electric storm restoration expenses; however Central Hudson cannot predict the final outcome of this proceeding.

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Other PSC Proceedings

For the quarter ended March 31, 2013, there has been no significant activity related to the following proceedings:

· Advanced Metering Infrastructure

· The American Recovery and Reinvestment Act of 2009

· Management Audit

· Energy Efficiency Portfolio Standard and State Energy Planning

· SIR Proceeding

· Gas Expansion Case

· AC Transmission Upgrades Proceeding

· Moreland Commission

OTHER MATTERS

Changes in Accounting Standards

See Note 1 – "Summary of Significant Accounting Policies" and Note 3 – "New Accounting Guidance" for discussion of relevant changes, which discussion is incorporated by reference herein.

Off-Balance Sheet Arrangements

CH Energy Group and Central Hudson do not have any off-balance sheet arrangements.

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Climate

While it is possible that some form of global climate change program will be adopted at the federal level in the next term of Congress, it is too early to determine what impact such program will have on CH Energy Group.  It should be noted, however, that the Company's calculated CO₂ emission levels are relatively small, mainly because the Company does not generate electricity in significant quantities and the electricity it does generate is primarily from zero emission hydroelectric plants.  Therefore, federally mandated greenhouse gas reductions or limits on CO₂ emissions are not expected to have a material impact on the Company's financial position or results of operations.  However, the Company can make no prediction as to the outcome of this matter.  If the cost of CO₂ emissions causes purchased electricity and natural gas costs to rise, such increases are expected to be collected through automatic adjustment clauses.  If sales are depressed by higher costs through price elasticity, the RDMs are expected to prevent an earnings impact on the Company.

FORWARD-LOOKING STATEMENTS

Statements included in this Quarterly Report on Form 10-Q and any documents incorporated by reference which are not historical in nature are intended to be, and are hereby identified as, "forward-looking statements" for purposes of the safe harbor provided by Section 21E of the Exchange Act. Forward-looking statements may be identified by words including "anticipates," "intends," "estimates," "believes," "projects," "expects," "plans," "assumes," "seeks," and similar expressions.  Forward-looking statements including, without limitation, those relating to CH Energy Group's and Central Hudson's future business prospects, revenues, proceeds, working capital, investment valuations, liquidity, income, and margins, as well as the acquisition by a subsidiary of Fortis Inc. and the expected timing of the transaction, are subject to certain risks and uncertainties that could cause actual results to differ materially from those indicated in the forward-looking statements, due to several important factors, including those identified from time to time in the forward-looking statements. Those factors include, but are not limited to: the possibility that various conditions precedent to the consummation of the proposed Fortis transaction will not be satisfied or waived, including regulatory approvals of the proposed Fortis transaction and the timing and terms thereof; the impact of delay or failure to complete the proposed Fortis transaction on CH Energy Group's stock price; the costs associated with the proposed Fortis transaction; deviations from normal seasonal weather and storm activity; fuel prices; energy supply and demand; potential future acquisitions; legislative, regulatory, and competitive developments; interest rates; access to capital; market risks; electric and natural gas industry restructuring and cost recovery; the ability to obtain adequate and timely rate relief; changes in fuel supply or costs including future market prices for energy, capacity, and ancillary services; the success of strategies to satisfy electricity, natural gas, fuel oil, and propane requirements; the outcome of pending litigation and certain environmental matters, particularly the status of inactive hazardous waste disposal sites and waste site remediation requirements; and certain presently unknown or unforeseen factors, including, but not limited to, acts of terrorism.  CH Energy Group and Central Hudson undertake no obligation to update publicly any forward-looking statements, whether as a result of new information, future events, or otherwise.  Given these uncertainties, undue reliance should not be placed on the forward-looking statements.

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Additional Information about the Fortis Transaction and Where to Find It

In connection with the proposed acquisition of CH Energy Group by Fortis, CH Energy Group filed a definitive proxy statement with the SEC on May 9, 2012, and has filed other relevant materials with the SEC as well.  Investors and stockholders of CH Energy Group are urged to read the proxy statement and other relevant materials filed with the SEC because they contain important information about the proposed acquisition and related matters.  Investors and stockholders may obtain a free copy of the proxy statement and other documents filed by CH Energy Group, at the SEC's Web site, www.sec.gov.  These documents can also be obtained by investors and stockholders free of charge from CH Energy Group at CH Energy Group's website at www.chenergygroup.com, or by contacting CH Energy Group's Shareholder Relations Department at (845) 486-5204.

ITEM 3 - Quantitative and Qualitative Disclosures About Market Risk

Reference is made to Part II, Item 7A of the Corporations' 10-K Annual Report for a discussion of market risk.  The practices employed by CH Energy Group and Central Hudson to mitigate these risks - which were discussed in the Corporations' 10-K Annual Report - continue to operate effectively.  For related discussion on this activity, see, in the Financial Statements of the Corporations' 10-K Annual Report, Note 14 – "Accounting for Derivative Instruments and Hedging Activities" and Item 7 – "Management's Discussion and Analysis of Financial Condition and Results of Operations" under the sub-caption "Capital Resources and Liquidity," and Note 9 – "Capitalization - Long-Term Debt" and Item 2 – "Management's Discussion and Analysis of Financial Condition and Results of Operations" under the sub-caption "Financing Program" of this Quarterly Report on Form 10-Q.

ITEM 4 – Controls and Procedures

The Chief Executive Officer and Chief Financial Officer of CH Energy Group and Central Hudson evaluated the effectiveness of the disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended) as of the end of the period covered by this Quarterly Report on Form 10-Q and based on the evaluation, concluded that, as of the end of the period covered by this Quarterly Report on Form 10-Q, the Corporations' controls and procedures are effective.

There were no changes to the Corporations' internal control over financial reporting that occurred during the Corporations' last fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Corporations' internal control over financial reporting.

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PART II – OTHER INFORMATION

ITEM 1 – Legal Proceedings

For information about developments regarding certain legal proceedings, see Item 3 ("Legal Proceedings") of the Corporations' 10-K Annual Report, and Note 12 – "Commitments and Contingencies" of that 10-K and/or Note 12 – "Commitments and Contingencies" of this Quarterly Report on Form 10-Q.

ITEM 1A – Risk Factors

RISKS RELATED TO THE PROPOSED ACQUISITION BY FORTIS, INC.

We May Be Unable to Satisfy the Conditions or Obtain the Approvals Required to Complete the Proposed Acquisition

While the proposed acquisition has been approved by CH Energy Group shareholders, the Federal Energy Regulatory Commission and the Committee on Foreign Investment in the United States, the approval of the PSC has not yet been obtained.  The PSC may not approve the acquisition or may seek to impose conditions on the completion of the transaction, which could cause the conditions to the acquisition to not be satisfied or which could delay or increase the cost of the transaction.  In addition, the occurrence of a material adverse effect could result in a termination of the agreement by Fortis.

The Proposed Acquisition May Not Be Completed, Which May Have a Material Adverse Effect on Our Share Price

Failure to complete the acquisition could negatively affect our share price, including by reducing it to a level at or below the trading range preceding the announcement of the Fortis transaction.

Termination of the Proposed Acquisition Could Result in CH Energy Group Being Required to Pay Termination Fees to Fortis

CH Energy Group will be obligated to reimburse up to $4 million of FortisUS' expenses if (i) FortisUS or CH Energy Group terminates the merger agreement because the acquisition has not been completed by the outside date of August 20, 2013 or FortisUS terminates the merger agreement based on a breach of the merger agreement by CH Energy Group, and (ii) a competing proposal has been made or publicly disclosed and not withdrawn prior to the termination of the merger agreement or applicable breach.  In addition, if within twelve months after such termination, a definitive agreement providing for an acquisition transaction is entered into, or an acquisition transaction is consummated by CH Energy Group with, the person who made the acquisition proposal prior to such termination or applicable breach or with any other third party making an acquisition proposal within three months following such termination, CH Energy Group will be obligated to pay FortisUS a termination fee of $19.7 million (less any expense reimbursement previously paid).  In no event will more than one termination fee be payable.

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For a discussion identifying additional risk factors that could cause actual results to differ materially from those anticipated, see the discussion under "Item 1A – Risk Factors" of the Corporations' 10-K Annual Report.

ITEM 2 - Unregistered Sales of Equity Securities and Use of Proceeds

The following table provides a summary of shares repurchased by CH Energy Group for the quarter ended March 31, 2013:

		Total Number of Shares Purchased(1)	Average Price Paid per Share(2)			Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number of Shares that May Yet be Purchased Under the Plans or Programs(3)
January 1-31, 2013	1	-	$	-		-	-
February 1-28, 2013	1	2,111	$	65.10		-	-
March 1-31, 2013	1	-	$	-		-	-
Total		2,111	$	65.10	1	-

(1)	Consists of shares surrendered to CH Energy Group in satisfaction of tax withholdings on the vesting of restricted shares.
(2)	Value at which reacquired shares of CH Energy Group's common stock credited on the date the stock was surrendered.
(3)	On July 31, 2007, the Board of Directors authorized the repurchase of up to 2,000,000 shares or approximately 13% of CH Energy Group's outstanding common stock on that date, from time to time, over the five year period ending July 31, 2012.  Upon expiration, the repurchase program was not extended under the terms of the merger agreement.

 

ITEM 4 – Mine Safety Disclosures

Not applicable.

ITEM 6 – Exhibits

Incorporated herein by reference to the Exhibit Index for this Quarterly Report on Form 10-Q, which is located immediately after the signature pages to this report.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.

	CH ENERGY GROUP, INC.
	(Registrant)
By:	/s/ Kimberly J. Wright
	Kimberly J. Wright
	Vice President - Accounting and Controller
	CENTRAL HUDSON GAS & ELECTRIC CORPORATION
	(Co-Registrant)
By:	/s/ Kimberly J. Wright
	Kimberly J. Wright
	Controller

Dated: May 8, 2013

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EXHIBIT INDEX

Following is the list of Exhibits, as required by Item 601 of Regulation S-K, filed as part of this Quarterly Report on Form 10-Q:

Exhibit No. (Regulation S-K Item 601 Designation)	Exhibit Description
31.1.1	Rule 13a-14(a)/15d-14(a) Certification by Mr. Lant.
31.1.2	Rule 13a-14(a)/15d-14(a) Certification by Mr. Capone.
31.2.1	Rule 13a-14(a)/15d-14(a) Certification by Mr. Lant.
31.2.2	Rule 13a-14(a)/15d-14(a) Certification by Mr. Capone.
32.1.1	Section 1350 Certification by Mr. Lant.
32.1.2	Section 1350 Certification by Mr. Capone.
32.2.1	Section 1350 Certification by Mr. Lant.
32.2.2	Section 1350 Certification by Mr. Capone.
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Extension Schema.
101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
101.DEF	XBRL Taxonomy Extension Definition Linkbase.
101.LAB	XBRL Taxonomy Extension Label Linkbase.
101.PRE	XBRL Taxonomy Extension Presentation Linkbase.

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EX-31.1.1

CERTIFICATIONS

EXHIBIT 31.1.1

I, Steven V. Lant, certify that:

1.  I have reviewed this Quarterly Report on Form 10-Q of CH Energy Group, Inc.;

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the Registrant as of, and for, the periods presented in this report;

4.  The Registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the Registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the Registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the Registrant's internal control over financial reporting that occurred during the Registrant's most recent fiscal quarter (the Registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the Registrant's internal control over financial reporting; and

5.  The Registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the Registrant's auditors and the audit committee of the Registrant's boards of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant's internal control over financial reporting.

Date:  May 8, 2013

/s/ Steven V. Lant

Steven V. Lant

Chairman of the Board, President and

Chief Executive Officer

EX-31.1.2

CERTIFICATIONS

EXHIBIT 31.1.2

I, Christopher M. Capone, certify that:

1.  I have reviewed this Quarterly Report on Form 10-Q of CH Energy Group, Inc.;

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the Registrant as of, and for, the periods presented in this report;

4.  The Registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the Registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the Registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the Registrant's internal control over financial reporting that occurred during the Registrant's most recent fiscal quarter (the Registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the Registrant's internal control over financial reporting; and

5.  The Registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the Registrant's auditors and the audit committee of the Registrant's boards of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant's internal control over financial reporting.

Date:  May 8, 2013

/s/ Christopher M. Capone

Christopher M. Capone

Executive Vice President and Chief Financial Officer

EX-31.2.1

CERTIFICATIONS

EXHIBIT 31.2.1

I, Steven V. Lant, certify that:

1.  I have reviewed this Quarterly Report on Form 10-Q of Central Hudson Gas & Electric Corporation;

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the Registrant as of, and for, the periods presented in this report;

4.  The Registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the Registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the Registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the Registrant's internal control over financial reporting that occurred during the Registrant's most recent fiscal quarter (the Registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the Registrant's internal control over financial reporting; and

5.  The Registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the Registrant's auditors and the audit committee of the Registrant's boards of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant's internal control over financial reporting.

Date:  May 8, 2013

/s/ Steven V. Lant

Steven V. Lant

Chairman of the Board and Chief Executive Officer

EX-31.2.2

CERTIFICATIONS

EXHIBIT 31.2.2

I, Christopher M. Capone, certify that:

1.  I have reviewed this Quarterly Report on Form 10-Q of Central Hudson Gas & Electric Corporation;

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the Registrant as of, and for, the periods presented in this report;

4.  The Registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the Registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the Registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the Registrant's internal control over financial reporting that occurred during the Registrant's most recent fiscal quarter (the Registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the Registrant's internal control over financial reporting; and

5.  The Registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the Registrant's auditors and the audit committee of the Registrant's boards of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant's internal control over financial reporting.

Date:  May 8, 2013

/s/ Christopher M. Capone

Christopher M. Capone

Executive Vice President and Chief Financial Officer

EX-32.1.1

CERTIFICATIONS

EXHIBIT 32.1.1

I, Steven V. Lant, do hereby certify in accordance with 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. The Quarterly Report on Form 10-Q of CH Energy Group, Inc. (the "Company") for the period ended March 31, 2013 (the "Quarterly Report") fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

2. The information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:  May 8, 2013

/s/ Steven V. Lant

Steven V. Lant

Chairman of the Board, President and

Chief Executive Officer

EX-32.1.2

CERTIFICATIONS

EXHIBIT 32.1.2

I, Christopher M. Capone, do hereby certify in accordance with 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. The Quarterly Report on Form 10-Q of CH Energy Group, Inc. (the "Company") for the period ended March 31, 2013 (the "Quarterly Report") fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

2. The information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:  May 8, 2013

/s/ Christopher M. Capone

Christopher M. Capone

Executive Vice President and Chief Financial Officer

EX-32.2.1

CERTIFICATIONS

EXHIBIT 32.2.1

I, Steven V. Lant, do hereby certify in accordance with 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. The Quarterly Report on Form 10-Q of Central Hudson Gas & Electric Corporation (the "Company") for the period ended March 31, 2013 (the "Quarterly Report") fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

2. The information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:  May 8, 2013

/s/ Steven V. Lant

Steven V. Lant

Chairman of the Board and Chief Executive Officer

EX-32.2.2

CERTIFICATIONS

EXHIBIT 32.2.2

I, Christopher M. Capone, do hereby certify in accordance with 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. The Quarterly Report on Form 10-Q of Central Hudson Gas & Electric Corporation (the "Company") for the period ended March 31, 2013 (the "Quarterly Report") fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

2. The information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:  May 8, 2013

/s/ Christopher M. Capone

Christopher M. Capone

Executive Vice President and Chief Financial Officer

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Summary of Significant Accounting Policies (Details) (USD $)	3 Months Ended			12 Months Ended
	Mar. 31, 2013		Mar. 31, 2012	Dec. 31, 2012	Mar. 27, 2013	Oct. 02, 2012	Feb. 21, 2012
Pending Merger with Fortis Inc. [Abstract]
Merger with Fortis, price per share (in dollars per share)							$ 65
Expired waiting period under HartScottRodino Antitrust Improvements Act						30 days
Reclassification [Abstract]
Reclassification adjustment			$ (10,600,000)
Revenue Recognition [Abstract]
Deferred revenue balances	3,936,000		3,853,000	4,801,000
Term of customer contract (in months)	12 months
Public Utilities, Inventory [Line Items]
Inventory	17,654,000		19,689,000	24,496,000
Depreciation and Amortization [Abstract]
Regulatory liabilities	118,400,000		110,509,000	105,460,000
Earnings Per Share [Abstract]
Average dilutive effect of stock options, performance shares and restricted shares (in shares)	213,908		260,259
Stock options excluded from the calculation of diluted earnings per share (in shares)			0
Common Stock Dividends [Abstract]
Common stock, dividends per share (in dollars per share)					$ 55.5
Maximum percentage of average annual income that may be paid to parent (in hundredths)				100.00%
Central Hudson's maximum dividend payment				45,100,000
Reduced percentage of average annual income (in hundredths)				75.00%
Central Hudson dividends declared and paid to the parent	5,000,000
Heating oil, propane, other petroleum products, weather and commodity hedges [Member]
Guarantees [Abstract]
Maximum Potential Payments	30,650,000	[1]
Outstanding Liabilities	8,555,000	[1]
Deferred cost of removal [Member]
Depreciation and Amortization [Abstract]
Regulatory liabilities	44,795,000		42,748,000	43,392,000
Natural gas [Member]
Public Utilities, Inventory [Line Items]
Inventory	2,759,000		7,322,000	7,638,000
Petroleum products and propane [Member]
Public Utilities, Inventory [Line Items]
Inventory	2,098,000		2,115,000	3,942,000
Fuel used in electric generation [Member]
Public Utilities, Inventory [Line Items]
Inventory	293,000		286,000	295,000
Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	12,504,000		9,966,000	12,621,000
Central Hudson [Member]
Public Utilities, Inventory [Line Items]
Inventory	14,194,000		16,389,000	19,264,000
Common Stock Dividends [Abstract]
Central Hudson dividends declared and paid to the parent	5,000,000		0
Central Hudson [Member] | Natural gas [Member]
Public Utilities, Inventory [Line Items]
Inventory	2,759,000		7,322,000	7,638,000
Central Hudson [Member] | Petroleum products and propane [Member]
Public Utilities, Inventory [Line Items]
Inventory	0		0	0
Central Hudson [Member] | Fuel used in electric generation [Member]
Public Utilities, Inventory [Line Items]
Inventory	293,000		286,000	295,000
Central Hudson [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	$ 11,142,000		$ 8,781,000	$ 11,331,000

[1] Balance included in CH Energy Group's Consolidated Balance Sheet.

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Subsequent Events (Details) (Subsequent Event [Member], Central Hudson [Member], USD $) In Millions, unless otherwise specified	1 Months Ended
	May 08, 2013
Subsequent Event [Line Items]
Subsequent event, date	Apr. 24, 2013
Subsequent event, description	the Commission issued a notice stating that the Administrative Law Judges ("ALJs") assigned to this matter would prepare a Recommended Decision ("RD") for the Commission. On May 3, 2013 the Recommended Decision of the two Administrative Law Judges - an advisory document - was issued by the PSC.
Dividend Declared [Member]
Subsequent Event [Line Items]
Subsequent event, date	Apr. 18, 2013
Subsequent event, description	Central Hudson's Board of Directors approved a $5.0 million dividend payment to parent CH Energy Group
Subsequent event, amount	5

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Post-Employment Benefits (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013		Mar. 31, 2012		Dec. 31, 2012
Accrued pension costs [Abstract]
Accrued pension costs	$ (88,828)		$ (96,547)		$ (113,885)
Defined Benefit Plan Contributions [Abstract]
Contributions to the Retirement Plan	26,165		28,165
Asset allocation targets [Abstract]
Planned equity securities asset allocation by year end (in hundredths)	50.00%
Planned long duration fixed income asset allocation by year end (in hundredths)	50.00%
Equity Securities [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Actual Plan Asset Allocations (in hundredths)	51.20%				50.50%
Equity Securities [Member] | Minimum [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	45.00%
Equity Securities [Member] | Weighted Average [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	50.00%
Equity Securities [Member] | Maximum [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	55.00%
Debt Securities [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Actual Plan Asset Allocations (in hundredths)	47.40%				47.40%
Debt Securities [Member] | Minimum [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	45.00%
Debt Securities [Member] | Weighted Average [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	50.00%
Debt Securities [Member] | Maximum [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	55.00%
Other [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Actual Plan Asset Allocations (in hundredths)	1.40%	[1]			2.10%	[1]
Other [Member] | Minimum [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	0.00%	[1]
Other [Member] | Weighted Average [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	0.00%	[1]
Other [Member] | Maximum [Member]
Asset allocation targets [Abstract]
Target Plan Asset Allocations (in hundredths)	0.00%	[1]
Pension Benefits [Member]
Net periodic benefit costs [Abstract]
Service cost	3,073		2,741
Interest cost	5,732		6,177
Expected return on plan assets	(7,698)		(6,768)
Amortization of:
Prior service cost (credit)	433		501
Transitional obligation	0		0
Recognized actuarial loss	4,840		5,788
Net Periodic Benefit Cost	6,380		8,439
Funding status adjustments [Abstract]
Prefunded pension costs prior to funding status adjustment	44,956		49,996		25,172
Additional liability required	(133,784)		(146,543)		(139,057)
Total accrued pension costs	(88,828)		(96,547)		(113,885)
Total offset to additional liability - Regulatory assets - Pension Plan	133,784		146,543		139,057
Defined Benefit Plan Contributions [Abstract]
Contributions to the Retirement Plan	26,000		28,000
OPEB [Member]
Net periodic benefit costs [Abstract]
Service cost	760	[2]	644	[2]
Interest cost	1,382	[2]	1,662	[2]
Expected return on plan assets	(1,723)	[2]	(1,734)	[2]
Amortization of:
Prior service cost (credit)	(1,465)	[2]	(1,466)	[2]
Transitional obligation	2	[2]	641	[2]
Recognized actuarial loss	1,582	[2]	2,326	[2]
Net Periodic Benefit Cost	538	[2]	2,073	[2]
Defined Benefit Plan Contributions [Abstract]
Contributions to the OPEB plan	$ 0		$ 0

[1] Consists of temporary cash investments, as well as receivables for investments sold and interest, and payables for investments purchased, which have not settled as of that date.

[2] The OPEB amounts for all periods presented reflect the effect of the Medicare Prescription Drug Improvement and Modernization Act of 2003.

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Capitalization Common and Preferred Stock (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended			3 Months Ended				3 Months Ended		3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012 Common Stock [Member] Repurchase Program [Member]	Jul. 31, 2007 Common Stock [Member] Repurchase Program [Member]	Mar. 31, 2013 Common Stock [Member] Employees Savings Inventive Plan (SIP) [Member]	Mar. 31, 2013 Central Hudson [Member]	Mar. 31, 2012 Central Hudson [Member]	Mar. 21, 2013 Central Hudson [Member] Cumulative Preferred Stock [Member]	Mar. 31, 2013 Central Hudson [Member] Cumulative Preferred Stock 450 Series [Member]	Mar. 21, 2013 Central Hudson [Member] Cumulative Preferred Stock 450 Series [Member]	Mar. 31, 2013 Central Hudson [Member] Cumulative Preferred Stock 475 Series [Member]	Mar. 21, 2013 Central Hudson [Member] Cumulative Preferred Stock 475 Series [Member]
Schedule of Capitalization, Equity [Line Items]
Common Stock Repurchase Program, number of shares authorized to be repurchased (in shares)			2,000,000
Percentage of outstanding Common Stock authorized to be repurchased (in hundredths)			13.00%
Cumulative shares purchased under the Repurchase Program (in shares)		948,676
Number of shares issued from treasury related to employer matching contribution (in shares)				44,786
Shares issued in employer matching contribution (in shares)				3,425
Number of series of preferred stock redeemed (in series)							2
Preferred Stock, Dividend Rate, Percentage (in hundredths)								4.50%		4.75%
Preferred stock, redemption price per share (in dollars per share)									$ 107.00		$ 106.75
Preferred Stock, Dividends, Per Share, Cash Paid (in dollars per share)								$ 1.00		$ 1.056
Total redemption price per share (in dollars per share)								$ 108.000		$ 107.806
Dividend payment to parent during the period	$ 5				$ 5	$ 0

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Post-Employment Benefits (Tables)

3 Months Ended

Mar. 31, 2013

Post-Employment Benefits [Abstract]

Net Periodic Benefit Cost

The following are the components of Central Hudson's net periodic benefit costs for its pension and OPEB plans for the three months ended March 31, 2013 and 2012 (In Thousands):

	Pension Benefits						OPEB(1)
	Three Months Ended March 31,						Three Months Ended March 31,
	2013			2012			2013			2012
Service cost	$	3,073		$	2,741		$	760		$	644
Interest cost		5,732			6,177			1,382			1,662
Expected return on plan assets		(7,698	)		(6,768	)		(1,723	)		(1,734	)
Amortization of:
Prior service cost (credit)		433			501			(1,465	)		(1,466	)
Transitional obligation		-			-			2			641
Recognized actuarial loss		4,840			5,788			1,582			2,326
Net Periodic Benefit Cost	$	6,380		$	8,439		$	538		$	2,073

(1) The OPEB amounts for all periods presented reflect the effect of the Medicare Prescription Drug Improvement and Modernization Act of 2003.

Accrued Pension Costs

The balance of Central Hudson's accrued pension costs (i.e., the under-funded status) is as follows (In Thousands):

	March 31,		December 31,		March 31,
	2013		2012		2012
Accrued pension costs	$	88,828	$	113,885	$	96,547

Impact of Funding Status Adjustments on the Balance Sheets

The following reflects the impact of the recording of funding status adjustments on the Balance Sheets of CH Energy Group and Central Hudson (In Thousands):

	March 31,			December 31,			March 31,
	2013			2012			2012
Prefunded pension costs prior to funding status adjustment	$	44,956		$	25,172		$	49,996
Additional liability required		(133,784	)		(139,057	)		(146,543	)
Total accrued pension costs	$	(88,828	)	$	(113,885	)	$	(96,547	)
Total offset to additional liability - Regulatory assets - Pension Plan	$	133,784		$	139,057		$	146,543

Contributions

Contributions for the three months ended March 31, 2013 and 2012 were as follows (In Thousands):

	Retirement Income Plan				OPEB
	Three Months Ended				Three Months Ended
	March 31,				March 31,
	2013		2012		2013		2012
Contributions	$	26,000	$	28,000	$	-	$	-

Retirement Plan, Actual and Target Asset Allocation

Asset allocation targets in effect for the three months ended March 31, 2013 as well as actual asset allocations as of March 31, 2013 and December 31, 2012 expressed as a percentage of the market value of the Retirement Plan's assets, are summarized in the table below:

Asset Class	December 31, 2012			Minimum			Target Average			Maximum			March 31, 2013
Equity Securities		50.5	%		45	%		50	%		55	%		51.2	%
Debt Securities		47.4	%		45	%		50	%		55	%		47.4	%
Other(1)		2.1	%		-	%		-	%		-	%		1.4	%

(1) Consists of temporary cash investments, as well as receivables for investments sold and interest, and payables for investments purchased, which have not settled as of that date.

