Atmos Energy (ATO) 10-Q4 Feb 142014 Q1 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
Document and Entity Information	Dec. 31, 2013	Jan. 31, 2014
Document And Entity Information [Abstract]	'	'
Entity Registrant Name	'Atmos Energy Corporation	'
Entity Central Index Key	'0000731802	'
Current Fiscal Year End Date	'--09-30	'
Entity Filer Category	'Large Accelerated Filer	'
Document Type	'10-Q	'
Document Period End Date	31-Dec-13	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	90,958,751
Entity Well-known Seasoned Issuer	'Yes	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $)	Dec. 31, 2013	Sep. 30, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013
ASSETS	'	'
Property, plant and equipment	$7,861,741	$7,722,019
Less accumulated depreciation and amortization	1,708,778	1,691,364
Net property, plant and equipment	6,152,963	6,030,655
Current assets	'	'
Cash and cash equivalents	194,563	66,199
Accounts receivable, net	661,213	301,992
Gas stored underground	286,542	244,741
Other current assets	157,252	64,201
Total current assets	1,299,570	677,133
Goodwill	741,363	741,363
Deferred charges and other assets	422,195	485,117
Total assets	8,616,091	7,934,268
Shareholders' equity	'	'
Common stock, no par value (stated at $.005 per share)	455	453
Additional paid-in capital	1,769,516	1,765,811
Retained earnings	828,311	775,267
Accumulated other comprehensive income (loss)	63,032	38,878
Shareholders' equity	2,661,314	2,580,409
Long-term debt	1,955,750	2,455,671
Total capitalization	4,617,064	5,036,080
Current liabilities	'	'
Accounts payable and accrued liabilities	458,198	241,611
Other current liabilities	365,508	368,891
Short-term debt	689,795	367,984
Current maturities of long-term debt	500,000	0
Total current liabilities	2,013,501	978,486
Deferred income taxes	1,230,052	1,164,053
Regulatory cost of removal obligation	356,617	359,299
Pension and postretirement liabilities	359,534	358,787
Deferred credits and other liabilities	39,323	37,563
Total shareholders' equity and liabilities	$8,616,091	$7,934,268

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (PARENTHETICALS) (USD $)	Dec. 31, 2013	Sep. 30, 2013
Statement of Financial Position [Abstract]	'	'
Common Stock, Par Value Per Share	$0	$0
Common Stock, Stated Value Per Share	$0.01	$0.01
Common Stock, Shares Authorized	200,000,000	200,000,000
Common Stock, Shares, Issued	90,958,302	90,640,211
Common Stock, Shares, Outstanding	90,958,302	90,640,211

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (USD $)	3 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Operating revenues	'	'
Operating revenues	$1,255,148,000	$1,034,155,000
Purchased gas cost	'	'
Purchased gas cost	866,191,000	671,793,000
Gross profit	388,957,000	362,362,000
Operating expenses	'	'
Operation and maintenance	115,757,000	106,527,000
Depreciation and amortization	60,469,000	59,579,000
Taxes, other than income	42,011,000	41,334,000
Total operating expenses	218,237,000	207,440,000
Operating income	170,720,000	154,922,000
Miscellaneous income (expense)	-2,132,000	698,000
Interest charges	32,115,000	30,522,000
Income (loss) before income taxes	136,473,000	125,098,000
Income tax expense (benefit)	49,457,000	47,750,000
Income (loss) from continuing operations	87,016,000	77,348,000
Income from discontinued operations, net of tax	0	3,117,000
Net income (loss)	87,016,000	80,465,000
Income Loss From Continuing Operations Per Basic Share	$0.96	$0.85
Income Loss From Discontinued Operations Net Of Tax Per Basic Share	$0	$0.04
Basic net income (loss) per share	$0.96	$0.89
Income Loss From Continuing Operations Per Diluted Share	$0.95	$0.85
Income Loss From Discontinued Operations Net Of Tax Per Diluted Share	$0	$0.03
Diluted net income (loss) per share	$0.95	$0.88
Cash dividends per share	$0.37	$0.35
Weighted average shares outstanding:	'	'
Basic weighted average shares outstanding	90,833	90,359
Diluted weighted average shares outstanding	91,746	91,309
Natural Gas Distribution Segment [Member]	'	'
Operating revenues	'	'
Operating revenues	843,865,000	666,787,000
Purchased gas cost	'	'
Purchased gas cost	544,694,000	387,156,000
Gross profit	299,171,000	279,631,000
Operating expenses	'	'
Operation and maintenance	89,663,000	83,736,000
Depreciation and amortization	49,551,000	50,060,000
Taxes, other than income	37,084,000	36,751,000
Total operating expenses	176,298,000	170,547,000
Operating income	122,873,000	109,084,000
Miscellaneous income (expense)	-471,000	-131,000
Interest charges	23,325,000	23,563,000
Income (loss) before income taxes	99,077,000	85,390,000
Income tax expense (benefit)	36,320,000	32,297,000
Income (loss) from continuing operations	'	53,093,000
Income from discontinued operations, net of tax	'	3,117,000
Net income (loss)	62,757,000	56,210,000
Regulated Transmission and Storage Segment [Member]	'	'
Operating revenues	'	'
Operating revenues	71,341,000	60,681,000
Purchased gas cost	'	'
Purchased gas cost	0	0
Gross profit	71,341,000	60,681,000
Operating expenses	'	'
Operation and maintenance	17,300,000	16,320,000
Depreciation and amortization	9,786,000	8,390,000
Taxes, other than income	4,663,000	3,949,000
Total operating expenses	31,749,000	28,659,000
Operating income	39,592,000	32,022,000
Miscellaneous income (expense)	-1,181,000	-127,000
Interest charges	8,957,000	6,871,000
Income (loss) before income taxes	29,454,000	25,024,000
Income tax expense (benefit)	10,008,000	8,919,000
Income (loss) from continuing operations	'	16,105,000
Income from discontinued operations, net of tax	'	0
Net income (loss)	19,446,000	16,105,000
Nonregulated Segment [Member]	'	'
Operating revenues	'	'
Operating revenues	447,721,000	399,894,000
Purchased gas cost	'	'
Purchased gas cost	429,155,000	377,435,000
Gross profit	18,566,000	22,459,000
Operating expenses	'	'
Operation and maintenance	8,915,000	6,882,000
Depreciation and amortization	1,132,000	1,129,000
Taxes, other than income	264,000	634,000
Total operating expenses	10,311,000	8,645,000
Operating income	8,255,000	13,814,000
Miscellaneous income (expense)	324,000	1,667,000
Interest charges	637,000	797,000
Income (loss) before income taxes	7,942,000	14,684,000
Income tax expense (benefit)	3,129,000	6,534,000
Income (loss) from continuing operations	'	8,150,000
Income from discontinued operations, net of tax	'	0
Net income (loss)	4,813,000	8,150,000
Intersegment Elimination [Member]	'	'
Operating revenues	'	'
Operating revenues	-107,779,000	-93,207,000
Purchased gas cost	'	'
Purchased gas cost	-107,658,000	-92,798,000
Gross profit	-121,000	-409,000
Operating expenses	'	'
Operation and maintenance	-121,000	-411,000
Depreciation and amortization	0	0
Taxes, other than income	0	0
Total operating expenses	-121,000	-411,000
Operating income	0	2,000
Miscellaneous income (expense)	-804,000	-711,000
Interest charges	-804,000	-709,000
Income (loss) before income taxes	0	0
Income tax expense (benefit)	0	0
Income (loss) from continuing operations	'	0
Income from discontinued operations, net of tax	'	0
Net income (loss)	$0	$0

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (PARENTHETICALS) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Income Statement [Abstract]	'	'
Discontinued Operation Tax Effect Of Income Loss From Discontinued Operation During Phase Out Period	$0	$1,728

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Statement of Comprehensive Income [Abstract]	'	'
Net income (loss)	$87,016	$80,465
Other comprehensive income (loss), net of tax	'	'
Net unrealized holding gains (losses) on available-for-sale securities, net of tax	2,394	-373
Amortization and unrealized gains (losses) on interest rate agreements, net of tax	13,942	12,264
Net unrealized gains (losses) on commodity cash flow hedges, net of tax	7,818	-365
Total other comprehensive income	24,154	11,526
Total comprehensive income	$111,170	$91,991

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (PARENTHETICALS) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Other Comprehensive Income Loss Tax Portion Attributable To Parent Abstract	'	'
Unrealized holding gains (losses) on available-for-sale securities, tax	$1,435	($220)
Amortization and unrealized gains (losses) on interest rate agreements, tax	8,013	7,049
Net unrealized gains (losses) on commodity cash flow hedging transactions, tax	$4,999	($233)