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2013

Summary of Significant Accounting Policies [Abstract]

Revenue Recognition

Revenue Recognition

CH Energy Group's deferred revenue balances as of March 31, 2013, December 31, 2012 and March 31, 2012 were $3.9 million, $4.8 million and $3.9 million, respectively.  The deferred revenue balance will be recognized in CH Energy Group's operating revenues over the 12-month term of the respective customer contract.

As required by the PSC, Central Hudson records gross receipts tax revenues and expenses on a gross income statement presentation basis (i.e., included in both revenue and expenses).  Sales and use taxes for both Central Hudson and Griffith are accounted for on a net basis (excluded from revenue).

Depreciation and Amortization

Depreciation and Amortization

Current accounting guidance related to asset retirements precludes the recognition of expected future retirement obligations as a component of depreciation expense or accumulated depreciation.  Central Hudson, however, is required to use depreciation methods and rates approved by the PSC under regulatory accounting.  These depreciation rates include a charge for the cost of future removal and retirement of fixed assets.  In accordance with current accounting guidance for regulated operations, Central Hudson continues to accrue for the future cost of removal for its rate-regulated natural gas and electric utility assets.  In accordance with current accounting guidance related to asset retirements, Central Hudson has classified $44.8 million, $43.4 million, and $42.7 million of cost of removal as regulatory liabilities as of March 31, 2013, December 31, 2012, and March 31, 2012, respectively.  This liability represents the portion of the cost of removal charge in excess of the amount reported as an Asset Retirement Obligation under GAAP.

See Note 6 - "Goodwill and Other Intangible Assets" for further discussion of amortization of intangibles (other than goodwill).

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Commitments and Contingencies (Details) (USD $)				3 Months Ended		36 Months Ended			12 Months Ended		3 Months Ended				360 Months Ended	3 Months Ended		12 Months Ended		3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Mar. 31, 2013 Central Hudson [Member]		Jun. 30, 2013 Central Hudson [Member]	Dec. 31, 2012 Central Hudson [Member]	Mar. 31, 2012 Central Hudson [Member]	Dec. 31, 2000 Central Hudson [Member] Soil and Groundwater Cleanup [Member] T	Mar. 31, 2013 Central Hudson [Member] Asbestos Litigation [Member]	Mar. 31, 2013 Central Hudson [Member] MGP Sites 1, 2, 3, 4 [Member]		Mar. 31, 2013 Central Hudson [Member] MGP Sites 5, 6 [Member]		Dec. 31, 2042 Central Hudson [Member] MGP Sites 2, 3, 4, 5, 6 [Member]	Mar. 31, 2013 Central Hudson [Member] MGP Sites 1, 2, 3, 4, 5, 6 [Member]	Mar. 31, 2011 Griffith [Member]	Dec. 31, 2009 Griffith [Member]	Mar. 31, 2013 Griffith [Member]	Mar. 31, 2013 Central Hudson [Member] Electricity Purchase Commitments [Member]	Mar. 31, 2012 Central Hudson [Member] Electricity Purchase Commitments [Member]
Electricity Purchase Commitments [Abstract]
Cost of electricity purchased under contract																				$ 4,300,000	$ 5,200,000
Percentage of annual full-service customer electricity requirements purchased through contract (in hundredths)																				14.00%
Environmental Matters [Abstract]
Number of manufactured gas plant sites in franchise territory (in sites)				7
Accrual for environmental loss contingencies [Rollforward]
Liability recorded, beginning balance				13,953,000							12,210,000		1,743,000						1,400,000
Amounts spent in 2013				3,696,000	[1]						3,628,000	[1]	68,000	[1]
Liability adjustment				821,000							883,000		(62,000)
Liability recorded, ending balance				11,078,000							9,465,000		1,613,000						1,400,000
Current portion of liability	4,267,000	7,117,000	7,064,000	3,838,000			6,660,000	6,562,000			2,916,000		922,000						400,000
Long-term portion of liability	8,250,000	8,324,000	10,559,000	7,240,000			7,293,000	9,407,000			6,549,000		691,000
Legal fees not included in accrual for environmental loss																8,000
Percentage of confidence level															90.00%
Environmental Exit Costs, Anticipated Cost															152,000,000
Rate allowance for MGP Site Investigation and Remediation Costs over the three year period covered by the 2010 Rate Order						13,600,000
Settlement period (in years) per Rate Order						3 years
Total MGP Site Investigation and Remediation costs recovered				25,600,000
MGP Site Investigation and Remediation costs recovered during the period				1,200,000
Site investigation and remediation expense				3,700,000
Regulatory Asset	285,224,000	289,043,000	320,979,000	14,700,000
Amounts recovered from insurance				0		2,300,000
Little Britain Road property [Abstract]
Approximate amount of soil removed (in tons)									3,100
CHEC [Abstract]
Limitation within which certain claims must be brought (in years)																		P5Y
Aggregate deductible applicable to certain types of non-environmental claims																		800,000
Aggregate cap on indemnification obligation																		5,700,000
Environmental remediation costs reserved under the sale agreement																		2,600,000
Amount paid under environmental remediation cost obligation																			1,200,000
Reduction of reserve based on completion of an environmental study																	600,000
Reserve balance related to the divestiture																			$ 800,000
Asbestos litigation [Abstract]
Number of asbestos claims brought (in claims)										3,338
Number of asbestos claims pending (in claims)										1,166
Number of asbestos claims dismissed or discontinued without payment (in claims)										2,017
Number of asbestos claims settled (in claims)										155

[1] Amounts spent in 2013 as shown above do not include legal fees of approximately $8 thousand.

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Income Tax (Details) (USD $)	3 Months Ended
	Mar. 31, 2013		Mar. 31, 2012
Summary of activity related to uncertain tax positions [Roll Forward]
Balance at the beginning of the period	$ 2,000,000		$ 3,172,000
Adjustments related to tax accounting method change	47,000		2,000
Balance at the end of the period	2,047,000		3,174,000
Income Tax Reconciliation [Abstract]
Net Income Attributable to CH Energy Group	18,090,000		14,581,000
Net Income	18,946,000		14,823,000
Preferred Stock dividends of Central Hudson	92,000		242,000
Preferred Stock Redemption Premium	764,000		0
Federal income tax	7,465,000		0
State income tax	544,000		408,000
Deferred federal income tax	2,833,000		10,452,000
Deferred state income tax	323,000		809,000
Income before taxes	30,111,000		26,492,000
Computed federal tax at 35% statutory rate	10,539,000		9,272,000
State income tax net of federal tax benefit	879,000		1,293,000
Depreciation flow-through	891,000		797,000
Cost of Removal	(616,000)		(596,000)
Merger Transaction Costs	84,000		1,705,000
Other	(612,000)		(802,000)
Total income tax	11,165,000		11,669,000
Effective tax rate - federal (in hundredths)	34.20%		39.40%
Effective tax rate - state (in hundredths)	2.90%		4.60%
Effective tax rate - combined (in hundredths)	37.10%		44.00%
Merger related transaction costs	200,000		4,300,000
Central Hudson [Member]
Income Tax Reconciliation [Abstract]
Net Income	14,369,000		16,733,000
Preferred Stock dividends of Central Hudson	92,000		242,000
Preferred Stock Redemption Premium	764,000		0
Federal income tax	5,318,000		0
Deferred federal income tax	2,565,000		9,320,000
Deferred state income tax	901,000		1,433,000
Income before taxes	23,153,000		27,486,000
Computed federal tax at 35% statutory rate	8,104,000		9,620,000
State income tax net of federal tax benefit	901,000		1,433,000
Depreciation flow-through	891,000		797,000
Cost of Removal	(616,000)		(596,000)
Other	(496,000)		(501,000)
Total income tax	$ 8,784,000		$ 10,753,000
Effective tax rate - federal (in hundredths)	34.00%		33.90%
Effective tax rate - state (in hundredths)	3.90%		5.20%
Effective tax rate - combined (in hundredths)	37.90%		39.10%
Federal [Member]
Income Tax Contingency [Line Items]
Tax Years Open for Audit	2007	[1]
New York State [Member]
Income Tax Contingency [Line Items]
Tax Years Open for Audit	2009

[1] Federal tax filings for the years 2007 - 2011 are currently under audit.

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Accounting for Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2013

Accounting for Derivative Instruments and Hedging Activities [Abstract]

Electric and Gas Requirements Closed With Fixed Price Forward Purchases

The percentage of Central Hudson's electric and gas requirements covered with fixed price forward purchases is as follows:

Central Hudson	% of Requirement Hedged (1)
Electric Derivative Contracts:
April 2013 – December 2013		34.0	%
2014		28.8	%
2015		21.7	%
2016		7.2	%
2017		7.1	%
Natural Gas Derivative Contracts:
November 2013 – March 2014		2.3	%

(1) Projected coverage as of March 31, 2013.

Derivative Assets and Liabilities

The net presentation for CH Energy Group's and Central Hudson's derivative assets and liabilities as of March 31, 2013, December 31, 2012 and March 31, 2012 are as follows (In Thousands):

							Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Financial Position		Net Amount of Assets Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
As of March 31, 2013
Derivative Contracts:
Central Hudson - electric	$	5,822	$	-	$	5,822	$	608	$	-	$	5,214
Total Central Hudson Assets	$	5,822	$	-	$	5,822	$	608	$	-	$	5,214
Griffith - heating oil	$	3	$	-	$	3	$	-	$	-	$	3
Total CH Energy Group Assets	$	5,825	$	-	$	5,825	$	608	$	-	$	5,217
As of December 31, 2012
Derivative Contracts:
Central Hudson - electric	$	693	$	-	$	693	$	664	$	-	$	29
Central Hudson - gas		95		-		95		18		-		77
Total Central Hudson Assets	$	788	$	-	$	788	$	682	$	-	$	106
Griffith - heating oil	$	26	$	-	$	26	$	-	$	-	$	26
Total CH Energy Group Assets	$	814	$	-	$	814	$	682	$	-	$	132
As of March 31, 2012
Derivative Contracts:
Central Hudson - electric	$	-	$	-	$	-	$	-	$	-	$	-
Total Central Hudson Assets	$	-	$	-	$	-	$	-	$	-	$	-
Griffith - heating oil	$	9	$	-	$	9	$	-	$	-	$	9
Total CH Energy Group Assets	$	9	$	-	$	9	$	-	$	-	$	9

							Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Financial Position		Net Amount of Assets Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
As of March 31, 2013
Derivative Contracts:
Central Hudson - electric	$	608	$	-	$	608	$	608	$	-	$	-
Central Hudson - gas		2		-		2		-		-		2
Total Central Hudson Liabilities	$	610	$	-	$	610	$	608	$	-	$	2
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	610	$	-	$	610	$	608	$	-	$	2
As of December 31, 2012
Derivative Contracts:
Central Hudson - electric	$	1,367	$	-	$	1,367	$	664	$	-	$	703
Central Hudson - gas		110		-		110		18		-		92
Total Central Hudson Liabilities	$	1,477	$	-	$	1,477	$	682	$	-	$	795
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	1,477	$	-	$	1,477	$	682	$	-	$	795
As of March 31, 2012
Derivative Contracts:
Central Hudson - electric	$	23,792	$	-	$	23,792	$	-	$	-	$	23,792
Central Hudson - gas		14		-		14		-		-		14
Total Central Hudson Liabilities	$	23,806	$	-	$	23,806	$	-	$	-	$	23,806
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	23,806	$	-	$	23,806	$	-	$	-	$	23,806

Gross Fair Value of Derivative Instruments

Derivative contracts are measured at fair value on a recurring basis.  As of March 31, 2013, December 31, 2012, and March 31, 2012, CH Energy Group's and Central Hudson's derivative assets and liabilities by category and hierarchy level are as follows (In Thousands):

Asset or Liability Category	Fair Value			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
As of March 31, 2013(1)
Assets:
Derivative Contracts:
Central Hudson - electric	$	5,822		$	-		$	-	$	5,822
Total Central Hudson Assets	$	5,822		$	-		$	-	$	5,822
Griffith - heating oil	$	3		$	3		$	-	$	-
Total CH Energy Group Assets	$	5,825		$	3		$	-	$	5,822
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(608	)	$	-		$	-	$	(608	)
Central Hudson - natural gas		(2	)		(2	)		-		-
Total CH Energy Group and Central Hudson Liabilities	$	(610	)	$	(2	)	$	-	$	(608	)
As of December 31, 2012(1)
Assets:
Derivative Contracts:
Central Hudson - electric	$	693		$	-		$	-	$	693
Central Hudson - natural gas		95			95			-		-
Total Central Hudson Assets	$	788		$	95		$	-	$	693
Griffith - heating oil	$	26		$	26		$	-	$	-
Total CH Energy Group Assets	$	814		$	121		$	-	$	693
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(1,367	)	$	(110	)	$	-	$	(1,367	)
Central Hudson - natural gas		(110	)		-			-		-
Total CH Energy Group and Central Hudson Liabilities	$	(1,477	)	$	(110	)	$	-	$	(1,367	)
As of March 31, 2012(1)
Assets:
Derivative Contracts:
Griffith - heating oil	$	9		$	-		$	-	$	-
Total CH Energy Group Assets	$	9		$	-		$	-	$	-
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(23,792	)	$	-		$	-	$	(23,792	)
Central Hudson - natural gas		(14	)		(14	)		-		-
Total CH Energy Group and Central Hudson Liabilities	$	(23,806	)	$	(14	)	$	-	$	(23,792	)

(1) Interest rate cap agreement is not shown in the above table because the FMV at each period stated was zero.

Reconciliation of Fair Value of Liabilities Classified as Level 3

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value and classified as Level 3 in the fair value hierarchy (In Thousands):

	Three Months Ended
	March 31,
	2013			2012
Balance at Beginning of Period	$	(674	)	$	(16,830	)
Unrealized gains/(losses)		5,888			(6,962	)
Realized gains/(losses)		5,119			(7,654	)
Purchases		-			-
Issuances		-			-
Sales and settlements		(5,119	)		7,654
Transfers in and/or out of Level 3		-			-
Balance at End of Period	$	5,214		$	(23,792	)
The amount of total gains or losses for the period included in earnings attributable to the change in unrealized gains or losses relating to derivatives still held at end of period	$	-		$	-

The company did not have any transfers into or out of Levels 1 or 2.

The Effect of Derivative Instruments on the Statements of Income

For the three months ended March 31, 2013 and 2012, neither CH Energy Group nor Central Hudson had derivatives designated as hedging instruments.  The following table summarizes the effects of CH Energy Group and Central Hudson derivatives on the statements of income (In Thousands):

	Amount of Gain (Loss) Recognized as Increase/(Decrease) in the Income Statement
	Three Months Ended March 31,
	2013			2012			Location of Gain (Loss)
Central Hudson:
Electricity swap contracts	$	5,119		$	(7,654	)	Regulatory (asset)/liability(1)
Natural gas swap contracts		(44	)		(2,406	)	Regulatory (asset)/liability(1)
Total return swap contracts		-			617		Other-net
Total Central Hudson	$	5,075		$	(9,443	)
Griffith:
Heating oil call option contracts	$	(2	)	$	30		Purchased petroleum
Griffith other derivative financial instrument		-			-		Purchased petroleum
Total Griffith	$	(2	)	$	30
Total CH Energy Group	$	5,073		$	(9,413	)

(1) Realized gains and losses on Central Hudson's derivative instruments are conveyed to or recovered from customers through PSC authorized deferral accounting mechanisms, with an offset in revenue and on the balance sheet, and no impact on results of operations.

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Accounting for Derivative Instruments and Hedging Activities (Details) (USD $) In Thousands, unless otherwise specified				3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Mar. 31, 2013 Not Designated as Hedging Instrument [Member]	Mar. 31, 2012 Not Designated as Hedging Instrument [Member]	Mar. 31, 2013 Not Designated as Hedging Instrument [Member] Central Hudson [Member]	Mar. 31, 2012 Not Designated as Hedging Instrument [Member] Central Hudson [Member]	Mar. 31, 2013 Not Designated as Hedging Instrument [Member] Central Hudson [Member] Electricity Swap Contracts [Member] Regulatory Asset [Member]		Mar. 31, 2012 Not Designated as Hedging Instrument [Member] Central Hudson [Member] Electricity Swap Contracts [Member] Regulatory Asset [Member]		Mar. 31, 2013 Not Designated as Hedging Instrument [Member] Central Hudson [Member] Natural Gas Swap Contracts [Member] Regulatory Asset [Member]		Mar. 31, 2012 Not Designated as Hedging Instrument [Member] Central Hudson [Member] Natural Gas Swap Contracts [Member] Regulatory Asset [Member]		Mar. 31, 2013 Not Designated as Hedging Instrument [Member] Central Hudson [Member] Total Return Swap Contracts [Member] Other - net [Member]	Mar. 31, 2012 Not Designated as Hedging Instrument [Member] Central Hudson [Member] Total Return Swap Contracts [Member] Other - net [Member]	Mar. 31, 2013 Not Designated as Hedging Instrument [Member] Griffith [Member]	Mar. 31, 2012 Not Designated as Hedging Instrument [Member] Griffith [Member]	Mar. 31, 2013 Not Designated as Hedging Instrument [Member] Griffith [Member] Heating Oil Call Option Contracts [Member] Purchased Petroleum [Member]	Mar. 31, 2012 Not Designated as Hedging Instrument [Member] Griffith [Member] Heating Oil Call Option Contracts [Member] Purchased Petroleum [Member]	Mar. 31, 2013 Not Designated as Hedging Instrument [Member] Griffith [Member] Other Derivative Financial Instrument [Member] Purchased Petroleum [Member]	Mar. 31, 2012 Not Designated as Hedging Instrument [Member] Griffith [Member] Other Derivative Financial Instrument [Member] Purchased Petroleum [Member]	Mar. 31, 2013 Derivative Financial Instruments, Net Assets (Liabilities) [Member]	Mar. 31, 2012 Derivative Financial Instruments, Net Assets (Liabilities) [Member]	Mar. 31, 2013 Fair Value, Measurements, Recurring [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Significant Other Observable Inputs (Level 2) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Significant Other Observable Inputs (Level 2) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Significant Other Observable Inputs (Level 2) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Significant Unobservable Inputs (Level 3) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Significant Unobservable Inputs (Level 3) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Significant Unobservable Inputs (Level 3) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Central Hudson [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Significant Other Observable Inputs (Level 2) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Significant Other Observable Inputs (Level 2) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Significant Other Observable Inputs (Level 2) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Significant Unobservable Inputs (Level 3) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Significant Unobservable Inputs (Level 3) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Central Hudson [Member] Significant Unobservable Inputs (Level 3) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Griffith [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Griffith [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member] Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Griffith [Member] Significant Other Observable Inputs (Level 2) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member] Significant Other Observable Inputs (Level 2) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member] Significant Other Observable Inputs (Level 2) [Member]		Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Griffith [Member] Significant Unobservable Inputs (Level 3) [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member] Significant Unobservable Inputs (Level 3) [Member]		Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Griffith [Member] Significant Unobservable Inputs (Level 3) [Member]		Mar. 31, 2013 Central Hudson [Member]	Dec. 31, 2012 Central Hudson [Member]	Mar. 31, 2012 Central Hudson [Member]	Mar. 31, 2013 Electric Derivative Contracts [Member] Central Hudson [Member]	Dec. 31, 2012 Electric Derivative Contracts [Member] Central Hudson [Member]	Mar. 31, 2012 Electric Derivative Contracts [Member] Central Hudson [Member]	Mar. 31, 2013 Natural Gas Derivative Contracts [Member] Central Hudson [Member]	Dec. 31, 2012 Natural Gas Derivative Contracts [Member] Central Hudson [Member]	Mar. 31, 2012 Natural Gas Derivative Contracts [Member] Central Hudson [Member]	Mar. 31, 2013 Heating Oil Derivative Contracts [Member] Griffith [Member]	Dec. 31, 2012 Heating Oil Derivative Contracts [Member] Griffith [Member]	Mar. 31, 2012 Heating Oil Derivative Contracts [Member] Griffith [Member]	Mar. 31, 2013 Central Hudson [Member] Electric Derivative Contracts [Member] April 2013 - December 2013 [Member]		Mar. 31, 2013 Central Hudson [Member] Electric Derivative Contracts [Member] 2014 [Member]		Mar. 31, 2013 Central Hudson [Member] Electric Derivative Contracts [Member] 2015 [Member]		Mar. 31, 2013 Central Hudson [Member] Electric Derivative Contracts [Member] 2016 [Member]		Mar. 31, 2013 Central Hudson [Member] Electric Derivative Contracts [Member] 2017 [Member]		Mar. 31, 2013 Central Hudson [Member] Natural Gas Derivative Contracts [Member] November 2013 - March 2014 [Member]
Derivative [Line Items]
Percentage of requirement hedged (in hundredths)																																																																																																														34.00%	[1]	28.80%	[1]	21.70%	[1]	7.20%	[1]	7.10%	[1]	2.30%	[1]
Derivative Risks [Abstract]
Total number of master netting agreements held (in agreements)	19
Number of master netting agreements with credit-risk related contingent features (in agreements)	11
Offsetting Assets and Liabilities [Line Items]
Gross Amounts of Recognized Assets	$ 5,825	$ 814	$ 9																																																																																															$ 5,822	$ 788	$ 0	$ 5,822	$ 693	$ 0		$ 95		$ 3	$ 26	$ 9
Gross Amount of Assets as Offset in Statement of Financial Position	0	0	0																																																																																															0	0	0	0	0	0		0		0	0	0
Net Amounts of Assets Presented in the Statement of Financial Position	5,825	814	9																																																																																															5,822	788	0	5,822	693	0		95		3	26	9
Financial Instruments, Assets	608	682	0																																																																																															608	682	0	608	664	0		18		0	0	0
Cash Collateral Received	0	0	0																																																																																															0	0	0	0	0	0		0		0	0	0
Net Amount, Assets	5,217	132	9																																																																																															5,214	106	0	5,214	29	0		77		3	26	9
Gross Amounts of Recognized Liabilities	610	1,477	23,806																																																																																															610	1,477	23,806	608	1,367	23,792	2	110	14	0	0	0
Gross Amount of Liabilities as Offset in Statement of Financial Position	0	0	0																																																																																															0	0	0	0	0	0	0	0	0	0	0	0
Net Amount of Assets Presented in the Statement of Financial Position, Liabilities	610	1,477	23,806																																																																																															610	1,477	23,806	608	1,367	23,792	2	110	14	0	0	0
Financial Instruments, Liabilities	608	682	0																																																																																															608	682	0	608	664	0	0	18	0	0	0	0
Cash Collateral Received, Liabilities	0	0	0																																																																																															0	0	0	0	0	0	0	0	0	0	0	0
Net Amount, Liabilities	2	795	23,806																																																																																															2	795	23,806	0	703	23,792	2	92	14	0	0	0
Assets:
Electric derivative contracts																																																		5,822	[2]	693	[2]			0	[2]	0	[2]			0	[2]	0	[2]			5,822	[2]	693	[2]
Natural gas derivative contracts																																																				95	[2]					95	[2]					0	[2]					0	[2]
Heating oil derivative contracts																																																																										3	[2]	26	[2]	9	[2]	3	[2]	26	[2]	0	[2]	0	[2]	0	[2]	0	[2]	0	[2]	0	[2]	0	[2]
Total Derivative Assets Fair Value																										5,825	[2]	814	[2]	9	[2]	3	[2]	121	[2]	0	[2]	0	[2]	0	[2]	0	[2]	5,822	[2]	693	[2]	0	[2]	5,822	[2]	788	[2]			0	[2]	95	[2]			0	[2]	0	[2]			5,822	[2]	693	[2]
Liabilities:
Electric derivative contracts																																																		(608)	[2]	(1,367)	[2]	(23,792)	[2]	0	[2]	(110)	[2]	0	[2]	0	[2]	0	[2]	0	[2]	(608)	[2]	(1,367)	[2]	(23,792)	[2]
Natural gas derivative contracts																																																		(2)	[2]	(110)	[2]	(14)	[2]	(2)	[2]	0	[2]	(14)	[2]	0	[2]	0	[2]	0	[2]	0	[2]	0	[2]	0	[2]
Total Derivative Liabilities Fair Value																										(610)	[2]	(1,477)	[2]	(23,806)	[2]	(2)	[2]	(110)	[2]	(14)	[2]	0	[2]	0	[2]	0	[2]	(608)	[2]	(1,367)	[2]	(23,792)	[2]
Changes in fair value of net assets (liabilities) classified as Level 3 [Roll Forward]
Balance at Beginning of Period																								(674)	(16,830)
Unrealized gains (losses)																								5,888	(6,962)
Realized gains (losses)																								5,119	(7,654)
Purchases																								0	0
Issuances																								0	0
Sales and settlements																								(5,119)	7,654
Transfers in and/or out of Level 3																								0	0
Balance at End of Period																								5,214	(23,792)
The amount of total gains or losses for the period included in earnings attributable to the change in unrealized gains or losses relating to derivatives still held at end of period																								0	0
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in the Income Statement				$ 5,073	$ (9,413)	$ 5,075	$ (9,443)	$ 5,119	[3]	$ (7,654)	[3]	$ (44)	[3]	$ (2,406)	[3]	$ 0	$ 617	$ (2)	$ 30	$ (2)	$ 30	$ 0	$ 0

[1] Projected coverage as of March 31, 2013.

[2] Interest rate cap agreement is not shown in the above table because the FMV at each period stated was zero.

[3] Realized gains and losses on Central Hudson's derivative instruments are conveyed to or recovered from customers through PSC authorized deferral accounting mechanisms, with an offset in revenue and on the balance sheet, and no impact on results of operations.

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Capitalization Long-Term Debt (Details) (USD $) In Thousands, unless otherwise specified				3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Mar. 31, 2013 Interest Rate Cap [Member]	Mar. 31, 2013 Central Hudson [Member]	Dec. 31, 2012 Central Hudson [Member]	Mar. 31, 2012 Central Hudson [Member]	Mar. 31, 2013 Central Hudson [Member] Series B NYSERDA Bonds [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term debt, outstanding	$ 518,002	$ 518,002	$ 495,008		$ 489,950	$ 489,950	$ 465,950	$ 33,700
Derivative [Line Items]
Period of derivative instrument (in years)				2 years
Derivative maturity date				Apr. 01, 2014
Multiple of tax-exempt variable rate debt on which derivative instrument is based (in hundredths)				175.00%
Minimum adjusted index at which a payout is triggered (in hundredths)				5.00%

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Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2013

Summary of Significant Accounting Policies [Abstract]

Summary of Significant Accounting Policies

NOTE 1 – Summary of Significant Accounting Policies

The Financial Statements were prepared in conformity with accounting principles generally accepted in the United States of America ("GAAP"), which for regulated public utilities, includes specific accounting guidance for regulated operations.  For additional information regarding regulatory accounting, see Note 2 – "Regulatory Matters."

Pending Acquisition by Fortis Inc.

On February 21, 2012, CH Energy Group announced that it had entered into an agreement and plan of merger under which it agreed, subject to shareholder approval and the approval of applicable regulatory authorities, to be acquired by Fortis Inc. ("Fortis") for $65 per share of common stock in cash.  On June 19, 2012, shareholders of CH Energy Group approved the proposed acquisition of the Company by Fortis.  On July 3, 2012, the Federal Energy Regulatory Commission ("FERC") approved the acquisition of CH Energy Group by Fortis.  On July 17, 2012, the Committee on Foreign Investment in the United States approved the acquisition of CH Energy Group by Fortis.  On October 2, 2012, the Federal Trade Commission permitted the 30-day waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 with respect to the acquisition of the Company by Fortis to expire.  On April 20, 2012, CH Energy Group, Central Hudson, Fortis, FortisUS Inc. ("FortisUS"), and Cascade Acquisition Sub Inc. ("Petitioners"), submitted a joint petition to the New York State Public Service Commission ("PSC" or "Commission") for approval of the proposed transaction under Section 70 of the Public Service Law.  Pursuant to a procedure schedule established by the Administrative Law Judges, the PSC Staff and other parties to the proceeding filed testimony and comments on October 12, 2012.  On January 25, 2013, a Joint Proposal with the Company, Fortis, PSC Staff, Multiple Intervenors, the Department of State Utility Intervention Unit, and Dutchess, Orange and Ulster counties as signatories, was submitted to the PSC.  The signatory parties have concluded that, based on the terms of the Joint Proposal, the acquisition is in the public interest pursuant to New York State Public Service Law, Section 70, and recommend approval by the Commission.  The deadline for submission of public comments in the proceeding was extended to May 1, 2013 by the Commission in a notice issued March 22, 2013.  On April 24, 2013, the Commission issued a notice stating that the Administrative Law Judges ("ALJs") assigned to this matter would prepare a Recommended Decision ("RD") for the Commission.  On May 3, 2013 the Recommended Decision of the two Administrative Law Judges – an advisory document – was issued by the PSC.  The RD states that, in its current form, the Joint Proposal does not meet the public interest test as required by New York State Public Service Law, Section 70, but also states that the ALJs recommend the Commission consider adopting the Joint Proposal subject to modifications that would alter the transaction's balance of risks and benefits.  Briefs on exceptions to the RD are due May 17, 2013 and briefs opposing exceptions are due on May 24, 2013.  While no assurance regarding the closing can be given until a final PSC Order is issued, the Company continues to anticipate that the Commission will review and approve the merger in the second quarter of 2013.  Under the terms of the merger agreement, Fortis must close the transaction if all conditions precedent are met, including PSC approval, and a material adverse effect has not occurred.  Closing of the transaction would follow shortly after issuance of the final PSC Order approving the merger.  Management believes this will occur in the second quarter of 2013.

Unaudited Financial Statements

The accompanying Consolidated Financial Statements of CH Energy Group and Financial Statements of Central Hudson are unaudited but, in the opinion of management, reflect adjustments (which include normal recurring adjustments) necessary for a fair statement of the results for the interim periods presented.  These unaudited quarterly Financial Statements do not contain all footnote disclosures concerning accounting policies and other matters which would be included in annual Financial Statements and, accordingly, should be read in conjunction with the audited Financial Statements (including the Notes thereto) included in the combined CH Energy Group/Central Hudson Annual Report on Form 10-K for the year ended December 31, 2012 (the "Corporations' 10-K Annual Report").

CH Energy Group's and Central Hudson's balance sheets as of March 31, 2012 are not required to be included in this Quarterly Report on Form 10-Q; however, these balance sheets are included for supplemental analysis purposes.

Reclassification

Certain amounts in the 2012 Financial Statements have been reclassified to conform to the 2013 presentation.

The Company reclassified amounts related to in-process work for cost of removal of plant assets from accumulated depreciation to deferred costs, regulatory liabilities. This reclassification resulted in a reduction to the March 31, 2012 balance of $10.6 million.

Revenue Recognition

CH Energy Group's deferred revenue balances as of March 31, 2013, December 31, 2012 and March 31, 2012 were $3.9 million, $4.8 million and $3.9 million, respectively.  The deferred revenue balance will be recognized in CH Energy Group's operating revenues over the 12-month term of the respective customer contract.

As required by the PSC, Central Hudson records gross receipts tax revenues and expenses on a gross income statement presentation basis (i.e., included in both revenue and expenses).  Sales and use taxes for both Central Hudson and Griffith are accounted for on a net basis (excluded from revenue).

Fuel, Materials & Supplies

The following is a summary of CH Energy Group's and Central Hudson's inventories (In Thousands):

	CH Energy Group						Central Hudson
	March 31,		December 31,		March 31,		March 31,		December 31,		March 31,
	2013		2012		2012		2013		2012		2012
Natural gas	$	2,759	$	7,638	$	7,322	$	2,759	$	7,638	$	7,322
Petroleum products and propane		2,098		3,942		2,115		-		-		-
Fuel used in electric generation		293		295		286		293		295		286
Materials and supplies		12,504		12,621		9,966		11,142		11,331		8,781
Total	$	17,654	$	24,496	$	19,689	$	14,194	$	19,264	$	16,389

Depreciation and Amortization

Current accounting guidance related to asset retirements precludes the recognition of expected future retirement obligations as a component of depreciation expense or accumulated depreciation.  Central Hudson, however, is required to use depreciation methods and rates approved by the PSC under regulatory accounting.  These depreciation rates include a charge for the cost of future removal and retirement of fixed assets.  In accordance with current accounting guidance for regulated operations, Central Hudson continues to accrue for the future cost of removal for its rate-regulated natural gas and electric utility assets.  In accordance with current accounting guidance related to asset retirements, Central Hudson has classified $44.8 million, $43.4 million, and $42.7 million of cost of removal as regulatory liabilities as of March 31, 2013, December 31, 2012, and March 31, 2012, respectively.  This liability represents the portion of the cost of removal charge in excess of the amount reported as an Asset Retirement Obligation under GAAP.

See Note 6 - "Goodwill and Other Intangible Assets" for further discussion of amortization of intangibles (other than goodwill).

Earnings Per Share

In the calculation of earnings per share (basic and diluted) of CH Energy Group's Common Stock, earnings for CH Energy Group are reduced by the Preferred Stock dividends of Central Hudson.

The average dilutive effect of CH Energy Group's stock options, performance shares and restricted shares are as follows:

	Three Months Ended
	March 31,
	2013		2012
Shares		213,908		260,259

Certain stock options can be excluded from the calculation of diluted earnings per share because the exercise prices of those options were greater than the average market price per share of Common Stock.  As of December 31, 2012, no stock options are outstanding.  There were no options excluded during the three months ended March 31, 2012.

Parental Guarantees

CH Energy Group and CHEC have issued guaranteesto counterparties to assure the payment, when due, of certain obligations incurred by CH Energy Group subsidiaries, in physical and financial transactions.

	March 31, 2013
Transaction Description	Maximum Potential Payments		Outstanding Liabilities(1)
Heating oil, propane, other petroleum products, weather and commodity hedges (In Thousands)	$	30,650	$	8,555

(1) Balance included in CH Energy Group's Consolidated Balance Sheet.

Management is not aware of any existing condition that would require payment under the guarantees.

Common Stock Dividends

On March 27, 2013, the Board of Directors of CH Energy Group declared a quarterly dividend of 55.5 cents per share payable May 1, 2013, to shareholders of record as of April 10, 2013.

CH Energy Group's ability to pay dividends is affected by the ability of its subsidiaries to pay dividends.  The Federal Power Act limits the payment of dividends by Central Hudson to its retained earnings.  More restrictive is the PSC's limit on the dividends Central Hudson may pay to CH Energy Group which is 100% of the average annual income available for common stock, calculated on a two-year rolling average basis.  Based on this calculation, Central Hudson was restricted to a maximum payment of $45.1 million in dividends to CH Energy Group for the year ended December 31, 2012.  Central Hudson's dividend would be reduced to 75% of its average annual income in the event of a downgrade of its senior debt rating below "BBB+" by more than one rating agency if the stated reason for the downgrade is related to any of CH Energy Group's or Central Hudson's affiliates.  Further restrictions are imposed for any downgrades below this level.  During the three months ended March 31, 2013, Central Hudson had declared and paid dividends of $5.0 million to parent CH Energy Group.  CH Energy Group's other subsidiaries do not have express restrictions on their ability to pay dividends.

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Acquisitions, Divestitures and Investments (Details) (USD $)	3 Months Ended			3 Months Ended		3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Mar. 31, 2011 Griffith [Member]	Mar. 31, 2013 CHEC [Member]	Mar. 31, 2013 CHEC [Member] Griffith Energy Services [Member]	Mar. 31, 2013 CHEC [Member] CH-Community Wind [Member]	Mar. 31, 2013 CHEC [Member] Other Renewable Energy Projects [Member]
Business Acquisition [Line Items]
Number of Acquired Companies (in companies)	0
Environmental reserve [Abstract]
Reduction of reserve based on completion of an environmental study				$ 600,000
Equity investment	2,241,000	2,536,000	2,559,000		42,923,000	40,682,000	0	2,241,000
Schedule of Equity Method Investments [Line Items]
Description						100% controlling interest in a fuel distribution business	50% equity interest in a joint venture that owns 18% interest in two operating wind projects
Ownership percentage (in hundredths)						100.00%	50.00%
Intercompany debt					40,000,000	40,000,000	0	0
Equity investment	2,241,000	2,536,000	2,559,000		42,923,000	40,682,000	0	2,241,000
Total investment					$ 82,923,000	$ 80,682,000	$ 0	$ 2,241,000
Percentage interest that joint venture that owns in two operating wind projects (in hundredths)							18.00%
Number of operating wind projects in which joint venture owns percentage interest							2

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Income Tax (Tables)

3 Months Ended

Mar. 31, 2013

Income Tax [Abstract]

Information Related To Uncertain Tax Positions

Other than the uncertain tax position related to the Company's accounting method change for gas transmission and distribution repairs, there are no other uncertain tax positions.  The following is a summary of activity related to uncertain tax positions (In Thousands):

	Three Months Ended March 31,
	2013		2012
Balance at the beginning of the period	$	2,000	$	3,172
Adjustments related to tax accounting method change		47		2
Balance at the end of the period	$	2,047	$	3,174

Jurisdiction	Tax Years Open for Audit
Federal(1)	2007 - 2012
New York State	2009 - 2012

(1)   Federal tax filings for the years 2007 - 2011 are currently under audit.

Effective Income Tax Reconciliation

Reconciliation - CH Energy Group

The following is a reconciliation between the amount of federal income tax computed on income before taxes at the statutory rate and the amount reported in CH Energy Group's Consolidated Statement of Income (In Thousands):

	Three Months Ended March 31,
	2013			2012
Net income attributable to CH Energy Group	$	18,090		$	14,581
Preferred Stock dividends of Central Hudson		92			242
Preferred Stock Redemption Premium		764			-
Federal income tax		7,465			-
State income tax		544			408
Deferred federal income tax		2,833			10,452
Deferred state income tax		323			809
Income before taxes	$	30,111		$	26,492
Computed federal tax at 35% statutory rate	$	10,539		$	9,272
State income tax net of federal tax benefit		879			1,293
Depreciation flow-through		891			797
Cost of Removal		(616	)		(596	)
Merger Transaction Costs		84			1,705
Other		(612	)		(802	)
Total income tax	$	11,165		$	11,669
Effective tax rate - federal		34.2	%		39.4	%
Effective tax rate - state		2.9	%		4.6	%
Effective tax rate - combined		37.1	%		44.0	%

Reconciliation - Central Hudson

The following is a reconciliation between the amount of federal income tax computed on income before taxes at the statutory rate and the amount reported in Central Hudson's Statement of Income (In Thousands):

	Three Months Ended March 31,
	2013			2012
Net income	$	14,369		$	16,733
Federal income tax		5,318			-
Deferred federal income tax		2,565			9,320
Deferred state income tax		901			1,433
Income before taxes	$	23,153		$	27,486
Computed federal tax at 35% statutory rate	$	8,104		$	9,620
State income tax net of federal tax benefit		901			1,433
Depreciation flow-through		891			797
Cost of Removal		(616	)		(596	)
Other		(496	)		(501	)
Total income tax	$	8,784		$	10,753
Effective tax rate - federal		34.0	%		33.9	%
Effective tax rate - state		3.9	%		5.2	%
Effective tax rate - combined		37.9	%		39.1	%

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New Accounting Guidance (Tables)

3 Months Ended

Mar. 31, 2013

New Accounting Guidance [Abstract]

New Accounting Guidance

Impact	Category	Accounting Reference	Title	Issued Date	Effective Date
1	Balance Sheet (Topic 210)	ASU No. 2011-11	Disclosures about Offsetting Assets and Liabilities	Dec-11	Jan-13
1	Balance Sheet (Topic 210)	ASU No. 2013-01	Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities	Jan-13	Jan-13
1	Comprehensive Income (Topic 220)	ASU No. 2013-02	Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income	Feb-13	Dec-12
2	Liabilities (Topic 405)	ASU No. 2013-04	Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date	Feb-13	Dec-13

Impact Key:
(1)	No current impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries when adopted on the effective date noted.  Additional disclosures have been added or presentation of information modified where required.
(2)	No anticipated impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries upon future adoption.

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Goodwill and Other Intangible Assets (Details) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012	Sep. 30, 2010
Goodwill and Other Intangible Assets [Abstract]
Fair value of goodwill, in excess of carrying value				$ 34,200,000
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	38,438,000	36,903,000	38,438,000
Accumulated Amortization	26,775,000	24,339,000	26,114,000
Intangibles Amortization Expense	661,000	634,000
Estimated annual amortization expense [Abstract]
Estimated annual amortization expense, remainder of fiscal year	1,984,000
Estimated annual amortization expense, year two	2,636,000
Estimated annual amortization expense, year three	2,374,000
Estimated annual amortization expense, year four	988,000
Estimated annual amortization expense, year five	683,000
Customer relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	37,709,000	36,526,000	37,709,000
Accumulated Amortization	26,645,000	24,188,000	26,017,000
Trademarks [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	318,000	0	318,000
Accumulated Amortization	8,000	0	0
Covenants not to compete [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	411,000	377,000	411,000
Accumulated Amortization	$ 122,000	$ 151,000	$ 97,000

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Acquisitions, Divestitures and Investments (Tables)

3 Months Ended

Mar. 31, 2013

Acquisitions, Divestitures and Investments [Abstract]

Investments

The value of CHEC's investments as of March 31, 2013 is as follows  (In Thousands):

CHEC Investment	Description	Intercompany Debt		Equity Investment		Total
Griffith Energy Services	100% controlling interest in a fuel distribution business	$	40,000	$	40,682	$	80,682
CH-Community Wind	50% equity interest in a joint venture that owns 18% interest in two operating wind projects		-		-		-
Other	Partnerships and an energy sector venture capital fund		-		2,241		2,241
		$	40,000	$	42,923	$	82,923

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Goodwill and Other Intangible Assets (Tables)

3 Months Ended

Mar. 31, 2013

Goodwill and Other Intangible Assets [Abstract]

Components of Amortizable Intangible Assets

The components of amortizable intangible assets of CH Energy Group are summarized as follows (In Thousands):

	March 31, 2013				December 31, 2012				March 31, 2012
	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
Customer relationships	$	37,709	$	26,645	$	37,709	$	26,017	$	36,526	$	24,188
Trademarks		318		8		318		-		-		-
Covenants not to compete		411		122		411		97		377		151
Total Amortizable Intangibles	$	38,438	$	26,775	$	38,438	$	26,114	$	36,903	$	24,339

Intangibles Amortization Expense

	Three Months Ended March 31,
	2013		2012
Intangibles Amortization Expense (In Thousands)	$	661	$	634

Schedule of Expected Amortization Expense

The estimated annual amortization expense for the remainder of the current year and for each of the next four years, assuming no new acquisitions or divestitures, is as follows (In Thousands):

	2013		2014		2015		2016		2017
Estimated Amortization Expense	$	1,984	$	2,636	$	2,374	$	988	$	683

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CONSOLIDATED STATEMENT OF EQUITY (UNAUDITED) (USD $) In Thousands, except Share data, unless otherwise specified	Common Stock [Member]	Treasury Stock [Member]	Paid-In Capital [Member]	Capital Stock Expense [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	Total	Central Hudson Gas & Electric Corporation [Member] Common Stock [Member]	Central Hudson Gas & Electric Corporation [Member] Treasury Stock [Member]	Central Hudson Gas & Electric Corporation [Member] Paid-In Capital [Member]	Central Hudson Gas & Electric Corporation [Member] Capital Stock Expense [Member]	Central Hudson Gas & Electric Corporation [Member] Retained Earnings [Member]	Central Hudson Gas & Electric Corporation [Member] Accumulated Other Comprehensive Income (Loss) [Member]	Central Hudson Gas & Electric Corporation [Member]
Beginning Balance at Dec. 31, 2011	$ 1,686	$ (92,908)	$ 351,053	$ (328)	$ 242,391	$ 354	$ 0	$ 502,248	$ 84,311	$ 0	$ 199,980	$ (4,961)	$ 165,965	$ 0	$ 445,295
Beginning Balance (in shares) at Dec. 31, 2011	16,862,087	(1,967,123)							16,862,087	0
Comprehensive income:
Net income					14,823			14,823					16,733		16,733
Dividends declared on Preferred Stock of subsidiary					(242)			(242)					(242)		(242)
Change in fair value:
Investments						(58)		(58)
Dividends declared on common stock					(8,279)			(8,279)
Treasury shares activity - net		930	(2,747)					(1,817)
Treasury shares activity - net (in shares)		19,889
Ending Balance at Mar. 31, 2012	1,686	(91,978)	348,306	(328)	248,693	296	0	506,675	84,311	0	199,980	(4,961)	182,456	0	461,786
Ending Balance (in shares) at Mar. 31, 2012	16,862,087	(1,947,234)							16,862,087	0
Beginning Balance at Dec. 31, 2012	1,686	(90,141)	349,428	(166)	248,103	380	0	509,290	84,311	0	199,980	(4,799)	190,169	0	469,661
Beginning Balance (in shares) at Dec. 31, 2012	16,862,087	(1,907,203)							16,862,087	0
Comprehensive income:
Net income					18,946			18,946					14,369		14,369
Preferred Stock Redemption			(28)	166	(764)			(626)			(28)	166	(764)		(626)
Dividends declared on Preferred Stock of subsidiary					(92)			(92)					(92)		(92)
Change in fair value:
Investments						(12)		(12)
Dividends declared on common stock					(8,310)			(8,310)
Dividends declared: On Common Stock to parent - CH Energy Group													(5,000)		(5,000)
Treasury shares activity - net		250	114					364
Treasury shares activity - net (in shares)		6,092
Ending Balance at Mar. 31, 2013	$ 1,686	$ (89,891)	$ 349,514	$ 0	$ 257,883	$ 368	$ 0	$ 519,560	$ 84,311	$ 0	$ 199,952	$ (4,633)	$ 198,682	$ 0	$ 478,312
Ending Balance (in shares) at Mar. 31, 2013	16,862,087	(1,901,111)							16,862,087	0

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Short-Term Borrowing Arrangements (Tables)

3 Months Ended

Mar. 31, 2013

Short-Term Borrowing Arrangements [Abstract]

Short-Term Borrowings Under Revolving Credit Facility

CH Energy Group and Central Hudson borrowings under its committed and uncommitted short-term borrowing arrangements are as follows (In Thousands):

	March 31, 2013			December 31, 2012			March 31, 2012
CH Energy Group Holding Company Short-term borrowings	$	29,000		$	19,500		$	32,000
Central Hudson Short-term borrowings		27,000			-			59,000
Intercompany Borrowing		-			-			(20,000	)
Total CH Energy Group	$	56,000		$	19,500		$	71,000
Total CH Energy Group Weighted Average Interest Rate		0.97	%		1.08	%		1.12	%

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Regulatory Matters (Details) (USD $)	36 Months Ended					1 Months Ended	12 Months Ended		1 Months Ended	3 Months Ended	12 Months Ended					1 Months Ended	3 Months Ended
	Jun. 30, 2013		Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Aug. 31, 2011 Tropical Storm Irene [Member]	Dec. 31, 2011 Tropical Storm Irene [Member]	Apr. 22, 2013 Tropical Storm Irene [Member]	Oct. 31, 2011 Snow Storm of 2011 [Member]	Mar. 31, 2012 Snow Storm of 2011 [Member]	Dec. 31, 2012 Snow Storm of 2011 [Member]	Jun. 30, 2012 Snow Storm of 2011 [Member]	Dec. 31, 2011 Snow Storm of 2011 [Member]	Apr. 22, 2013 Snow Storm of 2011 [Member]	Oct. 29, 2011 Snow Storm of 2011 [Member]	Oct. 31, 2012 Superstorm Sandy [Member]	Mar. 31, 2013 Superstorm Sandy [Member]	Dec. 31, 2012 Superstorm Sandy [Member]	Mar. 31, 2013 Deferred purchased electric and natural gas costs [Member]	Dec. 31, 2012 Deferred purchased electric and natural gas costs [Member]	Mar. 31, 2012 Deferred purchased electric and natural gas costs [Member]	Mar. 31, 2013 Deferred unrealized losses on derivatives [Member]	Dec. 31, 2012 Deferred unrealized losses on derivatives [Member]	Mar. 31, 2012 Deferred unrealized losses on derivatives [Member]	Mar. 31, 2013 Deferred unrealized gains on derivatives [Member]	Dec. 31, 2012 Deferred unrealized gains on derivatives [Member]	Mar. 31, 2012 Deferred unrealized gains on derivatives [Member]	Mar. 31, 2013 PSC General and Temporary State Assessment and carrying charges [Member]	Dec. 31, 2012 PSC General and Temporary State Assessment and carrying charges [Member]	Mar. 31, 2012 PSC General and Temporary State Assessment and carrying charges [Member]	Mar. 31, 2013 RDM and carrying charges [Member]	Dec. 31, 2012 RDM and carrying charges [Member]	Mar. 31, 2012 RDM and carrying charges [Member]	Mar. 31, 2013 Residual natural gas deferred balances [Member]	Dec. 31, 2012 Residual natural gas deferred balances [Member]	Mar. 31, 2012 Residual natural gas deferred balances [Member]	Mar. 31, 2013 Deferred storm costs and carrying charges [Member]	Dec. 31, 2012 Deferred storm costs and carrying charges [Member]	Mar. 31, 2012 Deferred storm costs and carrying charges [Member]	Mar. 31, 2013 Other regulatory assets and liabilities [Member]	Dec. 31, 2012 Other regulatory assets and liabilities [Member]	Mar. 31, 2012 Other regulatory assets and liabilities [Member]	Mar. 31, 2013 Deferred pension costs [Member]	Dec. 31, 2012 Deferred pension costs [Member]	Mar. 31, 2012 Deferred pension costs [Member]	Mar. 31, 2013 Rate base impact of tax repair project and carrying charges [Member]	Dec. 31, 2012 Rate base impact of tax repair project and carrying charges [Member]	Mar. 31, 2012 Rate base impact of tax repair project and carrying charges [Member]	Mar. 31, 2013 Carrying charges - pension reserve [Member]	Dec. 31, 2012 Carrying charges - pension reserve [Member]	Mar. 31, 2012 Carrying charges - pension reserve [Member]	Mar. 31, 2013 Deferred and accrued costs - MGP site remediation and carrying charges [Member]	Dec. 31, 2012 Deferred and accrued costs - MGP site remediation and carrying charges [Member]	Mar. 31, 2012 Deferred and accrued costs - MGP site remediation and carrying charges [Member]	Mar. 31, 2013 Energy efficiency incentives [Member]	Dec. 31, 2012 Energy efficiency incentives [Member]	Mar. 31, 2012 Energy efficiency incentives [Member]	Mar. 31, 2013 Deferred debt expense on re-acquired debt [Member]	Dec. 31, 2012 Deferred debt expense on re-acquired debt [Member]	Mar. 31, 2012 Deferred debt expense on re-acquired debt [Member]	Mar. 31, 2013 Deferred Medicare Subsidy taxes [Member]	Dec. 31, 2012 Deferred Medicare Subsidy taxes [Member]	Mar. 31, 2012 Deferred Medicare Subsidy taxes [Member]	Mar. 31, 2013 Residual natural gas deferred balances and carrying charges [Member]	Dec. 31, 2012 Residual natural gas deferred balances and carrying charges [Member]	Mar. 31, 2012 Residual natural gas deferred balances and carrying charges [Member]	Mar. 31, 2013 Income taxes recoverable through future rates [Member]	Dec. 31, 2012 Income taxes recoverable through future rates [Member]	Mar. 31, 2012 Income taxes recoverable through future rates [Member]	Mar. 31, 2013 Excess electric depreciation reserve and carrying charges [Member]	Dec. 31, 2012 Excess electric depreciation reserve and carrying charges [Member]	Mar. 31, 2012 Excess electric depreciation reserve and carrying charges [Member]	Mar. 31, 2013 Deferred unbilled gas revenues [Member]	Dec. 31, 2012 Deferred unbilled gas revenues [Member]	Mar. 31, 2012 Deferred unbilled gas revenues [Member]	Mar. 31, 2013 Customer benefit fund [Member]	Dec. 31, 2012 Customer benefit fund [Member]	Mar. 31, 2012 Customer benefit fund [Member]	Mar. 31, 2013 Deferred cost of removal [Member]	Dec. 31, 2012 Deferred cost of removal [Member]	Mar. 31, 2012 Deferred cost of removal [Member]	Mar. 31, 2013 Deferred OPEB costs [Member]	Dec. 31, 2012 Deferred OPEB costs [Member]	Mar. 31, 2012 Deferred OPEB costs [Member]	Mar. 31, 2013 Income taxes refundable through future rates [Member]	Dec. 31, 2012 Income taxes refundable through future rates [Member]	Mar. 31, 2012 Income taxes refundable through future rates [Member]	Mar. 31, 2013 Carrying charges - OPEB reserve [Member]	Dec. 31, 2012 Carrying charges - OPEB reserve [Member]	Mar. 31, 2012 Carrying charges - OPEB reserve [Member]
Regulatory Assets and Liabilities [Line Items]
Current regulatory assets			$ 35,165,000	$ 32,329,000	$ 49,683,000														$ 15,743,000	$ 11,367,000	$ 2,892,000	$ 517,000	$ 1,259,000	$ 22,118,000				$ 8,854,000	$ 6,260,000	$ 11,547,000	$ 0	$ 3,393,000	$ 3,068,000	$ 4,554,000	$ 4,554,000	$ 4,554,000				$ 291,000	$ 290,000	$ 290,000										$ 4,605,000	$ 4,605,000	$ 4,586,000				$ 601,000	$ 601,000	$ 628,000
Long-term regulatory assets			250,059,000	256,714,000	271,296,000																	93,000	218,000	1,688,000													19,717,000	23,274,000	15,178,000	13,322,000	15,751,000	11,747,000	140,349,000	146,935,000	151,737,000				10,303,000	9,182,000	6,158,000	10,109,000	10,739,000	13,459,000	2,719,000	2,719,000	2,719,000	4,586,000	4,737,000	5,172,000	7,933,000	7,808,000	7,450,000	3,809,000	5,443,000	8,168,000	37,119,000	29,908,000	47,820,000
Total Regulatory Assets			285,224,000	289,043,000	320,979,000
Current regulatory liabilities			14,568,000	10,736,000	8,959,000																				2,941,000	95,000	0				2,330,000	0	0																																					0	0	74,000	4,866,000	5,972,000	3,765,000										4,431,000	4,669,000	5,120,000
Long-term regulatory liabilities			118,400,000	105,460,000	110,509,000																				2,881,000	693,000	0													12,448,000	9,314,000	5,199,000				9,159,000	9,099,000	8,083,000																						1,586,000	1,586,000	2,688,000				2,419,000	2,390,000	2,566,000	44,795,000	43,392,000	42,748,000	9,696,000	7,975,000	8,974,000	24,194,000	21,062,000	33,769,000	11,222,000	9,949,000	6,482,000
Total Regulatory Liabilities			132,968,000	116,196,000	119,468,000
Net Regulatory Assets			152,256,000	172,847,000	201,511,000
2010 Rate Order [Abstract]
Electric delivery revenue increases for year one of Rate Order	11,800,000	[1]
Electric delivery revenue increases for year two of Rate Order	9,300,000	[1]
Electric delivery revenue increases for year three of Rate Order	9,100,000
Natural gas delivery revenue increases for year one of Rate Order	5,700,000
Natural gas delivery revenue increases for year two of Rate Order	2,400,000
Natural gas delivery revenue increases for year three of Rate Order	1,600,000
ROE (in hundredths)	10.00%											10.00%
Earnings sharing	Yes	[2]
Capital structure - common equity (in hundredths)	48.00%
Targets with true-up provisions - % of revenue requirement to defer for shortfalls [Abstract]
Net plant balances (in hundredths)	100.00%
Transmission and distribution ROW maintenance (in hundredths)	100.00%
RDMs - electric and natural gas	Yes	[3]
New deferral accounting for full recovery [Abstract]
Fixed debt costs	Yes	[4]
Transmission sag mitigation	Yes
New York State Temporary Assessment	Yes
Material regulatory actions	Yes	[5]
Property taxes - Deferral for 90% of excess/deficiency relative to revenue requirement	Yes	[6]
Percentage of excess/deficiency in property taxes allowed for deferral (in hundredths)	90.00%
Bill credits for year one of Rate Order	12,000,000
Bill credits for year two of Rate Order	4,000,000
Threshold percentage of ROE for which 50% of earnings will be returned to customers (in hundredths)	10.50%
Percentage of earnings returned to customers at first threshold ROE (in hundredths)	50.00%
Threshold percentage of ROE for which 80% of earnings will be returned to customers (in hundredths)	11.00%
Percentage of earnings returned to customers at second threshold ROE (in hundredths)	80.00%
Threshold percentage of ROE for which 90% of earnings will be returned to customers (in hundredths)	11.50%
Percentage of earnings returned to customers at third threshold ROE (in hundredths)	90.00%
Minimum percentage of net income considered to be a material impact (in hundredths)	2.00%
Maximum pre-tax gain or loss per rate year	700,000
Loss Contingencies [Line Items]
Approximate number of customers with disrupted service						180,000			150,000							103,000
Storm costs																		22,000,000
Regulatory liability to be funded by Fortis																		35,000,000
Recovery sought from PSC							$11.4 million of incremental electric storm restoration expense above the respective rate allowance			$8.6 million of total incremental electric storm restoration expense							$9.7 million of incremental electric storm restoration expense, with carrying charges
Deferred balance related to storm event																	9,800,000
Accumulation of snow (in inches)															20
Incremental electric storm restoration expense											3,300,000		3,700,000
Authorized rate of return on equity	10.00%											10.00%
Incremental electric storm restoration expense authorized for deferral								8,900,000
Costs denied by the Commission, for which petition was filed														3,700,000
Costs denied by the Commission which should have been allocated separately								$ 600,000

[1] Moderated by $12 million and $4 million bill credits, respectively.

[2] ROE > 10.5%, 50% to customers, > 11.0%, 80% to customers, > 11.5%, 90% to customers.

[3] Electric is based on revenue dollars; gas is based on usage per customer.

[4] Deferral authorization in RY2 and RY3 only.

[5] Legislative, governmental or regulatory actions with individual impacts greater than or equal to 2% of net income of the applicable department.

[6] The Company's pre-tax gain or loss limited to $0.7 million per rate year.

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Other Fair Value Measurements (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012
Long-term debt maturities [Abstract]
Total Debt Outstanding	$ 518,002	$ 518,002	$ 495,008
Estimated effective interest rate [Abstract]
Estimated Effective Interest Rate, Total (in hundredths)	5.02%	5.03%	5.07%
Long-term debt, fair value [Abstract]
Total Debt, Fair Value	588,424	596,555	579,659
Fixed Rate [Member]
Long-term debt maturities [Abstract]
Maturing in the remainder of current fiscal year	31,076		1,006
Maturing in next twelve months		31,076
Maturing in year two	21,650	21,650	31,076
Maturing in year three	1,230	1,230	21,650
Maturing in year four	9,315	9,315	1,230
Maturing in year five	34,406	34,406	9,315
Maturing thereafter	386,625	386,625	397,031
Total Debt Outstanding	484,302	484,302	461,308
Estimated effective interest rate [Abstract]
Estimated effective interest rate, remainder of current fiscal year (in hundredths)	6.93%		6.86%
Estimated effective interest rate, maturing in next twelve months (in hundredths)		6.93%
Estimated effective interest rate, maturing in year two (in hundredths)	5.50%	5.50%	6.93%
Estimated effective interest rate, maturing in year three (in hundredths)	6.86%	6.86%	5.50%
Estimated effective interest rate, maturing in year four (in hundredths)	3.36%	3.36%	6.86%
Estimated effective interest rate, maturing in year five (in hundredths)	6.13%	6.13%	3.36%
Estimated effective interest rate, maturing thereafter (in hundredths)	5.13%	5.13%	5.29%
Estimated Effective Interest Rate, Total (in hundredths)	5.31%	5.31%	5.38%
Long-term debt, fair value [Abstract]
Total Debt, Fair Value	554,724	562,855	545,959
Variable Rate [Member]
Long-term debt maturities [Abstract]
Maturing in the remainder of current fiscal year	0		0
Maturing in next twelve months		0
Maturing in year two	0	0	0
Maturing in year three	0	0	0
Maturing in year four	0	0	0
Maturing in year five	0	0	0
Maturing thereafter	33,700	33,700	33,700
Total Debt Outstanding	33,700	33,700	33,700
Estimated effective interest rate [Abstract]
Estimated effective interest rate, remainder of current fiscal year (in hundredths)	0.00%		0.00%
Estimated effective interest rate, maturing in next twelve months (in hundredths)		0.00%
Estimated effective interest rate, maturing in year two (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing in year three (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing in year four (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing in year five (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing thereafter (in hundredths)	0.20%	0.28%	0.37%
Estimated Effective Interest Rate, Total (in hundredths)	0.20%	0.28%	0.37%
Long-term debt, fair value [Abstract]
Total Debt, Fair Value	33,700	33,700	33,700
Central Hudson [Member]
Long-term debt maturities [Abstract]
Total Debt Outstanding	489,950	489,950	465,950
Estimated effective interest rate [Abstract]
Estimated Effective Interest Rate, Total (in hundredths)	4.92%	4.93%	4.96%
Long-term debt, fair value [Abstract]
Total Debt, Fair Value	555,406	563,410	541,678
Central Hudson [Member] | Fixed Rate [Member]
Long-term debt maturities [Abstract]
Maturing in the remainder of current fiscal year	30,000		0
Maturing in next twelve months		30,000
Maturing in year two	14,000	14,000	30,000
Maturing in year three	0	0	14,000
Maturing in year four	8,000	8,000	0
Maturing in year five	33,000	33,000	8,000
Maturing thereafter	371,250	371,250	380,250
Total Debt Outstanding	456,250	456,250	432,250
Estimated effective interest rate [Abstract]
Estimated effective interest rate, remainder of current fiscal year (in hundredths)	6.93%		0.00%
Estimated effective interest rate, maturing in next twelve months (in hundredths)		6.93%
Estimated effective interest rate, maturing in year two (in hundredths)	4.81%	4.81%	6.93%
Estimated effective interest rate, maturing in year three (in hundredths)	0.00%	0.00%	4.81%
Estimated effective interest rate, maturing in year four (in hundredths)	2.78%	2.78%	0.00%
Estimated effective interest rate, maturing in year five (in hundredths)	6.10%	6.10%	2.78%
Estimated effective interest rate, maturing thereafter (in hundredths)	5.06%	5.06%	5.22%
Estimated Effective Interest Rate, Total (in hundredths)	5.22%	5.22%	5.28%
Long-term debt, fair value [Abstract]
Total Debt, Fair Value	521,706	529,710	507,978
Central Hudson [Member] | Variable Rate [Member]
Long-term debt maturities [Abstract]
Maturing in the remainder of current fiscal year	0		0
Maturing in next twelve months		0
Maturing in year two	0	0	0
Maturing in year three	0	0	0
Maturing in year four	0	0	0
Maturing in year five	0	0	0
Maturing thereafter	33,700	33,700	33,700
Total Debt Outstanding	33,700	33,700	33,700
Estimated effective interest rate [Abstract]
Estimated effective interest rate, remainder of current fiscal year (in hundredths)	0.00%		0.00%
Estimated effective interest rate, maturing in next twelve months (in hundredths)		0.00%
Estimated effective interest rate, maturing in year two (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing in year three (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing in year four (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing in year five (in hundredths)	0.00%	0.00%	0.00%
Estimated effective interest rate, maturing thereafter (in hundredths)	0.20%	0.28%	0.37%
Estimated Effective Interest Rate, Total (in hundredths)	0.20%	0.28%	0.37%
Long-term debt, fair value [Abstract]
Total Debt, Fair Value	33,700	33,700	33,700
CHEC [Member] | CH-Community Wind [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of equity investment	0
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of equity investment	1,636	1,603	2,438
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of equity investment	1,636	1,603	2,438
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of equity investment	0	0	0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of equity investment	$ 0	$ 0	$ 0

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CONSOLIDATED STATEMENT OF INCOME (UNAUDITED) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Operating Revenues
Electric	$ 138,163	$ 129,272
Natural gas	56,300	55,850
Competitive business subsidiaries:
Petroleum products	99,019	84,632
Other	4,892	4,318
Total Operating Revenues	298,374	274,072
Operation:
Purchased electricity and fuel used in electric generation	50,409	45,059
Purchased natural gas	23,399	24,614
Purchased petroleum	81,529	70,305
Other expenses of operation - regulated activities	66,792	59,886
Other expenses of operation - competitive business subsidiaries	13,303	12,422
Merger related costs	387	5,219
Depreciation and amortization	11,187	10,624
Taxes, other than income tax	14,947	13,730
Total Operating Expenses	261,953	241,859
Operating Income	36,421	32,213
Other Income and Deductions
Income from unconsolidated affiliates	199	52
Interest on regulatory assets and other interest income	1,385	1,719
Regulatory adjustments for interest costs	324	319
Other - net	127	(9)
Total Other Income (Deductions)	2,035	2,081
Interest Charges
Interest on long-term debt	6,430	6,218
Interest on regulatory liabilities and other interest	1,915	1,584
Total Interest Charges	8,345	7,802
Income before income taxes, non-controlling interest and preferred dividends of subsidiary	30,111	26,492
Income Taxes	11,165	11,669
Net Income	18,946	14,823
Net income (loss) attributable to non-controlling interest:
Dividends declared on Preferred Stock of subsidiary	92	242
Preferred Stock Redemption Premium	764	0
Net Income Attributable to CH Energy Group	18,090	14,581
Dividends declared on Common Stock	8,310	8,279
Change in Retained Earnings	9,780	6,302
Common Stock:
Average shares outstanding - Basic (in shares)	14,942	14,882
Average shares outstanding - Diluted (in shares)	15,156	15,143
Amounts attributable to CH Energy Group common shareholders
Earnings per share - Basic (in dollars per share)	$ 1.21	$ 0.98
Earnings per share - Diluted (in dollars per share)	$ 1.19	$ 0.96
Dividends Declared per share (in dollars per share)	$ 0.555	$ 0.555
Central Hudson Gas & Electric Corporation [Member]
Operating Revenues
Electric	138,163	129,272
Natural gas	56,300	55,850
Competitive business subsidiaries:
Total Operating Revenues	194,463	185,122
Operation:
Purchased electricity and fuel used in electric generation	50,409	45,059
Purchased natural gas	23,399	24,614
Other expenses of operation - regulated activities	66,792	59,886
Depreciation and amortization	9,955	9,468
Taxes, other than income tax	14,750	13,491
Total Operating Expenses	165,305	152,518
Operating Income	29,158	32,604
Other Income and Deductions
Interest on regulatory assets and other interest income	1,373	1,706
Regulatory adjustments for interest costs	324	319
Other - net	99	112
Total Other Income (Deductions)	1,796	2,137
Interest Charges
Interest on long-term debt	5,956	5,728
Interest on regulatory liabilities and other interest	1,845	1,527
Total Interest Charges	7,801	7,255
Income before income taxes, non-controlling interest and preferred dividends of subsidiary	23,153	27,486
Income Taxes	8,784	10,753
Net Income	14,369	16,733
Net income (loss) attributable to non-controlling interest:
Dividends declared on Preferred Stock of subsidiary	92	242
Preferred Stock Redemption Premium	764	0
Income Available for Common Stock	$ 13,513	$ 16,491

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Short-Term Borrowing Arrangements (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012
Short-term Debt [Line Items]
Borrowings outstanding	$ 56,000	$ 19,500	$ 71,000
Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Borrowings outstanding	56,000	19,500	71,000
Intercompany borrowings	0	0	(20,000)
Short-Term borrowings weighted average interest rate	0.97%	1.08%	1.12%
Outstanding balance under the intercompany loan borrowing program	0	0	20,000
CH Energy Group Holding Company [Member] | Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Borrowings outstanding	29,000	19,500	32,000
Central Hudson [Member]
Short-term Debt [Line Items]
Borrowings outstanding	27,000	0	59,000
Central Hudson [Member] | Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Borrowings outstanding	$ 27,000	$ 0	$ 59,000

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CONSOLIDATED BALANCE SHEET (UNAUDITED) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012
Utility Plant
Electric	$ 1,074,858	$ 1,067,352	$ 1,017,986
Natural gas	326,061	320,258	301,609
Common	163,993	162,352	151,086
Gross Utility Plant	1,564,912	1,549,962	1,470,681
Less: Accumulated depreciation	420,696	414,137	400,894
Net	1,144,216	1,135,825	1,069,787
Construction work in progress	61,367	58,053	66,518
Net Utility Plant	1,205,583	1,193,878	1,136,305
Non-Utility Property & Plant
Griffith non-utility property & plant	33,808	33,574	31,456
Other non-utility property & plant	524	524	524
Gross Non-Utility Property & Plant	34,332	34,098	31,980
Less: Accumulated depreciation - Griffith	23,223	23,001	22,220
Net Non-Utility Property & Plant	11,109	11,097	9,760
Current Assets
Cash and cash equivalents	15,546	30,508	65,867
Accounts receivable from customers - net of allowance for doubtful accounts	120,237	91,457	96,574
Accrued unbilled utility revenues	16,428	17,155	14,283
Other receivables	8,331	9,582	9,096
Fuel, materials and supplies	17,654	24,496	19,689
Regulatory assets	35,165	32,329	49,683
Fair value of derivative instruments	2,944	121	9
Unamortized debt expense	428	344	407
Special deposits and prepayments	26,559	21,362	25,777
Accumulated deferred income tax	8,182	12,205	8,456
Total Current Assets	251,474	239,559	289,841
Deferred Charges and Other Assets
Regulatory assets - pension plan	140,349	146,935	151,737
Regulatory assets - other	109,710	109,779	119,559
Fair value of derivative instruments	2,881	693	0
Goodwill	38,981	38,981	37,752
Other intangible assets - net	11,663	12,324	12,564
Unamortized debt expense	4,682	4,764	4,628
Investments in unconsolidated affiliates	2,241	2,536	2,559
Other investments	18,240	17,847	15,212
Other	5,478	6,556	5,884
Total Deferred Charges and Other Assets	334,225	340,415	349,895
Total Assets	1,802,391	1,784,949	1,785,801
CH Energy Group Common Shareholders' Equity
Common Stock	1,686	1,686	1,686
Paid-in capital	349,514	349,428	348,306
Retained earnings	257,883	248,103	248,693
Treasury stock - 1,947,234 shares, 1,967,123 shares and 1,241,322 shares, respectively	(89,891)	(90,141)	(91,978)
Accumulated other comprehensive income	368	380	296
Capital stock expense	0	(166)	(328)
Total Equity	519,560	509,290	506,675
Preferred Stock of subsidiary	0	9,027	21,027
Long-term debt	479,926	486,926	494,002
Total Capitalization	999,486	1,005,243	1,021,704
Current Liabilities
Current maturities of long-term debt	38,076	31,076	1,006
Notes payable	56,000	19,500	71,000
Accounts payable	39,155	52,812	36,183
Accrued interest	8,875	5,931	7,330
Dividends payable	8,310	8,301	8,521
Accrued vacation and payroll	8,187	7,984	7,291
Customer advances	15,722	28,309	17,315
Customer deposits	7,115	7,135	7,235
Regulatory liabilities	14,568	10,736	8,959
Fair value of derivative instruments	517	1,259	22,118
Accrued environmental remediation costs	4,267	7,117	7,064
Accrued income and other taxes	6,146	635	817
Deferred revenues	3,936	4,801	3,853
Other	21,170	15,105	16,200
Total Current Liabilities	232,044	200,701	214,892
Deferred Credits and Other Liabilities
Regulatory liabilities - OPEB	9,696	7,975	8,974
Regulatory liabilities - other	108,704	97,485	101,535
Operating reserves	3,456	3,827	3,181
Fair value of derivative instruments	93	218	1,688
Accrued environmental remediation costs	8,250	8,324	10,559
Accrued OPEB costs	58,730	58,412	53,757
Accrued pension costs	88,170	113,227	95,896
Tax reserve	2,047	2,000	3,174
Other	21,028	20,643	20,520
Total Deferred Credits and Other Liabilities	300,174	312,111	299,284
Accumulated Deferred Income Tax	270,687	266,894	249,921
Commitments and Contingencies
Total Capitalization and Liabilities	1,802,391	1,784,949	1,785,801
Central Hudson Gas & Electric Corporation [Member]
Utility Plant
Electric	1,074,858	1,067,352	1,017,986
Natural gas	326,061	320,258	301,609
Common	163,993	162,352	151,086
Gross Utility Plant	1,564,912	1,549,962	1,470,681
Less: Accumulated depreciation	420,696	414,137	400,894
Net	1,144,216	1,135,825	1,069,787
Construction work in progress	61,367	58,053	66,518
Net Utility Plant	1,205,583	1,193,878	1,136,305
Non-Utility Property & Plant
Other non-utility property & plant	524	524	524
Net Non-Utility Property & Plant	524	524	524
Current Assets
Cash and cash equivalents	7,115	24,352	55,786
Accounts receivable from customers - net of allowance for doubtful accounts	77,609	60,155	65,922
Accrued unbilled utility revenues	16,428	17,155	14,283
Other receivables	4,630	5,206	6,086
Fuel, materials and supplies	14,194	19,264	16,389
Regulatory assets	35,165	32,329	49,683
Fair value of derivative instruments	2,941	95	0
Unamortized debt expense	428	344	407
Special deposits and prepayments	22,496	18,473	21,311
Accumulated deferred income tax	1,256	5,313	2,019
Total Current Assets	182,262	182,686	231,886
Deferred Charges and Other Assets
Regulatory assets - pension plan	140,349	146,935	151,737
Regulatory assets - other	109,710	109,779	119,559
Fair value of derivative instruments	2,881	693	0
Unamortized debt expense	4,682	4,764	4,628
Other investments	17,743	17,368	14,745
Other	2,734	3,740	2,218
Total Deferred Charges and Other Assets	278,099	283,279	292,887
Total Assets	1,666,468	1,660,367	1,661,602
CH Energy Group Common Shareholders' Equity
Common Stock	84,311	84,311	84,311
Paid-in capital	199,952	199,980	199,980
Retained earnings	198,682	190,169	182,456
Capital stock expense	(4,633)	(4,799)	(4,961)
Total Equity	478,312	469,661	461,786
Preferred Stock of subsidiary	0	9,027	21,027
Long-term debt	452,950	459,950	465,950
Total Capitalization	931,262	938,638	948,763
Current Liabilities
Current maturities of long-term debt	37,000	30,000	0
Notes payable	27,000	0	59,000
Accounts payable	29,639	45,002	27,299
Accrued interest	8,249	5,782	6,686
Dividends payable	0	0	242
Accrued vacation and payroll	6,424	6,708	5,671
Customer advances	10,243	18,084	11,231
Customer deposits	7,042	7,069	7,170
Regulatory liabilities	14,568	10,736	8,959
Fair value of derivative instruments	517	1,259	22,118
Accrued environmental remediation costs	3,838	6,660	6,562
Accrued income and other taxes	8,635	3,142	1,564
Other	14,549	12,095	10,764
Total Current Liabilities	167,704	146,537	167,266
Deferred Credits and Other Liabilities
Regulatory liabilities - OPEB	9,696	7,975	8,974
Regulatory liabilities - other	108,704	97,485	101,535
Operating reserves	2,647	2,696	2,148
Fair value of derivative instruments	93	218	1,688
Accrued environmental remediation costs	7,240	7,293	9,407
Accrued OPEB costs	58,730	58,412	53,757
Accrued pension costs	88,170	113,227	95,896
Tax reserve	2,047	2,000	3,174
Other	20,071	19,705	19,564
Total Deferred Credits and Other Liabilities	297,398	309,011	296,143
Accumulated Deferred Income Tax	270,104	266,181	249,430
Commitments and Contingencies
Total Capitalization and Liabilities	1,666,468	1,660,367	1,661,602
Central Hudson Enterprises Corporation [Member]
Deferred Charges and Other Assets
Investments in unconsolidated affiliates	$ 42,923

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2013

Commitments and Contingencies [Abstract]

Information For Certain MGP Sites

A summary of amounts accrued and spent are detailed in the chart below (In Thousands):

Site #	Liability Recorded as of 12/31/12		Amounts Spent in 2013(1)		Liability Adjustment			Liability Recorded as of 3/31/13		Current Portion of Liability at 3/31/13		Long-Term Portion of Liability at 3/31/13
1, 2, 3, 4	$	12,210	$	3,628	$	883		$	9,465	$	2,916	$	6,549
5, 6		1,743		68		(62	)		1,613		922		691
	$	13,953	$	3,696	$	821		$	11,078	$	3,838	$	7,240

(1) Amounts spent in 2013 as shown above do not include legal fees of approximately $8 thousand.

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Accounting for Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2013

Accounting for Derivative Instruments and Hedging Activities [Abstract]

Accounting for Derivative Instruments and Hedging Activities

NOTE 14 - Accounting for Derivative Instruments and Hedging Activities

Accounting for Derivatives

Central Hudson has been authorized to fully recover risk management costs through its natural gas and electricity cost adjustment charge clauses.  Risk management costs are defined by the PSC as "costs associated with transactions that are intended to reduce price volatility or reduce overall costs to customers.  These costs include transaction costs, and gains and losses associated with risk management instruments."  The related gains and losses associated with Central Hudson's derivatives are included as part of Central Hudson's commodity cost and/or price-reconciled in its natural gas and electricity cost adjustment charge clauses, and are not designated as hedges.  Additionally, Central Hudson has been authorized to fully recover the interest costs associated with its variable rate debt, which includes costs and gains or losses associated with its interest rate cap contracts.  As a result, these derivative activities at Central Hudson do not impact earnings.

Derivative activity related to Griffith's heating oil contracts is not material.

The percentage of Central Hudson's electric and gas requirements covered with fixed price forward purchases is as follows:

Central Hudson	% of Requirement Hedged (1)
Electric Derivative Contracts:
April 2013 – December 2013		34.0	%
2014		28.8	%
2015		21.7	%
2016		7.2	%
2017		7.1	%
Natural Gas Derivative Contracts:
November 2013 – March 2014		2.3	%

(1) Projected coverage as of March 31, 2013.

Derivative Risks

The basic types of risks associated with derivatives are market risk (that the value of the derivative will be adversely impacted by changes in the market, primarily the change in interest and exchange rates) and credit risk (that the counterparty will not perform according to the terms of the contract).  The market risk of the derivatives generally offset the market risk associated with the hedged commodity.

The majority of Central Hudson and Griffith's derivative instruments contain provisions that require the Company to maintain specified issuer credit ratings and financial strength ratings.  Should the company's ratings fall below these specified levels, it would be in violation of the provisions, and the derivatives' counterparties could terminate the contracts and request immediate payment.

To help limit the credit exposure of their derivatives, both Central Hudson and Griffith have entered into master netting agreements with counterparties whereby contracts in a gain position can be offset against contracts in a loss position.  Of the nineteen total agreements held by both companies, eleven contain credit-risk related contingent features. As of March 31, 2013, the amount that would be required to settle these instruments if the contingent features were triggered is immaterial.

CH Energy Group and Central Hudson have elected gross presentation for their derivative contracts under master netting agreements and collateral positions.  On March 31, 2013, neither Central Hudson nor Griffith had collateral posted against the fair value amount of derivatives.

The net presentation for CH Energy Group's and Central Hudson's derivative assets and liabilities as of March 31, 2013, December 31, 2012 and March 31, 2012 are as follows (In Thousands):

							Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Financial Position		Net Amount of Assets Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
As of March 31, 2013
Derivative Contracts:
Central Hudson - electric	$	5,822	$	-	$	5,822	$	608	$	-	$	5,214
Total Central Hudson Assets	$	5,822	$	-	$	5,822	$	608	$	-	$	5,214
Griffith - heating oil	$	3	$	-	$	3	$	-	$	-	$	3
Total CH Energy Group Assets	$	5,825	$	-	$	5,825	$	608	$	-	$	5,217
As of December 31, 2012
Derivative Contracts:
Central Hudson - electric	$	693	$	-	$	693	$	664	$	-	$	29
Central Hudson - gas		95		-		95		18		-		77
Total Central Hudson Assets	$	788	$	-	$	788	$	682	$	-	$	106
Griffith - heating oil	$	26	$	-	$	26	$	-	$	-	$	26
Total CH Energy Group Assets	$	814	$	-	$	814	$	682	$	-	$	132
As of March 31, 2012
Derivative Contracts:
Central Hudson - electric	$	-	$	-	$	-	$	-	$	-	$	-
Total Central Hudson Assets	$	-	$	-	$	-	$	-	$	-	$	-
Griffith - heating oil	$	9	$	-	$	9	$	-	$	-	$	9
Total CH Energy Group Assets	$	9	$	-	$	9	$	-	$	-	$	9

							Gross Amounts Not Offset in the Statement of Financial Position
Description	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Financial Position		Net Amount of Assets Presented in the Statement of Financial Position		Financial Instruments		Cash Collateral Received		Net Amount
As of March 31, 2013
Derivative Contracts:
Central Hudson - electric	$	608	$	-	$	608	$	608	$	-	$	-
Central Hudson - gas		2		-		2		-		-		2
Total Central Hudson Liabilities	$	610	$	-	$	610	$	608	$	-	$	2
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	610	$	-	$	610	$	608	$	-	$	2
As of December 31, 2012
Derivative Contracts:
Central Hudson - electric	$	1,367	$	-	$	1,367	$	664	$	-	$	703
Central Hudson - gas		110		-		110		18		-		92
Total Central Hudson Liabilities	$	1,477	$	-	$	1,477	$	682	$	-	$	795
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	1,477	$	-	$	1,477	$	682	$	-	$	795
As of March 31, 2012
Derivative Contracts:
Central Hudson - electric	$	23,792	$	-	$	23,792	$	-	$	-	$	23,792
Central Hudson - gas		14		-		14		-		-		14
Total Central Hudson Liabilities	$	23,806	$	-	$	23,806	$	-	$	-	$	23,806
Griffith - heating oil	$	-	$	-	$	-	$	-	$	-	$	-
Total CH Energy Group Liabilities	$	23,806	$	-	$	23,806	$	-	$	-	$	23,806

The fair value of CH Energy Group's and Central Hudson's derivative instruments and their location in the respective Balance Sheets are summarized in the table below, followed by a summarization of their effect on the respective Statements of Income.  For additional information regarding Central Hudson's physical hedges, see the discussion following the caption "Electricity Purchase Commitments" in Note 12 - "Commitments and Contingencies."

Gross Fair Value of Derivative Instruments

Derivative contracts are measured at fair value on a recurring basis.  As of March 31, 2013, December 31, 2012, and March 31, 2012, CH Energy Group's and Central Hudson's derivative assets and liabilities by category and hierarchy level are as follows (In Thousands):

Asset or Liability Category	Fair Value			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
As of March 31, 2013(1)
Assets:
Derivative Contracts:
Central Hudson - electric	$	5,822		$	-		$	-	$	5,822
Total Central Hudson Assets	$	5,822		$	-		$	-	$	5,822
Griffith - heating oil	$	3		$	3		$	-	$	-
Total CH Energy Group Assets	$	5,825		$	3		$	-	$	5,822
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(608	)	$	-		$	-	$	(608	)
Central Hudson - natural gas		(2	)		(2	)		-		-
Total CH Energy Group and Central Hudson Liabilities	$	(610	)	$	(2	)	$	-	$	(608	)
As of December 31, 2012(1)
Assets:
Derivative Contracts:
Central Hudson - electric	$	693		$	-		$	-	$	693
Central Hudson - natural gas		95			95			-		-
Total Central Hudson Assets	$	788		$	95		$	-	$	693
Griffith - heating oil	$	26		$	26		$	-	$	-
Total CH Energy Group Assets	$	814		$	121		$	-	$	693
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(1,367	)	$	(110	)	$	-	$	(1,367	)
Central Hudson - natural gas		(110	)		-			-		-
Total CH Energy Group and Central Hudson Liabilities	$	(1,477	)	$	(110	)	$	-	$	(1,367	)
As of March 31, 2012(1)
Assets:
Derivative Contracts:
Griffith - heating oil	$	9		$	-		$	-	$	-
Total CH Energy Group Assets	$	9		$	-		$	-	$	-
Liabilities:
Derivative Contracts:
Central Hudson - electric	$	(23,792	)	$	-		$	-	$	(23,792	)
Central Hudson - natural gas		(14	)		(14	)		-		-
Total CH Energy Group and Central Hudson Liabilities	$	(23,806	)	$	(14	)	$	-	$	(23,792	)

(1) Interest rate cap agreement is not shown in the above table because the FMV at each period stated was zero.

Central Hudson obtains forward pricing for Level 3 derivatives from an independent third party provider of derivative pricing. Significant unobservable inputs utilized in their pricing model are bi-lateral contracts and projected activity of certain major participants. Generally, a change in any of the underlying assumptions would result in a positively correlated change in fair value measurement.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value and classified as Level 3 in the fair value hierarchy (In Thousands):

	Three Months Ended
	March 31,
	2013			2012
Balance at Beginning of Period	$	(674	)	$	(16,830	)
Unrealized gains/(losses)		5,888			(6,962	)
Realized gains/(losses)		5,119			(7,654	)
Purchases		-			-
Issuances		-			-
Sales and settlements		(5,119	)		7,654
Transfers in and/or out of Level 3		-			-
Balance at End of Period	$	5,214		$	(23,792	)
The amount of total gains or losses for the period included in earnings attributable to the change in unrealized gains or losses relating to derivatives still held at end of period	$	-		$	-

The company did not have any transfers into or out of Levels 1 or 2.

The Effect of Derivative Instruments on the Statements of Income

Realized gains and losses on Central Hudson's derivative instruments are conveyed to or recovered from customers through PSC authorized deferral accounting mechanisms, with no material impact on cash flows, results of operations or liquidity.  Realized gains and losses on Central Hudson's energy derivative instruments are reported as part of purchased electricity and fuel used in electric generation in Central Hudson's Consolidated Statement of Income as the corresponding amounts are either recovered from or returned to customers through electric cost adjustment clauses in revenues.

For the three months ended March 31, 2013 and 2012, neither CH Energy Group nor Central Hudson had derivatives designated as hedging instruments.  The following table summarizes the effects of CH Energy Group and Central Hudson derivatives on the statements of income (In Thousands):

	Amount of Gain (Loss) Recognized as Increase/(Decrease) in the Income Statement
	Three Months Ended March 31,
	2013			2012			Location of Gain (Loss)
Central Hudson:
Electricity swap contracts	$	5,119		$	(7,654	)	Regulatory (asset)/liability(1)
Natural gas swap contracts		(44	)		(2,406	)	Regulatory (asset)/liability(1)
Total return swap contracts		-			617		Other-net
Total Central Hudson	$	5,075		$	(9,443	)
Griffith:
Heating oil call option contracts	$	(2	)	$	30		Purchased petroleum
Griffith other derivative financial instrument		-			-		Purchased petroleum
Total Griffith	$	(2	)	$	30
Total CH Energy Group	$	5,073		$	(9,413	)

(1) Realized gains and losses on Central Hudson's derivative instruments are conveyed to or recovered from customers through PSC authorized deferral accounting mechanisms, with an offset in revenue and on the balance sheet, and no impact on results of operations.

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Segments and Related Information (Tables)

3 Months Ended

Mar. 31, 2013

Segments and Related Information [Abstract]

CH Energy Group Segment Disclosure

CH Energy Group Segment Disclosure

(In Thousands)

	Three Months Ended March 31, 2013
	Segments						Other
	Central Hudson						Businesses
			Natural				and
	Electric		Gas		Griffith		Investments			Eliminations			Total
Revenues from external customers	$	138,163	$	56,300	$	103,911	$	-		$	-		$	298,374
Intersegment revenues		2		116		-		-			(118	)		-
Total revenues		138,165		56,416		103,911		-			(118	)		298,374
Operating income (loss)		16,967		12,191		7,791		(528	)		-			36,421
Interest and investment income		1,182		191		-		656			(644	)(1)		1,385
Interest charges		6,166		1,635		644		544			(644	)(1)		8,345
Income (Loss) before income taxes		12,306		10,847		7,233		(275	)		-			30,111
Net Income Attributable to CH Energy Group		7,263		6,250		4,268		309			-			18,090
Segment assets at March 31		1,296,078		370,390		122,695		13,928			(700	)		1,802,391

(1) This represents the elimination of inter-company interest income (expense) generated from lending activities between CH Energy Group (the holding company), and its subsidiaries (CHEC and Griffith).

CH Energy Group Segment Disclosure

(In Thousands)

	Three Months Ended March 31, 2012
	Segments						Other
	Central Hudson						Businesses
			Natural				and
	Electric		Gas		Griffith		Investments			Eliminations			Total
Revenues from external customers	$	129,272	$	55,850	$	88,950	$	-		$	-		$	274,072
Intersegment revenues		3		90		-		-			(93	)		-
Total revenues		129,275		55,940		88,950		-			(93	)		274,072
Operating income (loss)		20,125		12,479		4,947		(5,338	)		-			32,213
Interest and investment income		1,436		270		-		697			(684	)(1)		1,719
Interest charges		5,716		1,539		696		535			(684	)(1)		7,802
Income (Loss) before income taxes		16,224		11,262		4,268		(5,262	)		-			26,492
Net Income (Loss) Attributable to CH Energy Group		10,278		6,213		2,518		(4,428	)		-			14,581
Segment assets at March 31		1,284,078		377,524		109,457		16,417			(1,675	)		1,785,801

(1) This represents the elimination of inter-company interest income (expense) generated from lending activities between CH Energy Group (the holding company), and its subsidiaries (CHEC and Griffith).

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Subsequent Events

3 Months Ended

Mar. 31, 2013

Subsequent Events [Abstract]

Subsequent Events

NOTE 16 – Subsequent Events

In addition to items disclosed in the footnotes, CH Energy Group has performed an evaluation of events subsequent to March 31, 2013 through the date the financial statements were issued and noted two additional items to disclose.

On April 18, 2013, Central Hudson's Board of Directors approved a $5.0 million dividend payment to parent CH Energy Group that was paid on April 30, 2013.

On April 24, 2013, the Commission issued a notice stating that the Administrative Law Judges ("ALJs") assigned to this matter would prepare a Recommended Decision ("RD") for the Commission.  On May 3, 2013 the Recommended Decision of the two Administrative Law Judges – an advisory document – was issued by the PSC.  See Item 7 - "Management's Discussion and Analysis of Financial Condition and Results of Operations" under the caption "Regulatory Matters – PSC Proceedings" for further discussion regarding the terms of the Joint Proposal and schedule.

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CONSOLIDATED BALANCE SHEET (UNAUDITED) (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012
Current Assets
Allowance for doubtful accounts	$ 6.0	$ 6.5	$ 7.0
Capitalization
Common Stock, authorized (in shares)	30,000,000	30,000,000	30,000,000
Common Stock, par value (in dollars per share)	$ 0.1	$ 0.1	$ 0.1
Common Stock, issued (in shares)	16,862,087	16,862,087	16,862,087
Common Stock, outstanding (in shares)	14,960,976	14,954,884	14,914,853
Treasury Stock (in shares)	1,901,111	1,907,203	1,947,234
Central Hudson Gas & Electric Corporation [Member]
Current Assets
Allowance for doubtful accounts	$ 4.2	$ 4.6	$ 5.4
Capitalization
Common Stock, authorized (in shares)	30,000,000	30,000,000	30,000,000
Common Stock, par value (in dollars per share)	$ 5	$ 5	$ 5
Common Stock, issued (in shares)	16,862,087	16,862,087	16,862,087
Common Stock, outstanding (in shares)	16,862,087	16,862,087	16,862,087

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CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Net Income	$ 18,946	$ 14,823
Fair value of cash flow hedges:
Net unrealized losses on investments held by equity method investees - net of tax	(12)	(58)
Other comprehensive Incomes (loss)	(12)	(58)
Comprehensive Income	18,934	14,765
Comprehensive income attributable to non-controlling interest	856	242
Comprehensive income attributable to CH Energy Group	18,078	14,523
Central Hudson Gas & Electric Corporation [Member]
Net Income	14,369	16,733
Fair value of cash flow hedges:
Other comprehensive Incomes (loss)	0	0
Comprehensive Income	$ 14,369	$ 16,733

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Capitalization Long-Term Debt

3 Months Ended

Mar. 31, 2013

Capitalization - Long-Term Debt [Abstract]

Capitalization - Long-Term Debt

NOTE 9 – Capitalization – Long-Term Debt

NYSERDA

Central Hudson's outstanding Series B NYSERDA Bonds total $33.7 million at March 31, 2013.  These bonds are tax-exempt multi-modal bonds that are currently in a variable rate mode.  In its Orders, the PSC has authorized deferral accounting treatment for variations in the interest costs from these bonds.  As such, variations between the actual interest rates on these bonds and the interest rate included in the current delivery rate structure for these bonds are deferred for future recovery from or refund to customers and therefore do not impact earnings.

To mitigate the potential cash flow impact from unexpected increases in short-term interest rates on Series B NYSERDA Bonds, on March 28, 2012, Central Hudson purchased an interest rate cap based on an index of short-term tax-exempt debt.  The rate cap is two years in length with a notional amount aligned with Series B and will expire on April 1, 2014.  The cap is based on the monthly weighted average of an index of tax-exempt variable rate debt, multiplied by 175%.  Central Hudson would receive a payout if the adjusted index exceeds 5.0% for a given month.  The rate cap replaced an expiring rate cap with substantially similar terms. See Note 14 – "Accounting for Derivative Instruments and Hedging Activities" for fair value disclosures related to this instrument.

Central Hudson is currently evaluating what actions, if any, it may take in the future in connection with its Series B NYSERDA Bonds.  Potential actions may include converting the debt to another interest rate mode or refinancing with taxable bonds.

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Document and Entity Information	3 Months Ended
	Mar. 31, 2013	Apr. 30, 2013
Entity Information [Line Items]
Entity Registrant Name	CH ENERGY GROUP INC
Entity Central Index Key	0001061393
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		14,973,794
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2013
CENTRAL HUDSON GAS & ELECTRIC CORP [Member]
Entity Information [Line Items]
Entity Registrant Name	CENTRAL HUDSON GAS & ELECTRIC CORP
Entity Central Index Key	0000018647
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		16,862,087

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Post-Employment Benefits

3 Months Ended

Mar. 31, 2013

Post-Employment Benefits [Abstract]

Post-Employment Benefits

NOTE 10 – Post-Employment Benefits

Central Hudson provides certain health care and life insurance benefits for retired employees through its post-retirement benefit plans.  Central Hudson pension benefits include a Retirement Income Plan ("RIP") and a non-qualified Supplemental Executive Retirement Plan ("SERP").

In its Orders, the PSC has authorized deferral accounting treatment for any variations between actual pension and other post-employment benefits ("OPEB") expense and the amount included in the current delivery rate structure.  As a result, post-retirement benefit plans at Central Hudson do not have any impact on earnings.  The following information is provided in accordance with current accounting requirements.

The following are the components of Central Hudson's net periodic benefit costs for its pension and OPEB plans for the three months ended March 31, 2013 and 2012 (In Thousands):

	Pension Benefits						OPEB(1)
	Three Months Ended March 31,						Three Months Ended March 31,
	2013			2012			2013			2012
Service cost	$	3,073		$	2,741		$	760		$	644
Interest cost		5,732			6,177			1,382			1,662
Expected return on plan assets		(7,698	)		(6,768	)		(1,723	)		(1,734	)
Amortization of:
Prior service cost (credit)		433			501			(1,465	)		(1,466	)
Transitional obligation		-			-			2			641
Recognized actuarial loss		4,840			5,788			1,582			2,326
Net Periodic Benefit Cost	$	6,380		$	8,439		$	538		$	2,073

(1) The OPEB amounts for all periods presented reflect the effect of the Medicare Prescription Drug Improvement and Modernization Act of 2003.

The balance of Central Hudson's accrued pension costs (i.e., the under-funded status) is as follows (In Thousands):

	March 31,		December 31,		March 31,
	2013		2012		2012
Accrued pension costs	$	88,828	$	113,885	$	96,547

These balances include the difference between the projected benefit obligation ("PBO") for pensions and the market value of the pension assets, and the liability for the non-qualified Supplemental Executive Retirement Plan ("SERP").

The following reflects the impact of the recording of funding status adjustments on the Balance Sheets of CH Energy Group and Central Hudson (In Thousands):

	March 31,			December 31,			March 31,
	2013			2012			2012
Prefunded pension costs prior to funding status adjustment	$	44,956		$	25,172		$	49,996
Additional liability required		(133,784	)		(139,057	)		(146,543	)
Total accrued pension costs	$	(88,828	)	$	(113,885	)	$	(96,547	)
Total offset to additional liability - Regulatory assets - Pension Plan	$	133,784		$	139,057		$	146,543

Gains or losses and prior service costs or credits that arise during the period but that are not recognized as components of net periodic pension cost would typically be recognized as a component of other comprehensive income, net of tax.  However, Central Hudson has PSC approval to record regulatory assets rather than adjusting comprehensive income to offset the additional liability.

Contribution levels for the RIP and OPEB plans are determined by various factors including the discount rate, expected return on plan assets, benefit changes, and corporate resources.  In addition, OPEB plan contribution levels are also impacted by medical claims assumptions used and mortality assumptions used.

Contributions for the three months ended March 31, 2013 and 2012 were as follows (In Thousands):

	Retirement Income Plan				OPEB
	Three Months Ended				Three Months Ended
	March 31,				March 31,
	2013		2012		2013		2012
Contributions	$	26,000	$	28,000	$	-	$	-

Retirement Plan Policy and Strategy

Central Hudson's Retirement Plan investment policy seeks to achieve long-term growth and income to match the long-term nature of its funding obligations. Management has transitioned to a liability-driven investment ("LDI") strategy for its pension plan assets.  Management's objective is to reduce the volatility of the plan's funded status and the level of contributions by more closely aligning the characteristics of plan assets with liabilities.

Asset allocation targets in effect for the three months ended March 31, 2013 as well as actual asset allocations as of March 31, 2013 and December 31, 2012 expressed as a percentage of the market value of the Retirement Plan's assets, are summarized in the table below:

Asset Class	December 31, 2012			Minimum			Target Average			Maximum			March 31, 2013
Equity Securities		50.5	%		45	%		50	%		55	%		51.2	%
Debt Securities		47.4	%		45	%		50	%		55	%		47.4	%
Other(1)		2.1	%		-	%		-	%		-	%		1.4	%

(1) Consists of temporary cash investments, as well as receivables for investments sold and interest, and payables for investments purchased, which have not settled as of that date.

The above asset allocations as of December 31, 2012 and March 31, 2013 reflect the transition to a LDI strategy resulting in an asset allocation of approximately 50% equity and 50% long duration fixed income assets. Due to market value fluctuations, RIP assets will require rebalancing from time to time to maintain the asset allocation within target ranges.  Management is currently monitoring ongoing market activity and the impact on the pension plan asset allocations to determine if a rebalancing will be necessary.

Central Hudson cannot assure that the RIP's return objectives or funded status objectives will be achieved.

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CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Fair value of cash flow hedges:
Net unrealized losses recorded from investments held by equity method investees - tax	$ 8	$ 38

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Income Tax

3 Months Ended

Mar. 31, 2013

Income Tax [Abstract]

Income Tax

NOTE 4 – Income Tax

In September of 2010, Central Hudson filed a request with the Internal Revenue Service ("IRS") to change the Company's tax accounting method related to costs to repair and maintain utility assets.  The change was effective for the tax year ending December 31, 2009.  This change allows Central Hudson to take a current tax deduction for a significant amount of repair costs that were previously capitalized for tax purposes.

In September 2012, Central Hudson filed corporate income tax returns for the year ended December 31, 2011.  With that filing, the Company included an election to adopt the provisions of Revenue Procedure 2011-43 ("Rev Proc"), which provided IRS guidance related to the repair deduction previously taken on electric transmission and distribution property. Adoption of the provisions of the Rev Proc resulted in reduced federal and state net operating income tax loss ("NOL") carryforwards. The Company believes the remaining electric repair deduction meets and complies with the requirements included in the Rev Proc. As such, tax reserves related to the electric transmission and distribution repair deductions have been reclassified to deferred tax liability accounts.

IRS guidance with respect to repairs taken on Gas Transmission and Distribution repairs is still pending. Therefore, remaining reserves related to the gas repair deduction continue to be shown as "Tax Reserve" under the Deferred Credits and Other Liabilities section of the Central Hudson Balance Sheet.

Other than the uncertain tax position related to the Company's accounting method change for gas transmission and distribution repairs, there are no other uncertain tax positions.  The following is a summary of activity related to uncertain tax positions (In Thousands):

	Three Months Ended March 31,
	2013		2012
Balance at the beginning of the period	$	2,000	$	3,172
Adjustments related to tax accounting method change		47		2
Balance at the end of the period	$	2,047	$	3,174

Jurisdiction	Tax Years Open for Audit
Federal(1)	2007 - 2012
New York State	2009 - 2012

(1)   Federal tax filings for the years 2007 - 2011 are currently under audit.

Reconciliation - CH Energy Group

The following is a reconciliation between the amount of federal income tax computed on income before taxes at the statutory rate and the amount reported in CH Energy Group's Consolidated Statement of Income (In Thousands):

	Three Months Ended March 31,
	2013			2012
Net income attributable to CH Energy Group	$	18,090		$	14,581
Preferred Stock dividends of Central Hudson		92			242
Preferred Stock Redemption Premium		764			-
Federal income tax		7,465			-
State income tax		544			408
Deferred federal income tax		2,833			10,452
Deferred state income tax		323			809
Income before taxes	$	30,111		$	26,492
Computed federal tax at 35% statutory rate	$	10,539		$	9,272
State income tax net of federal tax benefit		879			1,293
Depreciation flow-through		891			797
Cost of Removal		(616	)		(596	)
Merger Transaction Costs		84			1,705
Other		(612	)		(802	)
Total income tax	$	11,165		$	11,669
Effective tax rate - federal		34.2	%		39.4	%
Effective tax rate - state		2.9	%		4.6	%
Effective tax rate - combined		37.1	%		44.0	%

The decrease in the effective tax rate for the three months ended March 31, 2013 as compared to 2012 was primarily driven by the decrease in merger related costs.  Merger related transaction costs that are facilitative in nature are considered nondeductible for tax purposes. Merger related transaction costs incurred for the three months ended March 31, 2013 were $0.2 million and for the three months ended March 31, 2012 were $4.3 million which have been determined to be facilitative and therefore nondeductible.

Reconciliation - Central Hudson

The following is a reconciliation between the amount of federal income tax computed on income before taxes at the statutory rate and the amount reported in Central Hudson's Statement of Income (In Thousands):

	Three Months Ended March 31,
	2013			2012
Net income	$	14,369		$	16,733
Federal income tax		5,318			-
Deferred federal income tax		2,565			9,320
Deferred state income tax		901			1,433
Income before taxes	$	23,153		$	27,486
Computed federal tax at 35% statutory rate	$	8,104		$	9,620
State income tax net of federal tax benefit		901			1,433
Depreciation flow-through		891			797
Cost of Removal		(616	)		(596	)
Other		(496	)		(501	)
Total income tax	$	8,784		$	10,753
Effective tax rate - federal		34.0	%		33.9	%
Effective tax rate - state		3.9	%		5.2	%
Effective tax rate - combined		37.9	%		39.1	%

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New Accounting Guidance

3 Months Ended

Mar. 31, 2013

New Accounting Guidance [Abstract]

New Accounting Guidance

NOTE 3 - New Accounting Guidance

Newly adopted and soon to be adopted accounting guidance is summarized below, including explanations for any new guidance issued in 2013 (except that which is not currently applicable) and the expected impact on CH Energy Group and its subsidiaries.

Impact	Category	Accounting Reference	Title	Issued Date	Effective Date
1	Balance Sheet (Topic 210)	ASU No. 2011-11	Disclosures about Offsetting Assets and Liabilities	Dec-11	Jan-13
1	Balance Sheet (Topic 210)	ASU No. 2013-01	Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities	Jan-13	Jan-13
1	Comprehensive Income (Topic 220)	ASU No. 2013-02	Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income	Feb-13	Dec-12
2	Liabilities (Topic 405)	ASU No. 2013-04	Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date	Feb-13	Dec-13

Impact Key:
(1)	No current impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries when adopted on the effective date noted.  Additional disclosures have been added or presentation of information modified where required.
(2)	No anticipated impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries upon future adoption.

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Other Fair Value Measurements

3 Months Ended

Mar. 31, 2013

Other Fair Value Measurements [Abstract]

Other Fair Value Measurements

NOTE 15 – Other Fair Value Measurements

Other Assets Recorded at Fair Value

In addition to the derivatives reported at fair value discussed in Note 14 – "Accounting for Derivative Instruments and Hedging Activities", CH Energy Group reports certain other assets at fair value in the Consolidated Balance Sheets. The following table summarizes the amount reported at fair value related to these assets as of March 31, 2013, December 31, 2012, and March 31, 2012 (In Thousands):

Asset Category	Fair Value		Quoted Prices in Active Markets for Identical Assets(Level 1)		Significant Other Observable Inputs(Level 2)		Significant Unobservable Inputs(Level 3)
As of March 31, 2013:
Other investments	$	1,636	$	1,636	$	-	$	-
As of December 31, 2012:
Other investments	$	1,603	$	1,603	$	-	$	-
As of March 31, 2012:
Other investments	$	2,438	$	2,438	$	-	$	-

As of March 31, 2013, December 31, 2012 and March 31, 2012, a portion of the trust assets for the funding of CH Energy Group's Directors and Executives Deferred Compensation Plan were invested in mutual funds, which are measured at fair value on a recurring basis.  These investments are valued at quoted market prices in active markets and as such are Level 1 investments as defined in the fair value hierarchy.  These amounts are included in the line titled "Other investments" within the Deferred Charges and Other Assets section of the CH Energy Group Consolidated and Central Hudson Balance Sheets.

In the third quarter of 2011, CHEC recorded an impairment loss for the full value of its investment in CH-Community Wind.  An impairment analysis was performed and based on this analysis, the present value of the after-tax projected cash flows using a market participant's expected return, is insufficient for CHEC to recover any of its investment.  This analysis used significant unobservable inputs including a discount rate and projected cash flows for the entity and as such this is a Level 3 investment. As of March 31, 2013, management believes the fair value of this investment remains at zero and is therefore appropriately reserved.

Other Fair Value Disclosure

Financial instruments are recorded at carrying value in the financial statements, however, the fair value of these instruments is disclosed below in accordance with current accounting guidance related to financial instruments.

The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value:

Cash and Cash Equivalents:  Carrying amount (Level 1)

Long-term Debt:  Quoted market prices for the same or similar issues (Level 2)

Valuations were obtained for each issue using the observed Treasury market in conjunction with secondary market trading levels and recent new issuances of comparable companies.

Notes Payable:  Carrying amount (Level 2)

Due to the short-term nature (typically one month or less) of our Notes Payable borrowings, the carrying value is equivalent to the current FMV.

Long-term Debt Maturities and Fair Value - CH Energy Group

(Dollars in Thousands)

		Fixed Rate				Variable Rate				Total Debt Outstanding
Expected Maturity Date		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate
As of March 31, 2013:
	2013	$	31,076	6.93	%	$	-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	2017		34,406	6.13	%		-	-	%
	Thereafter		386,625	5.13	%		33,700	0.20	%
	Total	$	484,302	5.31	%	$	33,700	0.20	%	$	518,002	5.02	%
	Fair Value	$	554,724			$	33,700			$	588,424
As of December 31, 2012:
	2013	$	31,076	6.93	%	$	-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	2017		34,406	6.13	%		-	-	%
	Thereafter		386,625	5.13	%		33,700	0.28	%
	Total	$	484,302	5.31	%	$	33,700	0.28	%	$	518,002	5.03	%
	Fair Value	$	562,855			$	33,700			$	596,555
As of March 31, 2012:
	2012	$	1,006	6.86	%	$	-	-	%
	2013		31,076	6.93	%		-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	Thereafter		397,031	5.29	%		33,700	0.37	%
	Total	$	461,308	5.38	%	$	33,700	0.37	%	$	495,008	5.07	%
	Fair Value	$	545,959			$	33,700			$	579,659

Long-term Debt Maturities and Fair Value - Central Hudson

(Dollars in Thousands)

		Fixed Rate					Variable Rate				Total Debt Outstanding
Expected Maturity Date		Amount			Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate
As of March 31, 2013:
	2013	$	30,000		6.93	%	$	-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-	1	-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	2017		33,000		6.10	%		-	-	%
	Thereafter		371,250		5.06	%		33,700	0.20	%
	Total	$	456,250		5.22	%	$	33,700	0.20	%	$	489,950	4.92	%
	Fair Value	$	521,706				$	33,700			$	555,406
As of December 31, 2012:
	2013	$	30,000		6.93	%	$	-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-		-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	2017		33,000		6.10	%		-	-	%
	Thereafter		371,250		5.06	%		33,700	0.28	%
	Total	$	456,250		5.22	%	$	33,700	0.28	%	$	489,950	4.93	%
	Fair Value	$	529,710				$	33,700			$	563,410
As of March 31, 2012:
	2012	$	-		-	%	$	-	-	%
	2013		30,000		6.93	%		-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-		-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	Thereafter		380,250		5.22	%		33,700	0.37	%
	Total	$	432,250		5.28	%	$	33,700	0.37	%	$	465,950	4.96	%
	Fair Value	$	507,978				$	33,700			$	541,678

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Equity-Based Compensation

3 Months Ended

Mar. 31, 2013

Equity-Based Compensation [Abstract]

Equity-Based Compensation

NOTE 11 – Equity-Based Compensation

CH Energy Group has adopted the CH Energy Group, Inc. 2011 Long-Term Equity Incentive Plan (the "2011 Plan").  The 2011 Plan reserves for awards to be granted up to a maximum of 400,000 shares of Common Stock plus any shares remaining available under the 2006 Long-Term Equity Incentive Plan (the "2006 Plan") as of April 26, 2011 and any shares that are subject to awards granted under the 2006 Plan that are forfeited, cancelled, surrendered or otherwise terminated without the issuance of shares on or after that date.  Awards may consist of incentive stock options, nonqualified stock options, stock appreciation rights, restricted shares, restricted share units, performance shares, dividend equivalents and other awards that CH Energy Group may authorize. 

The 2011 Plan will continue in effect until February 9, 2021, unless sooner terminated by the Board of Directors.  Termination will not affect grants and awards then outstanding.

In December 2012, the board approved the non-refundable accelerated payment of 80% of earned performance shares for certain executive officers for the February 8, 2010 grant and the acceleration of the vesting of 80% of restricted shares outstanding for certain executive officers issued under the February 10, 2010 grant award.  In accordance with accounting rules, the modification of the restricted share grant is treated as a cancellation of the original award and issue of a new award with the new grant date fair value and incremental expense recognized.  The incremental expense resulting from this modification was not material.

Performance Shares

A summary of the status of outstanding performance shares granted to executives under the 2006 and 2011 Plans are as follows:

Grant Date	Grant Date Fair Value		Performance Shares Granted	Performance Shares Outstanding at March 31, 2013
February 8, 2010	$	38.62	48,740	37,348	(1)
February 7, 2011	$	49.77	40,320	40,320
February 6, 2012	$	58.15	39,440	39,440
February 5, 2013	$	65.02	35,780	35,780

(1) CH Energy Group treasury stock of 613 shares in 2011 and 4,128 in 2012 were issued in satisfaction of the pro-rated payout of an officer who retired in 2011 and the accelerated payment to certain executive officers in 2012, respectively.

The ultimate number of shares earned under the awards is based on metrics established by the Compensation Committee at the beginning of the award cycle.  Participants may elect to defer receipt of shares earned in accordance with terms and subject to conditions of the Directors and Executives Deferred Compensation Plan.  Ultimate payouts from the Directors and Executives Deferred Compensation Plan are made in the form of cash or shares.  Accordingly, these awards are classified as liabilities and are adjusted to fair value as of the end of each reporting period.

Performance shares granted February 8, 2010 and shown as outstanding as of March 31, 2013 in the table above, were paid out in April 2013.  Those recipients electing not to defer this compensation under the CH Energy Group Directors and Executives Deferred Compensation Plan received shares issued from CH Energy Group's treasury stock totaling 11,354 shares.

Restricted Shares and Restricted Stock Units

The following table summarizes information concerning restricted shares and stock units outstanding as of March 31, 2013:

Grant Date	Type of Award	Shares or Stock Units Granted	Grant Date Fair Value		Vesting Terms	Unvested Shares Outstanding at March 31, 2013
October 1, 2009	Shares	14,375	$	43.86	Ratably over 5 years	5,750
November 20, 2009	Stock Units	13,900	$	41.43	1/3 each year in Years 5, 6 and 7	13,900
February 8, 2010	Shares	3,060	$	38.62	End of 3 years	-	(1)
February 10, 2010	Shares	5,200	$	38.89	End of 3 years	-	(2)
November 15, 2010	Shares	3,000	$	46.53	Ratably over 3 years	1,000
February 7, 2011	Shares	1,500	$	49.77	1/3 each year in Years 3, 4 and 5	1,500
February 7, 2011	Shares	2,230	$	49.77	End of 3 years	2,230
February 6, 2012	Shares	2,170	$	58.15	End of 3 years	2,170
February 5, 2013	Shares	2,035	$	65.02	End of 3 years	2,035

(1)	The vesting of 405 shares was accelerated as approved by the Board of Directors.  The remaining 2,655 shares vested on February 8, 2013.
(2)	The vesting of 3,520 shares was accelerated as approved by the Board of Directors.  The remaining 1,680 shares vested on February 8, 2013.

Compensation Expense

The following table summarizes expense for equity-based compensation by award type for the three months ended March 31, 2013 and 2012 (In Thousands):

	CH Energy Group						Central Hudson
	Three Months Ended March 31,						Three Months Ended March 31,
	2013			2012			2013			2012
Performance shares		$	617		$	1,538		$	502		$	525
Restricted shares and stock units		$	105		$	114		$	72		$	65
Recognized tax benefit of restricted shares and stock units		$	41		$	46		$	29		$	26

Compensation expense for performance shares is recognized over the three year performance period based on the fair value of the awards at the end of each reporting period and the time elapsed within each grant's performance period.  The fair value of performance shares is determined based on the shares' current market value at the end of each reporting period, estimated forfeitures for each grant, and expected payout based on management's best estimate including analysis of historical performance in accordance with the defined metrics of each grant.  Compensation expense is recorded as performance shares are earned over the relevant three-year life of the performance share grant prior to its award.  The portion of the compensation expense related to an employee who retires during the performance period is the amount recognized up to the date of retirement.

Compensation expense for restricted shares is recognized over the defined vesting periods based on the grant date fair value of the awards.  As of December 31, 2012, there are no stock options outstanding.  Stock option expense recognized over the three months ended March 31, 2012 was not material.

The market price of CH Energy Group stock increased approximately $8 per share immediately following the February 21, 2012 announcement that CH Energy Group had entered into a merger agreement with Fortis.  CH Energy Group's equity-based compensation expense for the three months ended March 31, 2013 and 2012 included approximately $0.1 million and $1.0 million attributable to the increase in stock price on outstanding performance share awards, which has been recognized at the holding company as a transaction cost resulting from the proposed acquisition of CH Energy Group by Fortis and not allocated to its subsidiaries.

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Short-Term Borrowing Arrangements

3 Months Ended

Mar. 31, 2013

Short-Term Borrowing Arrangements [Abstract]

Short-Term Borrowing Arrangements

NOTE 7 – Short-Term Borrowing Arrangements

CH Energy Group and Central Hudson borrowings under its committed and uncommitted short-term borrowing arrangements are as follows (In Thousands):

	March 31, 2013			December 31, 2012			March 31, 2012
CH Energy Group Holding Company Short-term borrowings	$	29,000		$	19,500		$	32,000
Central Hudson Short-term borrowings		27,000			-			59,000
Intercompany Borrowing		-			-			(20,000	)
Total CH Energy Group	$	56,000		$	19,500		$	71,000
Total CH Energy Group Weighted Average Interest Rate		0.97	%		1.08	%		1.12	%

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Acquisitions, Divestitures and Investments

3 Months Ended

Mar. 31, 2013

Acquisitions, Divestitures and Investments [Abstract]

Acquisitions, Divestitures and Investments

NOTE 5 – Acquisitions and Investments

Acquisitions

During the three months ended March 31, 2013, CH Energy Group or Central Hudson made no acquisitions.

Investments

The value of CHEC's investments as of March 31, 2013 is as follows  (In Thousands):

CHEC Investment	Description	Intercompany Debt		Equity Investment		Total
Griffith Energy Services	100% controlling interest in a fuel distribution business	$	40,000	$	40,682	$	80,682
CH-Community Wind	50% equity interest in a joint venture that owns 18% interest in two operating wind projects		-		-		-
Other	Partnerships and an energy sector venture capital fund		-		2,241		2,241
		$	40,000	$	42,923	$	82,923

The remaining investments identified as CH-Community Wind and Other are not considered a part of the core business; however, management intends to retain these investments at this time.

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Goodwill and Other Intangible Assets

3 Months Ended

Mar. 31, 2013

Goodwill and Other Intangible Assets [Abstract]

Goodwill and Other Intangible Assets

NOTE 6 – Goodwill and Other Intangible Assets

Goodwill, customer relationships, trademarks and covenants not to compete associated with acquisitions are included in intangible assets.  In accordance with current accounting guidance related to goodwill and other intangible assets, goodwill and other intangible assets that have indefinite useful lives are not amortized, but instead are periodically reviewed for impairment.

In the fourth quarter of 2012, management performed a qualitative assessment of any potential impairment of Griffith's goodwill.  The last quantitative analysis of impairment was performed as of September 30, 2010, which reflected that the fair value of Griffith exceeded its carrying value by approximately $34.2 million.  Additionally, management believes that no event has occurred which would trigger impairment since the last quantitative test performed.  Based on these factors and other factors considered in its qualitative analysis, management believes that it is more likely than not that the fair market value of Griffith is more than the carrying value and, therefore, the first and second steps of the impairment test prescribed in guidance were not necessary.

The components of amortizable intangible assets of CH Energy Group are summarized as follows (In Thousands):

	March 31, 2013				December 31, 2012				March 31, 2012
	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
Customer relationships	$	37,709	$	26,645	$	37,709	$	26,017	$	36,526	$	24,188
Trademarks		318		8		318		-		-		-
Covenants not to compete		411		122		411		97		377		151
Total Amortizable Intangibles	$	38,438	$	26,775	$	38,438	$	26,114	$	36,903	$	24,339

	Three Months Ended March 31,
	2013		2012
Intangibles Amortization Expense (In Thousands)	$	661	$	634

The estimated annual amortization expense for the remainder of the current year and for each of the next four years, assuming no new acquisitions or divestitures, is as follows (In Thousands):

	2013		2014		2015		2016		2017
Estimated Amortization Expense	$	1,984	$	2,636	$	2,374	$	988	$	683

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Capitalization Common and Preferred Stock

3 Months Ended

Mar. 31, 2013

Capitalization - Common and Preferred Stock [Abstract]

Capitalization - Common and Preferred Stock

NOTE 8 – Capitalization – Common and Preferred Stock

For a schedule of activity related to common stock, paid-in capital and capital stock, see the Consolidated Statement of Equity for CH Energy Group and Central Hudson.

Effective July 31, 2007, the Board of Directors of CH Energy Group extended and amended the Common Stock Repurchase Program of the Company (the "Repurchase Program"), which was authorized in 2002.  As amended, the Repurchase Program authorized the repurchase of up to 2 million shares (excluding shares purchased before July 31, 2007) or approximately 13% of the CH Energy Group's outstanding Common Stock, from time to time, through July 31, 2012.  In accordance with the merger agreement with Fortis, which prohibited CH Energy Group from repurchasing additional shares subsequent to February 21, 2012, the Repurchase Program was not renewed.  As of December 31, 2012, CH Energy Group had purchased 948,676 shares under the Repurchase Program, which were not retired or cancelled, and the repurchases accordingly have been presented as an increase to treasury stock in CH Energy Group's Consolidated Balance Sheet.

Effective July 1, 2011, employer matching contributions to an eligible employee's Savings Incentive Plan ("SIP") account could be paid in either cash or in CH Energy Group Common Stock, and CH Energy Group initially chose to meet its matching obligation in Common Stock.  Since March 1, 2012, the Company has been contributing cash for all of its matching obligations, except for matching contributions associated with classified employees of Central Hudson.  The classified employees will continue to receive matching contributions in CH Energy Group Common Stock.  As of March 31, 2013, 44,786 shares had been issued from treasury related to employer matching contributions, of which 3,425 shares were issued in 2013.

On March 21, 2013, Central Hudson redeemed its two outstanding series of preferred stock.  Registered holders of 4 1/2% Cumulative Preferred Stock received $107.00 per share plus accrued and unpaid dividends to the redemption date in the amount of $1.00 per share, for a total redemption price of $108.00 per share.  Registered holders of 4.75% Cumulative Preferred Stock received $106.75 per share plus accrued and unpaid dividends to the redemption date in the amount of $1.056 per share, for a total redemption price of $107.806 per share.  The premium paid in connection with the redemption of the preferred stock was recorded as a reduction of Retained Earnings on Central Hudson's Balance Sheet and as Premium on Preferred Stock Redemption on Central Hudson's Income Statement.

Through March 31, 2013, Central Hudson made $5.0 million of dividend payments in 2013 to parent CH Energy Group.  In the prior year, Central Hudson made no dividend payments to parent CH Energy Group in the three months ended March 31, 2012.

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Equity-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2013

Equity-Based Compensation [Abstract]

Performance Shares Granted to Executives Under the 2006 and 2011 Plans

A summary of the status of outstanding performance shares granted to executives under the 2006 and 2011 Plans are as follows:

Grant Date	Grant Date Fair Value		Performance Shares Granted	Performance Shares Outstanding at March 31, 2013
February 8, 2010	$	38.62	48,740	37,348	(1)
February 7, 2011	$	49.77	40,320	40,320
February 6, 2012	$	58.15	39,440	39,440
February 5, 2013	$	65.02	35,780	35,780

(1) CH Energy Group treasury stock of 613 shares in 2011 and 4,128 in 2012 were issued in satisfaction of the pro-rated payout of an officer who retired in 2011 and the accelerated payment to certain executive officers in 2012, respectively.

Restricted Shares and Stock Units Outstanding

The following table summarizes information concerning restricted shares and stock units outstanding as of March 31, 2013:

Grant Date	Type of Award	Shares or Stock Units Granted	Grant Date Fair Value		Vesting Terms	Unvested Shares Outstanding at March 31, 2013
October 1, 2009	Shares	14,375	$	43.86	Ratably over 5 years	5,750
November 20, 2009	Stock Units	13,900	$	41.43	1/3 each year in Years 5, 6 and 7	13,900
February 8, 2010	Shares	3,060	$	38.62	End of 3 years	-	(1)
February 10, 2010	Shares	5,200	$	38.89	End of 3 years	-	(2)
November 15, 2010	Shares	3,000	$	46.53	Ratably over 3 years	1,000
February 7, 2011	Shares	1,500	$	49.77	1/3 each year in Years 3, 4 and 5	1,500
February 7, 2011	Shares	2,230	$	49.77	End of 3 years	2,230
February 6, 2012	Shares	2,170	$	58.15	End of 3 years	2,170
February 5, 2013	Shares	2,035	$	65.02	End of 3 years	2,035

(1)	The vesting of 405 shares was accelerated as approved by the Board of Directors.  The remaining 2,655 shares vested on February 8, 2013.
(2)	The vesting of 3,520 shares was accelerated as approved by the Board of Directors.  The remaining 1,680 shares vested on February 8, 2013.

Expense For Equity-Based Compensation

The following table summarizes expense for equity-based compensation by award type for the three months ended March 31, 2013 and 2012 (In Thousands):

	CH Energy Group						Central Hudson
	Three Months Ended March 31,						Three Months Ended March 31,
	2013			2012			2013			2012
Performance shares		$	617		$	1,538		$	502		$	525
Restricted shares and stock units		$	105		$	114		$	72		$	65
Recognized tax benefit of restricted shares and stock units		$	41		$	46		$	29		$	26

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Segments and Related Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013		Mar. 31, 2012		Dec. 31, 2012
Segment Reporting Information [Line Items]
Revenues from external customers	$ 298,374		$ 274,072
Intersegment revenues	0		0
Total Operating Revenues	298,374		274,072
Operating income (loss)	36,421		32,213
Interest and investment income	1,385		1,719
Interest charges	8,345		7,802
Income (Loss) before income taxes	30,111		26,492
Net Income (Loss) Attributable to CH Energy Group	18,090		14,581
Segment assets	1,802,391		1,785,801		1,784,949
Central Hudson Electric [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	138,163		129,272
Intersegment revenues	2		3
Total Operating Revenues	138,165		129,275
Operating income (loss)	16,967		20,125
Interest and investment income	1,182		1,436
Interest charges	6,166		5,716
Income (Loss) before income taxes	12,306		16,224
Net Income (Loss) Attributable to CH Energy Group	7,263		10,278
Segment assets	1,296,078		1,284,078
Central Hudson Natural Gas [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	56,300		55,850
Intersegment revenues	116		90
Total Operating Revenues	56,416		55,940
Operating income (loss)	12,191		12,479
Interest and investment income	191		270
Interest charges	1,635		1,539
Income (Loss) before income taxes	10,847		11,262
Net Income (Loss) Attributable to CH Energy Group	6,250		6,213
Segment assets	370,390		377,524
Griffith [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	103,911		88,950
Intersegment revenues	0		0
Total Operating Revenues	103,911		88,950
Operating income (loss)	7,791		4,947
Interest and investment income	0		0
Interest charges	644		696
Income (Loss) before income taxes	7,233		4,268
Net Income (Loss) Attributable to CH Energy Group	4,268		2,518
Segment assets	122,695		109,457
Other Businesses and Investments [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	0		0
Intersegment revenues	0		0
Total Operating Revenues	0		0
Operating income (loss)	(528)		(5,338)
Interest and investment income	656		697
Interest charges	544		535
Income (Loss) before income taxes	(275)		(5,262)
Net Income (Loss) Attributable to CH Energy Group	309		(4,428)
Segment assets	13,928		16,417
Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	0		0
Intersegment revenues	(118)		(93)
Total Operating Revenues	(118)		(93)
Operating income (loss)	0		0
Interest and investment income	(644)	[1]	(684)	[1]
Interest charges	(644)	[1]	(684)	[1]
Income (Loss) before income taxes	0		0
Net Income (Loss) Attributable to CH Energy Group	0		0
Segment assets	$ (700)		$ (1,675)

[1] This represents the elimination of inter-company interest income (expense) generated from lending activities between CH Energy Group (the holding company), and its subsidiaries (CHEC and Griffith).

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Segments and Related Information

3 Months Ended

Mar. 31, 2013

Segments and Related Information [Abstract]

Segments and Related Information

NOTE 13 – Segments and Related Information

CH Energy Group's reportable operating segments are the regulated electric utility business and regulated natural gas utility business of Central Hudson and the unregulated fuel distribution business of Griffith.  Other activities of CH Energy Group, which do not constitute a business segment, include CHEC's renewable energy investments and the holding company's activities, which consist primarily of financing its subsidiaries, and are reported under the heading "Other Businesses and Investments."

Certain additional information regarding these segments is set forth in the following tables.  General corporate expenses and Central Hudson's property common to both electric and natural gas segments have been allocated in accordance with practices established for regulatory purposes.

Central Hudson's and Griffith's operations are seasonal in nature and weather-sensitive and, as a result, financial results for interim periods are not necessarily indicative of trends for a twelve-month period.  Demand for electricity typically peaks during the summer, while demand for natural gas and heating oil typically peaks during the winter.

CH Energy Group Segment Disclosure

(In Thousands)

	Three Months Ended March 31, 2013
	Segments						Other
	Central Hudson						Businesses
			Natural				and
	Electric		Gas		Griffith		Investments			Eliminations			Total
Revenues from external customers	$	138,163	$	56,300	$	103,911	$	-		$	-		$	298,374
Intersegment revenues		2		116		-		-			(118	)		-
Total revenues		138,165		56,416		103,911		-			(118	)		298,374
Operating income (loss)		16,967		12,191		7,791		(528	)		-			36,421
Interest and investment income		1,182		191		-		656			(644	)(1)		1,385
Interest charges		6,166		1,635		644		544			(644	)(1)		8,345
Income (Loss) before income taxes		12,306		10,847		7,233		(275	)		-			30,111
Net Income Attributable to CH Energy Group		7,263		6,250		4,268		309			-			18,090
Segment assets at March 31		1,296,078		370,390		122,695		13,928			(700	)		1,802,391

(1) This represents the elimination of inter-company interest income (expense) generated from lending activities between CH Energy Group (the holding company), and its subsidiaries (CHEC and Griffith).

CH Energy Group Segment Disclosure

(In Thousands)

	Three Months Ended March 31, 2012
	Segments						Other
	Central Hudson						Businesses
			Natural				and
	Electric		Gas		Griffith		Investments			Eliminations			Total
Revenues from external customers	$	129,272	$	55,850	$	88,950	$	-		$	-		$	274,072
Intersegment revenues		3		90		-		-			(93	)		-
Total revenues		129,275		55,940		88,950		-			(93	)		274,072
Operating income (loss)		20,125		12,479		4,947		(5,338	)		-			32,213
Interest and investment income		1,436		270		-		697			(684	)(1)		1,719
Interest charges		5,716		1,539		696		535			(684	)(1)		7,802
Income (Loss) before income taxes		16,224		11,262		4,268		(5,262	)		-			26,492
Net Income (Loss) Attributable to CH Energy Group		10,278		6,213		2,518		(4,428	)		-			14,581
Segment assets at March 31		1,284,078		377,524		109,457		16,417			(1,675	)		1,785,801

(1) This represents the elimination of inter-company interest income (expense) generated from lending activities between CH Energy Group (the holding company), and its subsidiaries (CHEC and Griffith).

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2013

Summary of Significant Accounting Policies [Abstract]

Fuel, Material and Supplies

The following is a summary of CH Energy Group's and Central Hudson's inventories (In Thousands):

	CH Energy Group						Central Hudson
	March 31,		December 31,		March 31,		March 31,		December 31,		March 31,
	2013		2012		2012		2013		2012		2012
Natural gas	$	2,759	$	7,638	$	7,322	$	2,759	$	7,638	$	7,322
Petroleum products and propane		2,098		3,942		2,115		-		-		-
Fuel used in electric generation		293		295		286		293		295		286
Materials and supplies		12,504		12,621		9,966		11,142		11,331		8,781
Total	$	17,654	$	24,496	$	19,689	$	14,194	$	19,264	$	16,389

Average Dilutive Effect of Stock Options, Performance Shares and Restricted Shares

The average dilutive effect of CH Energy Group's stock options, performance shares and restricted shares are as follows:

	Three Months Ended
	March 31,
	2013		2012
Shares		213,908		260,259

Parental Guarantees

	March 31, 2013
Transaction Description	Maximum Potential Payments		Outstanding Liabilities(1)
Heating oil, propane, other petroleum products, weather and commodity hedges (In Thousands)	$	30,650	$	8,555

(1) Balance included in CH Energy Group's Consolidated Balance Sheet.

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Equity-Based Compensation (Details) (USD $)	3 Months Ended				1 Months Ended	3 Months Ended		12 Months Ended						3 Months Ended			3 Months Ended			3 Months Ended			1 Months Ended	3 Months Ended		3 Months Ended							3 Months Ended							1 Months Ended	3 Months Ended		3 Months Ended			3 Months Ended			3 Months Ended			3 Months Ended		1 Months Ended	3 Months Ended		3 Months Ended			3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013 Performance Shares [Member]	Mar. 31, 2012 Performance Shares [Member]	Apr. 30, 2013 Performance Shares [Member] Grant Date 2/8/10 [Member]	Mar. 31, 2010 Performance Shares [Member] Grant Date 2/8/10 [Member]		Dec. 31, 2012 Performance Shares [Member] Grant Date 2/8/10 [Member]	Dec. 31, 2011 Performance Shares [Member] Grant Date 2/8/10 [Member]	Mar. 31, 2013 Performance Shares [Member] Grant Date 2/8/10 [Member]		Feb. 08, 2010 Performance Shares [Member] Grant Date 2/8/10 [Member]		Mar. 31, 2011 Performance Shares [Member] Grant Date 2/7/11 [Member]	Mar. 31, 2013 Performance Shares [Member] Grant Date 2/7/11 [Member]	Feb. 07, 2011 Performance Shares [Member] Grant Date 2/7/11 [Member]	Mar. 31, 2012 Performance Shares [Member] Grant Date 2/6/12 [Member]	Mar. 31, 2013 Performance Shares [Member] Grant Date 2/6/12 [Member]	Feb. 06, 2012 Performance Shares [Member] Grant Date 2/6/12 [Member]	Mar. 31, 2013 Performance Shares [Member] Grant Date 2/5/13 [Member]	Feb. 05, 2013 Performance Shares [Member] Grant Date 2/5/13 [Member]	Dec. 31, 2012 Restricted Shares [Member] Grant Date 2/8/10 [Member]	Oct. 31, 2009 Restricted Shares [Member] Grant Date 10/1/09 [Member]	Mar. 31, 2013 Restricted Shares [Member] Grant Date 10/1/09 [Member]	Sep. 30, 2009 Restricted Shares [Member] Grant Date 10/1/09 [Member]	Mar. 31, 2013 Restricted Shares [Member] Grant Date 2/8/10 [Member]		Mar. 31, 2010 Restricted Shares [Member] Grant Date 2/8/10 [Member]		Feb. 08, 2013 Restricted Shares [Member] Grant Date 2/8/10 [Member]	Feb. 08, 2010 Restricted Shares [Member] Grant Date 2/8/10 [Member]		Mar. 31, 2013 Restricted Shares [Member] Grant Date 2/10/10 [Member]		Mar. 31, 2010 Restricted Shares [Member] Grant Date 2/10/10 [Member]		Feb. 08, 2013 Restricted Shares [Member] Grant Date 2/10/10 [Member]	Feb. 10, 2010 Restricted Shares [Member] Grant Date 2/10/10 [Member]		Nov. 30, 2010 Restricted Shares [Member] Grant Date 11/15/10 [Member]	Mar. 31, 2013 Restricted Shares [Member] Grant Date 11/15/10 [Member]	Nov. 15, 2010 Restricted Shares [Member] Grant Date 11/15/10 [Member]	Mar. 31, 2013 Restricted Shares [Member] Grant Date 2/7/11 [Member]	Mar. 31, 2011 Restricted Shares [Member] Grant Date 2/7/11 [Member]	Feb. 07, 2011 Restricted Shares [Member] Grant Date 2/7/11 [Member]	Mar. 31, 2013 Restricted Shares [Member] Grant Date 2/7/11 [Member]	Mar. 31, 2011 Restricted Shares [Member] Grant Date 2/7/11 [Member]	Feb. 07, 2011 Restricted Shares [Member] Grant Date 2/7/11 [Member]	Mar. 31, 2013 Restricted Shares [Member] Grant Date 2/6/12 [Member]	Mar. 31, 2012 Restricted Shares [Member] Grant Date 2/6/12 [Member]	Feb. 06, 2012 Restricted Shares [Member] Grant Date 2/6/12 [Member]	Mar. 31, 2013 Restricted Shares [Member] Grant Date 2/5/13 [Member]	Feb. 05, 2013 Restricted Shares [Member] Grant Date 2/5/13 [Member]	Nov. 30, 2009 Restricted Stock Units [Member] Grant Date 11/20/09 [Member]	Mar. 31, 2013 Restricted Stock Units [Member] Grant Date 11/20/09 [Member]	Nov. 20, 2009 Restricted Stock Units [Member] Grant Date 11/20/09 [Member]	Mar. 31, 2013 Restricted Shares and Stock Units [Member]	Mar. 31, 2012 Restricted Shares and Stock Units [Member]	Mar. 31, 2013 2011 Long-Term Equity Incentive Plan [Member]	Mar. 31, 2013 Central Hudson [Member]	Mar. 31, 2012 Central Hudson [Member]	Mar. 31, 2013 Central Hudson [Member] Performance Shares [Member]	Mar. 31, 2012 Central Hudson [Member] Performance Shares [Member]	Mar. 31, 2013 Central Hudson [Member] Restricted Shares and Stock Units [Member]	Mar. 31, 2012 Central Hudson [Member] Restricted Shares and Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of shares authorized for grant (in shares)																																																											400,000
Accelerated percentage of earned performance shares and vesting of shares (in hundredths)																						80.00%
Summary of outstanding shares [Abstract]
Grant date												Feb. 08, 2010	[1]			Feb. 07, 2011			Feb. 06, 2012		Feb. 05, 2013				Oct. 01, 2009						Feb. 08, 2010	[2]						Feb. 10, 2010	[3]			Nov. 15, 2010			Feb. 07, 2011			Feb. 07, 2011			Feb. 06, 2012		Feb. 05, 2013			Nov. 20, 2009
Grant date fair value (in dollars per share)												$ 38.62	[1]			$ 49.77			$ 58.15		$ 65.02				$ 43.86						$ 38.62	[2]						$ 38.89	[3]			$ 46.53			$ 49.77			$ 49.77			$ 58.15		$ 65.02			$ 41.43
Number granted (in shares)						48,740	[1]							40,320			39,440			35,780			14,375					3,060	[2]						5,200	[3]				3,000				1,500			2,230			2,170		2,035		13,900
Vesting terms																								Ratably over 5 years		End of 3 years	[2]						End of 3 years	[3]							Ratably over 3 years		1/3 each year in Years 3, 4 and 5			End of 3 years			End of 3 years			End of 3 years			1/3 each year in Years 5, 6 and 7
Shares outstanding (in shares)										37,348	[1]				40,320			39,440		35,780				5,750		0	[2]						0	[3]							1,000		1,500			2,230			2,170			2,035			13,900
Pro-rata payout (in shares)									613
Accelerated vesting as approved by the Board of Directors (in shares)								4,128																		405							3,520
Participant awards settled (in shares)					11,354
Shares not subject to accelerated vesting (in shares)																														2,655							1,680
Expense for equity-based compensation [Abstract]
Expense for equity-based compensation			$ 617,000	$ 1,538,000																																																					$ 105,000	$ 114,000				$ 502,000	$ 525,000	$ 72,000	$ 65,000
Recognized tax benefit of restricted shares and stock units	41,000	46,000																																																										29,000	26,000
Performance period (in years)	3 years
Increase in stock price per share (in dollars per share)		$ 8
Increase in equity-based compensation expense			$ 100,000	$ 1,000,000

[1] CH Energy Group treasury stock of 613 shares in 2011 and 4,128 in 2012 were issued in satisfaction of the pro-rated payout of an officer who retired in 2011 and the accelerated payment to certain executive officers in 2012, respectively.

[2] The vesting of 405 shares was accelerated as approved by the Board of Directors. The remaining 2,655 chares vested on February 8, 2013.

[3] The vesting of 3,520 shares was accelerated as approved by the Board of Directors. The remaining 1,680 shares vested on February 8, 2013.

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New Accounting Guidance (Details)	3 Months Ended
	Mar. 31, 2013
ASU No. 2011-11 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Category	Balance Sheet (Topic 210)
Title	Disclosures about Offsetting Assets and Liabilities
Issued Date	2011-12-01
Effective Date	2013-01-01
Impact	No current impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries when adopted on the effective date noted. Additional disclosures have been added or presentation of information modified where required.
ASU No. 2013-01 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Category	Balance Sheet (Topic 210)
Title	Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities
Issued Date	2013-01-01
Effective Date	2013-01-01
Impact	No current impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries when adopted on the effective date noted. Additional disclosures have been added or presentation of information modified where required.
ASU No. 2013-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Category	Comprehensive Income (Topic 220)
Title	Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income
Issued Date	2013-02-01
Effective Date	2012-12-01
Impact	No current impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries when adopted on the effective date noted. Additional disclosures have been added or presentation of information modified where required.
ASU No. 2013-04 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Category	Liabilities (Topic 405)
Title	Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date
Issued Date	2013-02-01
Effective Date	2013-12-01
Impact	No anticipated impact on the financial condition, results of operations and cash flows of CH Energy Group and its subsidiaries upon future adoption

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CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Operating Activities:
Net income	$ 18,946	$ 14,823
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation	9,940	9,499
Amortization	1,247	1,125
Deferred income taxes - net	3,156	11,598
Bad debt expense	964	2,500
Undistributed equity in earnings of unconsolidated affiliates	(199)	(52)
Pension expense	6,022	7,233
Other post-employment benefits (OPEB) expense	1,989	1,996
Regulatory liability - rate moderation	0	(1,033)
Revenue decoupling mechanism recorded	4,203	(950)
Regulatory asset amortization	1,682	1,722
Regulatory asset storm deferral adjustment	4,000	0
Gain on sale of assets	(22)	(79)
Changes in operating assets and liabilities - net of business acquisitions:
Accounts receivable, unbilled revenues and other receivables	(28,872)	(7,932)
Fuel, materials and supplies	6,842	5,425
Special deposits and prepayments	(5,100)	(4,407)
Income and other taxes	5,657	17
Accounts payable	(3,369)	(2,144)
Accrued interest	2,944	997
Customer advances	(12,587)	(5,212)
Pension plan contribution	(26,165)	(28,165)
Revenue decoupling mechanism collected (refunded)	1,485	(1,310)
Regulatory asset - storm deferral	(2,813)	(3,042)
Regulatory asset - manufactured gas plant (MGP) site remediation	(2,214)	951
Regulatory asset - Temporary State Assessment	(2,526)	(3,332)
Deferred natural gas and electric costs	(4,376)	7,883
Other - net	14,231	4,500
Net cash (used in) provided by operating activities	(4,935)	12,611
Investing Activities:
Proceeds from sale of assets	26	96
Additions to utility and other property and plant	(28,478)	(25,887)
Other - net	38	(637)
Net cash used in investing activities	(28,414)	(26,428)
Financing Activities:
Redemption of long-term debt	0	(36,000)
Proceeds from issuance of long-term debt	0	48,000
Borrowings of short-term debt - net	36,500	64,500
Dividends paid on Common Stock	(8,301)	(8,269)
Redemption of Preferred Stock	(9,625)	0
Dividends paid on Preferred Stock of subsidiary	(92)	(242)
Shares repurchased	0	(2,993)
Other - net	(95)	(593)
Net cash provided by financing activities	18,387	64,403
Net Change in Cash and Cash Equivalents	(14,962)	50,586
Cash and Cash Equivalents at Beginning of Period	30,508	15,281
Cash and Cash Equivalents at End of Period	15,546	65,867
Supplemental Disclosure of Cash Flow Information:
Interest paid	3,667	5,351
Federal and state income taxes paid	0	16
Additions to plant included in liabilities	3,783	4,126
Central Hudson Gas & Electric Corporation [Member]
Operating Activities:
Net income	14,369	16,733
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation	9,369	8,977
Amortization	586	491
Deferred income taxes - net	3,466	12,071
Bad debt expense	589	2,125
Pension expense	6,022	7,233
Other post-employment benefits (OPEB) expense	1,989	1,996
Regulatory liability - rate moderation	0	(1,033)
Revenue decoupling mechanism recorded	4,203	(950)
Regulatory asset amortization	1,682	1,722
Regulatory asset storm deferral adjustment	4,000	0
Changes in operating assets and liabilities - net of business acquisitions:
Accounts receivable, unbilled revenues and other receivables	(17,846)	(7,437)
Fuel, materials and supplies	5,069	4,648
Special deposits and prepayments	(3,926)	(3,203)
Income and other taxes	5,492	(942)
Accounts payable	(5,075)	(2,855)
Accrued interest	2,466	504
Customer advances	(7,841)	(3,374)
Pension plan contribution	(26,165)	(28,165)
Revenue decoupling mechanism collected (refunded)	1,485	(1,310)
Regulatory asset - storm deferral	(2,813)	(3,042)
Regulatory asset - manufactured gas plant (MGP) site remediation	(2,214)	951
Regulatory asset - Temporary State Assessment	(2,526)	(3,332)
Deferred natural gas and electric costs	(4,376)	7,883
Other - net	10,909	1,478
Net cash (used in) provided by operating activities	(1,086)	11,169
Investing Activities:
Additions to utility and other property and plant	(27,890)	(25,783)
Other - net	(408)	(777)
Net cash used in investing activities	(28,298)	(26,560)
Financing Activities:
Redemption of long-term debt	0	(36,000)
Proceeds from issuance of long-term debt	0	48,000
Borrowings of short-term debt - net	27,000	57,500
Redemption of Preferred Stock	(9,653)	0
Dividends paid to parent - CH Energy Group	(5,000)	0
Dividends paid on Preferred Stock of subsidiary	(92)	(242)
Other - net	(108)	(602)
Net cash provided by financing activities	12,147	68,656
Net Change in Cash and Cash Equivalents	(17,237)	53,265
Cash and Cash Equivalents at Beginning of Period	24,352	2,521
Cash and Cash Equivalents at End of Period	7,115	55,786
Supplemental Disclosure of Cash Flow Information:
Interest paid	3,601	5,312
Federal and state income taxes paid	0	0
Additions to plant included in liabilities	$ 3,783	$ 4,126

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Regulatory Matters

3 Months Ended

Mar. 31, 2013

Regulatory Matters [Abstract]

Regulatory Matters

NOTE 2 – Regulatory Matters

Summary of Regulatory Assets and Liabilities

The following table sets forth Central Hudson's regulatory assets and liabilities (In Thousands):

	March 31,		December 31,		March 31,
	2013		2012		2012
Regulatory Assets (Debits):
Current:
Deferred purchased electric and natural gas costs (Note 1)	$	15,743	$	11,367	$	2,892
Deferred unrealized losses on derivatives (Note 14)		517		1,259		22,118
PSC General and Temporary State Assessment and carrying charges		8,854		6,260		11,547
RDM and carrying charges		-		3,393		3,068
Residual natural gas deferred balances		4,554		4,554		4,554
Deferred debt expense on re-acquired debt		601		601		628
Deferred and accrued costs - MGP site remediation and carrying charges (Note 12)		4,605		4,605		4,586
Other		291		290		290
		35,165		32,329		49,683
Long-term:
Deferred pension costs (Note 10)		140,349		146,935		151,737
Deferred unrealized losses on derivatives (Note 14)		93		218		1,688
Carrying charges - pension reserve		10,303		9,182		6,158
Deferred and accrued costs - MGP site remediation and carrying charges (Note 12)		10,109		10,739		13,459
Deferred debt expense on re-acquired debt		4,586		4,737		5,172
Deferred Medicare Subsidy taxes		7,933		7,808		7,450
Residual natural gas deferred balances and carrying charges		3,809		5,443		8,168
Income taxes recoverable through future rates		37,119		29,908		47,820
Energy efficiency incentives		2,719		2,719		2,719
Deferred storm costs and carrying charges		19,717		23,274		15,178
Other		13,322		15,751		11,747
		250,059		256,714		271,296
Total Regulatory Assets	$	285,224	$	289,043	$	320,979
Regulatory Liabilities (Credits):
Current:
Excess electric depreciation reserve	$	-	$	-	$	74
RDM and carrying charges		2,330		-		-
Deferred unrealized gains on derivatives (Note 14)		2,941		95		-
Income taxes refundable through future rates		4,431		4,669		5,120
Deferred unbilled gas revenues		4,866		5,972		3,765
		14,568		10,736		8,959
Long-term:
Customer benefit fund		2,419		2,390		2,566
Deferred cost of removal (Note 1)		44,795		43,392		42,748
Rate Base impact of tax repair project and carrying charges		9,159		9,099		8,083
Excess electric depreciation reserve carrying charges		1,586		1,586		2,688
Deferred unrealized gains on derivatives (Note 14)		2,881		693		-
Income taxes refundable through future rates		24,194		21,062		33,769
Deferred OPEB costs		9,696		7,975		8,974
Carrying charges - OPEB reserve		11,222		9,949		6,482
Other		12,448		9,314		5,199
		118,400		105,460		110,509
Total Regulatory Liabilities	$	132,968	$	116,196	$	119,468
Net Regulatory Assets	$	152,256	$	172,847	$	201,511

2010 Rate Order

From July 1, 2010 through June 30, 2013, Central Hudson is operating under the terms of the 2010 Rate Order, which provides for the following:

Description	2010 Rate Order
Electric delivery revenue increases	$11.8 million(1) 7/1/10 $9.3 million(1)  7/1/11 $9.1 million 7/1/12
Natural gas delivery revenue increases	$5.7 million 7/1/10 $2.4 million 7/1/11 $1.6 million 7/1/12
ROE	10.0%
Earnings sharing	Yes(2)
Capital structure – common equity	48%
Targets with true-up provisions - % of revenue requirement to defer for shortfalls
Net plant balances	100%
Transmission and distribution ROW maintenance	100%
RDMs – electric and natural gas(3)	Yes
New deferral accounting for full recovery
Fixed debt costs	Yes(4)
Transmission sag mitigation	Yes
New York State Temporary Assessment	Yes
Material regulatory actions(5)	Yes(5)
Property taxes – Deferral for 90% of excess/deficiency relative to revenue requirement	Yes(6)

(1) Moderated by $12 million and $4 million bill credits, respectively.

(2) ROE > 10.5%, 50% to customers, > 11.0%, 80% to customers, > 11.5%, 90% to customers.

(3) Electric is based on revenue dollars; gas is based on usage per customer.

(4) Deferral authorization in RY2 and RY3 only.

(5) Legislative, governmental or regulatory actions with individual impacts greater than or equal to 2% of net income of the applicable department.

(6) The Company's pre-tax gain or loss limited to $0.7 million per rate year.

Other PSC Proceedings

On April 20, 2012, CH Energy Group, Central Hudson, Fortis, FortisUS, and Cascade Acquisition Sub Inc., submitted a joint petition to the PSC for approval of the acquisition of CH Energy Group by Fortis and related transactions.  The petition describes how the acquisition of Central Hudson by Fortis will produce benefits for constituencies that include customers, employees and communities in Central Hudson's service territory as well as positive public benefits.  The petition categorizes the public benefits into three major areas: 1) FortisUS' commitments and intention to preserve and build on the existing strength of Central Hudson, 2) mitigation of any potential negative aspects of the merger consistent with the PSC's disposition of specific issues that have arisen in prior utility merger proceedings in New York State and 3) identifiable monetary benefits resulting from assignment of costs to shareholders and cost savings made possible by the merger.  The petition includes proposals and commitments that effectively mitigate any potential risks to Central Hudson's customers from foreign holding company ownership and excess rate risk.  On January 25, 2013, a Joint Proposal with the Company, Fortis, PSC Staff, Multiple Intervenors, the Department of State Utility Intervention Unit, and Dutchess, Orange and Ulster counties as signatories, was submitted to the PSC.  The signatory parties have concluded that, based on the terms of the Joint Proposal, the acquisition is in the public interest pursuant to the New York State Public Service Law, Section 70, and recommended approval by the Commission.  On May 3, 2013 the Recommended Decision of the two Administrative Law Judges – an advisory document – was issued by the PSC.  The RD states that, in its current form, the Joint Proposal does not meet the public interest test as required by New York State Public Service Law, Section 70, but also states that the ALJs recommend the Commission consider adopting the Joint Proposal subject to modifications that would alter the transaction's balance of risks and benefits.  Briefs on exceptions to the RD are due May 17, 2013 and briefs opposing exceptions are due on May 24, 2013.  While no assurance regarding the closing can be given until a PSC Order is issued by the Commission, a decision from the PSC regarding the Joint Proposal and a subsequent closing is expected in the second quarter of 2013.See Item 7 - "Management's Discussion and Analysis of Financial Condition and Results of Operations" under the caption "Regulatory Matters – PSC Proceedings" for further discussion regarding the terms of the Joint Proposal and schedule.

On October 29, 2012, Central Hudson's service territory was impacted by Superstorm Sandy, and approximately 103,000 electric customers were affected.  The Sandy storm costs were included in the estimate of $22 million storm costs identified in the $35 million of regulatory liabilities to be funded by Fortis. Consistent with the Joint Proposal, on February 6, 2013, Central Hudson filed a petition with the PSC seeking expedited Commission approval to recover $9.7 million of incremental electric storm restoration expense, with carrying charges. These storm costs represent the amount Central Hudson deferred on its books as of December 31, 2012 based on actual costs incurred, bills received and an estimate for bills outstanding and are above the respective rate allowance during the twelve months ended June 30, 2013, which is the third rate year established by the PSC in its approval of a Joint Proposal in Case 09-E-0588. The Company believes the incremental costs associated with this storm meet the PSC's criteria for deferral: 1) the amount is incremental to the amount in rates; 2) the incremental amount is material and extraordinary in nature and 3) the utility's earnings are below the authorized rate of return on common equity.  As of March 31, 2013, the deferred balance related to this storm event was $9.8 million.

On October 29, 2011, Central Hudson experienced an unusual fall storm with snow accumulations of up to 20 inches in the service territory, resulting in electric service outages to over 150,000 customers, extensive damage to the electric system and significant restoration costs.  Following Tropical Storm Irene, the October snowstorm represented the second extraordinary storm event that occurred within the rate year.  Central Hudson filed a petition with the PSC to defer for future recovery with carrying charges the $8.6 million of total incremental electric storm restoration expense.  However, because the petition requested the PSC to deviate from its prior precedents, the Company was aware that the amount the PSC granted could have been lower.  Accordingly, management deferred only the portion of the incremental costs that strictly follows Commission practice used in the Company's previous requests to defer incremental storm costs.  Approximately $3.7 million and $3.3 million of incremental restoration expense associated with this storm was expensed in 2011 and 2012, respectively, so that the return on common equity for the twelve months ending June 30, 2012 did not exceed the authorized rate of return of 10%.

In late August 2011, Central Hudson's service territory was affected by Tropical Storm Irene, disrupting service to approximately 180,000 customers.  On November 28, 2011 Central Hudson filed a petition with the PSC seeking to defer for future recovery with carrying charges for the estimated $11.4 million of incremental electric storm restoration expense above the respective rate allowance during the twelve months ended June 30, 2012.  The Company believes the incremental costs associated with this storm meet the PSC's criteria for deferral.

On April 22, 2013, the Commission issued Orders approving deferral of $8.9 million and denying deferral of $3.7 million of the incremental electric storm restoration expense related to Tropical Storm Irene and the October snowstorm.  Regarding the majority of the disallowed costs, the PSC's decision stated that the Company did not meet the third prong requirement which requires the Company not be in an over earnings position.  The Commission adopted a staff recommendation to exclude ratemaking normalization adjustments for purposes of calculating authorized electric regulatory earnings, and therefore denied a portion of these petitioned deferrals based on this third prong criterion.  In addition, the PSC's Order stated that approximately $0.6 million of the costs related to Tropical Storm Irene should have been allocated to a separate storm, Tropical Storm Lee, and that this separate amount did not meet the materiality threshold for recovery.  Central Hudson expects to file a petition for reconsideration and rehearing on the PSC's April 22, 2013 Orders challenging the exclusion of the Company's normalization adjustments used to measure earnings.  The petition will seek rehearing for reconsideration and recovery of $3.7 million of costs denied by the Commission for deferral accounting treatment.  The Company believes that it is entitled to fully recover all of these incremental electric storm restoration expenses; however Central Hudson cannot predict the final outcome of this proceeding.

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Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2013

Regulatory Matters [Abstract]

Regulatory Assets and Liabilities

The following table sets forth Central Hudson's regulatory assets and liabilities (In Thousands):

	March 31,		December 31,		March 31,
	2013		2012		2012
Regulatory Assets (Debits):
Current:
Deferred purchased electric and natural gas costs (Note 1)	$	15,743	$	11,367	$	2,892
Deferred unrealized losses on derivatives (Note 14)		517		1,259		22,118
PSC General and Temporary State Assessment and carrying charges		8,854		6,260		11,547
RDM and carrying charges		-		3,393		3,068
Residual natural gas deferred balances		4,554		4,554		4,554
Deferred debt expense on re-acquired debt		601		601		628
Deferred and accrued costs - MGP site remediation and carrying charges (Note 12)		4,605		4,605		4,586
Other		291		290		290
		35,165		32,329		49,683
Long-term:
Deferred pension costs (Note 10)		140,349		146,935		151,737
Deferred unrealized losses on derivatives (Note 14)		93		218		1,688
Carrying charges - pension reserve		10,303		9,182		6,158
Deferred and accrued costs - MGP site remediation and carrying charges (Note 12)		10,109		10,739		13,459
Deferred debt expense on re-acquired debt		4,586		4,737		5,172
Deferred Medicare Subsidy taxes		7,933		7,808		7,450
Residual natural gas deferred balances and carrying charges		3,809		5,443		8,168
Income taxes recoverable through future rates		37,119		29,908		47,820
Energy efficiency incentives		2,719		2,719		2,719
Deferred storm costs and carrying charges		19,717		23,274		15,178
Other		13,322		15,751		11,747
		250,059		256,714		271,296
Total Regulatory Assets	$	285,224	$	289,043	$	320,979
Regulatory Liabilities (Credits):
Current:
Excess electric depreciation reserve	$	-	$	-	$	74
RDM and carrying charges		2,330		-		-
Deferred unrealized gains on derivatives (Note 14)		2,941		95		-
Income taxes refundable through future rates		4,431		4,669		5,120
Deferred unbilled gas revenues		4,866		5,972		3,765
		14,568		10,736		8,959
Long-term:
Customer benefit fund		2,419		2,390		2,566
Deferred cost of removal (Note 1)		44,795		43,392		42,748
Rate Base impact of tax repair project and carrying charges		9,159		9,099		8,083
Excess electric depreciation reserve carrying charges		1,586		1,586		2,688
Deferred unrealized gains on derivatives (Note 14)		2,881		693		-
Income taxes refundable through future rates		24,194		21,062		33,769
Deferred OPEB costs		9,696		7,975		8,974
Carrying charges - OPEB reserve		11,222		9,949		6,482
Other		12,448		9,314		5,199
		118,400		105,460		110,509
Total Regulatory Liabilities	$	132,968	$	116,196	$	119,468
Net Regulatory Assets	$	152,256	$	172,847	$	201,511

2010 Rate Order

From July 1, 2010 through June 30, 2013, Central Hudson is operating under the terms of the 2010 Rate Order, which provides for the following:

Description	2010 Rate Order
Electric delivery revenue increases	$11.8 million(1) 7/1/10 $9.3 million(1)  7/1/11 $9.1 million 7/1/12
Natural gas delivery revenue increases	$5.7 million 7/1/10 $2.4 million 7/1/11 $1.6 million 7/1/12
ROE	10.0%
Earnings sharing	Yes(2)
Capital structure – common equity	48%
Targets with true-up provisions - % of revenue requirement to defer for shortfalls
Net plant balances	100%
Transmission and distribution ROW maintenance	100%
RDMs – electric and natural gas(3)	Yes
New deferral accounting for full recovery
Fixed debt costs	Yes(4)
Transmission sag mitigation	Yes
New York State Temporary Assessment	Yes
Material regulatory actions(5)	Yes(5)
Property taxes – Deferral for 90% of excess/deficiency relative to revenue requirement	Yes(6)

(1) Moderated by $12 million and $4 million bill credits, respectively.

(2) ROE > 10.5%, 50% to customers, > 11.0%, 80% to customers, > 11.5%, 90% to customers.

(3) Electric is based on revenue dollars; gas is based on usage per customer.

(4) Deferral authorization in RY2 and RY3 only.

(5) Legislative, governmental or regulatory actions with individual impacts greater than or equal to 2% of net income of the applicable department.

(6) The Company's pre-tax gain or loss limited to $0.7 million per rate year.

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Other Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2013

Other Fair Value Measurements [Abstract]

Other Fair Value Measurements

In addition to the derivatives reported at fair value discussed in Note 14 – "Accounting for Derivative Instruments and Hedging Activities", CH Energy Group reports certain other assets at fair value in the Consolidated Balance Sheets. The following table summarizes the amount reported at fair value related to these assets as of March 31, 2013, December 31, 2012, and March 31, 2012 (In Thousands):

Asset Category	Fair Value		Quoted Prices in Active Markets for Identical Assets(Level 1)		Significant Other Observable Inputs(Level 2)		Significant Unobservable Inputs(Level 3)
As of March 31, 2013:
Other investments	$	1,636	$	1,636	$	-	$	-
As of December 31, 2012:
Other investments	$	1,603	$	1,603	$	-	$	-
As of March 31, 2012:
Other investments	$	2,438	$	2,438	$	-	$	-

Long-term Debt Maturities and Fair Value

Long-term Debt Maturities and Fair Value - CH Energy Group

(Dollars in Thousands)

		Fixed Rate				Variable Rate				Total Debt Outstanding
Expected Maturity Date		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate
As of March 31, 2013:
	2013	$	31,076	6.93	%	$	-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	2017		34,406	6.13	%		-	-	%
	Thereafter		386,625	5.13	%		33,700	0.20	%
	Total	$	484,302	5.31	%	$	33,700	0.20	%	$	518,002	5.02	%
	Fair Value	$	554,724			$	33,700			$	588,424
As of December 31, 2012:
	2013	$	31,076	6.93	%	$	-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	2017		34,406	6.13	%		-	-	%
	Thereafter		386,625	5.13	%		33,700	0.28	%
	Total	$	484,302	5.31	%	$	33,700	0.28	%	$	518,002	5.03	%
	Fair Value	$	562,855			$	33,700			$	596,555
As of March 31, 2012:
	2012	$	1,006	6.86	%	$	-	-	%
	2013		31,076	6.93	%		-	-	%
	2014		21,650	5.50	%		-	-	%
	2015		1,230	6.86	%		-	-	%
	2016		9,315	3.36	%		-	-	%
	Thereafter		397,031	5.29	%		33,700	0.37	%
	Total	$	461,308	5.38	%	$	33,700	0.37	%	$	495,008	5.07	%
	Fair Value	$	545,959			$	33,700			$	579,659

Long-term Debt Maturities and Fair Value - Central Hudson

(Dollars in Thousands)

		Fixed Rate					Variable Rate				Total Debt Outstanding
Expected Maturity Date		Amount			Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate		Amount		Estimated Effective Interest Rate
As of March 31, 2013:
	2013	$	30,000		6.93	%	$	-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-	1	-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	2017		33,000		6.10	%		-	-	%
	Thereafter		371,250		5.06	%		33,700	0.20	%
	Total	$	456,250		5.22	%	$	33,700	0.20	%	$	489,950	4.92	%
	Fair Value	$	521,706				$	33,700			$	555,406
As of December 31, 2012:
	2013	$	30,000		6.93	%	$	-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-		-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	2017		33,000		6.10	%		-	-	%
	Thereafter		371,250		5.06	%		33,700	0.28	%
	Total	$	456,250		5.22	%	$	33,700	0.28	%	$	489,950	4.93	%
	Fair Value	$	529,710				$	33,700			$	563,410
As of March 31, 2012:
	2012	$	-		-	%	$	-	-	%
	2013		30,000		6.93	%		-	-	%
	2014		14,000		4.81	%		-	-	%
	2015		-		-	%		-	-	%
	2016		8,000		2.78	%		-	-	%
	Thereafter		380,250		5.22	%		33,700	0.37	%
	Total	$	432,250		5.28	%	$	33,700	0.37	%	$	465,950	4.96	%
	Fair Value	$	507,978				$	33,700			$	541,678

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2013

Commitments and Contingencies [Abstract]

Commitments and Contingencies

NOTE 12 – Commitments and Contingencies

Electricity Purchase Commitments

On June 30, 2010and September 9, 2010,Central Hudson entered into agreements with Entergy Nuclear Power Marketing, LLC to purchase electricity (but not capacity) on a unit-contingent basis at defined prices from January 1, 2011 through December 31, 2013.  For the three months ended March 31, 2012, energy supplied under these agreements cost approximately $5.2 million.  For the three months ended March 31, 2013, energy supplied under these agreements cost approximately $4.3 million, which represents approximately 14% of Central Hudson's full-service customer requirements on an annual basis.

These contracts meet the definition of a normal purchase and are therefore excluded from current accounting requirements related to derivatives.  In the event the above noted counterparty is unable to fulfill its commitment to deliver under the terms of the agreements, Central Hudson would obtain the supply from the New York Independent System Operator ("NYISO") market, and under Central Hudson's current ratemaking treatment, recover the full cost from customers.  As such, there would be no impact on earnings.

Central Hudson must also acquire sufficient peak load capacity to meet the peak load requirements of its full service customers.  This capacity is made up of contracts with capacity providers, purchases from the NYISO capacity market and its own generating capacity.

Environmental Matters

Central Hudson

· Air

There has been no change to this matter in 2013, however, the relevant disclosure is provided as required.  In 1999, the New York State Attorney General ("Attorney General") alleged that Central Hudson "may have constructed, and continues to operate, major modifications to the Danskammer Point Steam Electric Generating Station ("Danskammer Plant") without obtaining certain requisite preconstruction permits."  In March 2000, the Environmental Protection Agency ("EPA") assumed responsibility for the investigation.  Central Hudson believes any permits required for these projects were obtained in a timely manner.  Central Hudson sold the Danskammer Plant to Dynegy in January 2001.  While Central Hudson could have retained liability after the sale, depending on the type of remedy, Central Hudson believes that the statutes of limitation relating to any alleged violation of air emissions rules have lapsed. 

· Former Manufactured Gas Plant Facilities

Central Hudson and its predecessors owned and operated manufactured gas plants ("MGPs") to serve their customers' heating and lighting needs. These plants manufactured gas from coal and oil beginning in the mid to late 1800s with all sites ceasing operations by the 1950s. This process produced certain by-products that may pose risks to human health and the environment.

The New York State Department of Environmental Conservation ("DEC"), which regulates the timing and extent of remediation of MGP sites in New York State, has notified Central Hudson that it believes Central Hudson or its predecessors at one time owned and/or operated MGPs at seven sites in Central Hudson's franchise territory.  The DEC has further requested that Central Hudson investigate and, if necessary, remediate these sites under a Consent Order, Voluntary Cleanup Agreement, or Brownfield Cleanup Agreement.  The DEC has placed all seven of these sites on the New York State Environmental Site Remediation Database.  As authorized by the PSC, Central Hudson is currently permitted to defer for future recovery the differences between actual costs for MGP site investigation and remediation and the associated rate allowances, with carrying charges to be accrued on the deferred balances at the authorized pre-tax rate of return.

MGP site investigation and remediation can be divided into various stages of completion based on the milestones of activities completed and reports reviewed.  Central Hudson accrues for remediation costs based on the amounts that can be reasonably estimated at a point in time.  These stages, the types of costs accrued during various stages and the sites currently in each stage, include:

· Investigation – Begins with preliminary investigations and is completed upon filing and approval by DEC of a Remedial Investigation ("RI") Report.  Central Hudson accrues for estimated investigation costs, Remediation Alternative Analysis ("RAA"), and Remedial Design costs.

Ø Site #6 – Kingston (NY) – Remedial Investigation in Progress

- The revised RI report was submitted to the DEC for review and approval in November 2012.  The DEC provided general and specific comments to the revised RI report in a letter dated February 27, 2013. Central Hudson submitted a comment response letter to the DEC on March 28, 2013.

- Amounts accrued represent an estimate of costs to complete the RAA and the Remedial Design.

· Remedial Alternative Analysis – Engineering analysis of alternatives for remediation based on the RI is compiled into a RAA Report.  Upon completion of the RAA and the filing with the DEC, management accrues for an estimate of remediation costs developed and quantified in the RAA based on DEC approved methods, as well as an estimate of post-remediation operation, maintenance and monitoring costs ("OM&M").  These amounts represent a significant portion of the total costs to remediate and are subject to change based on further investigations, final remedial design and associated engineering estimates, regulatory comments and requests, remedial design changes/negotiations, and changed or unforeseen conditions during the remediation or additional requirements following the remediation. Prior to the completion of the RAA, management cannot reasonably estimate what cost will be incurred for remediation or post-remediation activities.

Ø Site #5 – North Water Street (Poughkeepsie,NY) – Remedial Alternatives Analysis in progress

- DEC approved an Interim Remedial Measure ("IRM") associated with the southern portion of this site.  The IRM activities were completed in 2012.  The IRM Construction Completion Report ("CCR") and Interim Site Management Plan ("SMP") were submitted to the DEC for review and approval in December 2012 and February 2013, respectively.

- In addition, Central Hudson has recently retired and removed propane air facilities formerly located on site. The DEC approved a work plan to investigate the former propane tank area on February 7, 2013.  The investigation is tentatively planned to commence in the spring of 2013.  Depending on the results of this investigation some level of future remediation may be required in this area.

- Amounts accrued represent an estimate for completion of the RAA and Remedial Design.

· Remedial Design - Upon approval of the RAA and final decision of remediation approach based on alternatives presented, a Remedial Design is developed and filed with the DEC for approval.

· Remediation – Completion of the work plan as defined in the approved Remedial Design.  Upon completion, final reports are filed with the DEC for approval and may include a CCR, Final Engineering Report ("FER"), or other reports required by the DEC based on the work performed.

Ø Site #4 – Catskill (NY) – Remediation in Progress

- Remediation activities commenced in September 2012 and are anticipated to be completed in the summer of 2013.

- Amounts accrued represent an estimate of costs to complete the remediation and OM&M.

· Post-Remediation Monitoring – Entails the OM&M as directed by the DEC based on the approved final report of remediation.  The activities are typically defined in a SMP, which is approved by the DEC.  The extent of activities during this phase may increase or decrease based on the results of ongoing monitoring being performed and future potential usage of the property.

Ø Site #1 – Beacon (NY) – Post-Remediation Monitoring Complete

- SMP submitted to the DEC and release letter for the site was received under a March 26, 2013 cover letter.

- No further costs expected and no amounts accrued as of March 31, 2013 related to this site.

- If the building at this site were to be removed, further investigation and testing would be required related to the soil under the building, which may require additional remediation.  Management cannot currently estimate the costs that may be incurred related to this.

Ø Site #2 – Newburgh (NY) – Post-Remediation In Progress

- Amounts accrued represent an estimate of costs for OM&M and execution of the draft SMP.

- Central Hudson has recently retired and removed propane air facilities located on Area A.  A draft figure associated with a future work plan to investigate the former propane tank area was submitted to the DEC in February 2013.   Additionally, draft figures proposing recovery well installation in Area A and B and a proposal to expand the recovery well system near NMW-46 (Area B) were also submitted to the DEC for approval.  Depending on the results from the former propane tank area investigation some level of future remediation may be required in this area. Management cannot currently estimate the costs that may be incurred related to potential remediation of the former propane tank area.

Ø Site #3 – Laurel Street (Poughkeepsie, NY) – Post-Remediation In Progress

- The results of the sampling event completed in January 2013 were submitted to the DEC on February 19, 2013.  The DEC approved a request from Central Hudson to reduce the frequency of sampling from a quarterly to semi-annual frequency on February 20, 2013.

- Central Hudson continues to work with the DEC to complete an Environmental Easement for the portion of the site owned by Central Hudson.

- Amounts accrued represent an estimate of costs for OM&M.

· No Action Required

Ø  Site #7 – Bayeaux Street (Poughkeepsie, NY) – No further investigation or remedial action is currently required.  However, per the DEC this site still remains on the list for potential future investigation.

A summary of amounts accrued and spent are detailed in the chart below (In Thousands):

Site #	Liability Recorded as of 12/31/12		Amounts Spent in 2013(1)		Liability Adjustment			Liability Recorded as of 3/31/13		Current Portion of Liability at 3/31/13		Long-Term Portion of Liability at 3/31/13
1, 2, 3, 4	$	12,210	$	3,628	$	883		$	9,465	$	2,916	$	6,549
5, 6		1,743		68		(62	)		1,613		922		691
	$	13,953	$	3,696	$	821		$	11,078	$	3,838	$	7,240

(1) Amounts spent in 2013 as shown above do not include legal fees of approximately $8 thousand.

Based on a cost model analysis completed in 2012 of possible remediation and future operating, maintenance, and monitoring costs for sites #2 through #6, Central Hudson believes there is a 90% confidence level that the total costs to remediate these sites will not exceed $152.0 million over the next 30 years.  The cost model involves assumptions relating to investigation expenses, results of investigations, remediation costs, potential future liabilities, and post-remedial operating, maintenance and monitoring costs, and is based on a variety of factors including projections regarding the amount and extent of contamination, the location, size and use of the sites, proximity to sensitive resources, status of regulatory investigations, and information regarding remediation activities at other MGP sites in New York State.  The cost model also assumes that proposed or anticipated remediation techniques are technically feasible and that proposed remediation plans receive DEC and New York State Department of Health ("NYSDOH") approval.

Future remediation activities, including OM&M and related costs may vary significantly from the assumptions used in Central Hudson's current cost estimates, and these costs could have a material adverse effect (the extent of which cannot be reasonably determined) on the financial condition, results of operations and cash flows of CH Energy Group and Central Hudson if Central Hudson were unable to recover all or a substantial portion of these costs via collection in rates from customers and/or through insurance.

Central Hudson expects to recover its remediation costs from its customers.  The current components of this recovery include:

- Current Rate Order includes cash recovery from customers of $13.6 million spread equally over the three year settlement period ending June 30, 2013;

- As part of the 2010 Rate Order, Central Hudson maintained previously granted deferral authority and subsequent recovery for amounts spent over the rate allowance.

- Total MGP Site Investigation and Remediation costs recovered through rates and other regulatory mechanisms from July 1, 2007 through March 31, 2013 was approximately $25.6 million, with $1.2 million recovered in the three months ended March 31, 2013.

- The total spent in the three months ended March 31, 2013 related to site investigation and remediation was approximately $3.7 million.

- The regulatory asset balance as of March 31, 2013 was $14.7 million, which represents the difference between amounts spent or currently accrued as a liability and the amounts recovered through rate allowance, as well as carrying charges accrued. Upon completion of investigation at sites #5 and #6, when remediation and post-remediation costs will be able to be reasonably estimated and therefore will be recorded as a liability, this regulatory asset balance will likely increase significantly.  Management projects that the investigation at these sites will likely be completed within the next two years.

Central Hudson has put its insurers on notice and intends to seek reimbursement from its insurers for its costs.  Certain of these insurers have denied coverage.  In addition to the rate allowance amounts noted above, Central Hudson recovered approximately $2.3 million from insurance. There were no insurance recoveries in the first quarter of 2013.  However, we do not expect insurance recoveries to offset a meaningful portion of total costs.

· Little Britain Road property owned by Central Hudson

In 2000, Central Hudson and the DEC entered into a Voluntary Cleanup Agreement ("VCA") whereby Central Hudson removed approximately 3,100 tons of soil and conducted groundwater sampling.  Central Hudson believes that it has fulfilled its obligations under the VCA and should receive the release provided for in the VCA, but the DEC has proposed that additional groundwater work be done to address groundwater sampling results that showed the presence of certain contaminants at levels exceeding the DEC criteria.  Central Hudson believes that such work is not necessary and has completed a soil vapor intrusion study showing that indoor air at the facility met Occupational Safety and Health Administration ("OSHA") and NYSDOH standards. In October 2011, the DEC requested a 'non-committal' meeting with Central Hudson to discuss the site and possible next steps. At the annual MGP meeting with Central Hudson in October 2012, the DEC discussed the Little Britain Road property requesting an upcoming meeting to discuss the site and possible next steps. Central Hudson responded that we are available for such a meeting.  A meeting date has yet to be established.

At this time Central Hudson does not have sufficient information to estimate the need for additional remediation or potential remediation costs.  Central Hudson has put its insurers on notice regarding this matter and intends to seek reimbursement from its insurers for amounts, if any, for which it may become liable.  Central Hudson cannot predict the outcome of this matter.

· Eltings Corners

Central Hudson owns and operates a maintenance and warehouse facility.  In the course of Central Hudson's hazardous waste permit renewal process for this facility, sediment contamination was discovered within the wetland area across the street from the main property.  In cooperation with the DEC, Central Hudson continues to investigate the nature and extent of the contamination.  Additional off-site sediment and on-site groundwater sampling was performed during 2012 in accordance with a supplemental work plan approved by the DEC.  Results from the on-site groundwater sampling activities were submitted to the DEC in January of 2013.  Following their review, the DEC issued a letter dated March 28, 2013 relieving Central Hudson from any further on-site groundwater sampling.  The sediment sampling results are expected to be submitted to the DEC in the spring of 2013.  Further sediment investigation is expected to take place in 2013.  The extent of the contamination as well as the timing and costs for any future remediation efforts cannot be reasonably estimated at this time.

CHEC

During the three months ended March 31, 2013, the amount spent by Griffith on remediation efforts in Maryland, Virginia and Connecticut were immaterial.

Griffith's reserve for environmental remediation is $1.4 million as of March 31, 2013, of which $0.4 million is expected to be spent in the next twelve months.

In connection with the 2009 sale of operations in certain geographic locations, Griffith agreed to indemnify the purchaser for certain claims, losses and expenses arising out of any breach by Griffith of the representations, warranties and covenants Griffith made in the sale agreement, certain environmental matters and all liabilities retained by Griffith.  Griffith's indemnification obligation is subject to a number of limitations, including a five-year limitation within which certain claims must be brought, an aggregate deductible of $0.8 million applicable to certain types of non-environmental claims and other deductibles applicable to certain specific environmental claims, and caps on Griffith's liability with respect to certain of the indemnification obligations.  The sale agreement includes an aggregate cap of $5.7 million on Griffith's obligation to indemnify the purchaser for breaches of many of Griffith's representations and warranties and for certain environmental liabilities.  In 2009, the Company reserved $2.6 million for environmental remediation costs it may be obligated to pay based on its indemnification obligations under the sale agreement.  To date, Griffith has paid approximately $1.2 million under its environmental remediation cost obligation.  In the first quarter of 2011, Griffith reduced the reserve by $0.6 million based on the completion of an environmental study.  The balance as of March 31, 2013 related to the divestiture is $0.8 million.  Management believes this is the most likely amount Griffith would pay with respect to its indemnification obligations under the sale agreement.

Certain Litigation Related to the Fortis Transaction

Following the announcement of the proposed acquisition of CH Energy Group by Fortis on February 21, 2012, several complaints were filed by purported CH Energy Group shareholders in the Supreme Court of the State of New York, County of New York (the "New York County Court") and the Supreme Court of the State of New York, County of Dutchess, challenging the proposed merger. The Dutchess County actions have been transferred to the New York County Court, and all actions have been joined under the master caption In re CH Energy Group, Inc. Shareholder Litigation, Index No. 775,000/2012.

On April 9, 2012, a master amended complaint was filed in the joined litigation related to the proposed acquisition of CH Energy Group by Fortis.  The master amended complaint, which was filed on behalf of a putative class of CH Energy Group public shareholders, names as defendants CH Energy Group, its directors, Fortis, FortisUS, and Cascade Acquisition Sub, Inc. and generally alleges that the individual defendants breached their fiduciary duties in connection with the proposed transaction and that the entity defendants aided and abetted that breach.  The master amended complaint further alleges that the preliminary proxy filed in connection with the proposed transaction with Fortis contains material misstatements and omissions.  The master complaint seeks, among other things, an order preliminarily and permanently enjoining the proposed transaction with Fortis, damages, and plaintiffs' fees and expenses.

On May 9, 2012, the parties executed a memorandum of understanding that embodies their agreement in principle on the structure of a proposed settlement. The proposed settlement, which is subject to certain conditions, including court approval following notice to a proposed settlement class consisting of all CH Energy Group shareholders during the period from February 19, 2012 through the date of the consummation of the proposed merger (the "Class"), would, among other things, dismiss all causes of action asserted in the master amended complaint and release all claims that members of the Class may have arising out of or relating in any manner to the proposed merger. Pursuant to the terms of the proposed settlement, defendants agreed to make certain disclosures to shareholders.  In the meantime, the plaintiffs and their counsel have agreed, among other things, to stay the litigation and not to initiate any proceedings (including, but not limited to, a motion for a preliminary injunction) other than those incident to effecting the settlement.

Absent court approval of the proposed settlement, the defendants intend to vigorously defend themselves against the action.

Other Matters

Asbestos Litigation

As of March 31, 2013, of the 3,338 asbestos cases brought against Central Hudson, 1,166 remain pending.  Of the cases no longer pending against Central Hudson, 2,017 have been dismissed or discontinued without payment by Central Hudson, and Central Hudson has settled 155 cases.  Central Hudson is presently unable to assess the validity of the remaining asbestos lawsuits; however, based on information known to Central Hudson at this time, including Central Hudson's experience in settling asbestos cases and in obtaining dismissals of asbestos cases, Central Hudson believes that the costs which may be incurred in connection with the remaining lawsuits will not have a material adverse effect on the financial position, results of operations or cash flows of either CH Energy Group or Central Hudson.

Central Hudson and Griffith are involved in various other legal and administrative proceedings incidental to their businesses, which are in various stages.  While these matters collectively could involve substantial amounts, based on the facts currently known, it is the opinion of management that their ultimate resolution will not have a material adverse effect on either of CH Energy Group's or the individual segment's financial positions, results of operations or cash flows.

CH Energy Group and Central Hudson expense legal costs as incurred.