CONDENSED_CONSOLIDATED_STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Cash Flows From Operating Activities	'	'
Net income (loss)	$87,016	$80,465
Depreciation and amortization:	'	'
Charged to depreciation and amortization	60,469	60,500
Charged to other accounts	221	128
Other	'	'
Deferred income taxes	47,127	45,951
Other	5,228	3,242
Net Assets Liabilities From Risk Management Activities	-5,477	-15,641
Net change in operating assets and liabilities	-160,284	-144,787
Net cash provided by operating activities	34,300	29,858
Cash Flows From Investing Activities	'	'
Capital expenditures	-180,567	-190,027
Other, net	-5,867	-1,273
Net cash used in investing activities	-186,434	-191,300
Cash Flows From Financing Activities	'	'
Net decrease in short-term debt	320,783	256,933
Cash dividends paid	-33,984	-31,992
Repurchase of equity awards	-6,289	-3,124
Other	-12	-13
Net cash provided by (used in) financing activities	280,498	221,804
Net increase (decrease) in cash and cash equivalents	128,364	60,362
Cash and cash equivalents at beginning of period	66,199	64,239
Cash and cash equivalents at end of period	$194,563	$124,601

Nature_of_Business

Nature of Business	3 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Nature of Business	'
	Nature of Business
	Atmos Energy Corporation (“Atmos Energy” or the “Company”) and our subsidiaries are engaged primarily in the regulated natural gas distribution and transmission and storage businesses as well as certain other nonregulated businesses. For the fiscal year ended September 30, 2013, our regulated businesses generated approximately 95 percent of our consolidated net income.
	Through our natural gas distribution business, we deliver natural gas through sales and transportation arrangements to approximately three million residential, commercial, public authority and industrial customers through our six regulated natural gas distribution divisions, which at December 31, 2013, covered service areas located in eight states. On April 1, 2013, we completed the divestiture of our natural gas distribution operations in Georgia, representing approximately 64,000 customers. In addition, we transport natural gas for others through our distribution system. Our regulated businesses also include our regulated pipeline and storage operations, which include the transportation of natural gas to our distribution system and the management of our underground storage facilities. Our regulated businesses are subject to federal and state regulation and/or regulation by local authorities in each of the states in which our natural gas distribution divisions operate.
	Our nonregulated businesses operate primarily in the Midwest and Southeast through various wholly-owned subsidiaries of Atmos Energy Holdings, Inc., (AEH). AEH is wholly owned by the Company and based in Houston, Texas. Through AEH, we provide natural gas management and transportation services to municipalities, natural gas distribution companies, including certain divisions of Atmos Energy and third parties.
	We operate the Company through the following three segments:

	•	the natural gas distribution segment, which includes our regulated natural gas distribution and related sales operations,

	•	the regulated transmission and storage segment, which includes the regulated pipeline and storage operations of our Atmos Pipeline — Texas Division and

	•	the nonregulated segment, which includes our nonregulated natural gas management, nonregulated natural gas transmission, storage and other services.

Unaudited_Financial_Informatio

Unaudited Financial Information	3 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Unaudited Financial Information	'
	Unaudited Financial Information
	These consolidated interim-period financial statements have been prepared in accordance with accounting principles generally accepted in the United States on the same basis as those used for the Company’s audited consolidated financial statements included in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. In the opinion of management, all material adjustments (consisting of normal recurring accruals) necessary for a fair presentation have been made to the unaudited consolidated interim-period financial statements. These consolidated interim-period financial statements are condensed as permitted by the instructions to Form 10-Q and should be read in conjunction with the audited consolidated financial statements of Atmos Energy Corporation included in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. Because of seasonal and other factors, the results of operations for the three-month period ended December 31, 2013 are not indicative of our results of operations for the full 2014 fiscal year, which ends September 30, 2014.
	Except as noted in Note 5, no events have occurred subsequent to the balance sheet date that would require recognition or disclosure in the condensed consolidated financial statements.

	Significant accounting policies
	Our accounting policies are described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013.
	Certain prior-year amounts have been reclassified to conform with the current-year presentation.
	Due to the April 1, 2013 sale of our Georgia distribution operations, prior year financial results for this service area are shown in discontinued operations.
	During the three months ended December 31, 2013, there were no new accounting standards announced that will become applicable to the Company in future periods. Disclosure requirements for offsetting arrangements for financial instruments became effective for us beginning on October 1, 2013. We have presented these disclosures in Note 8. The adoption of this standard did not have an impact on our financial position, results of operations or cash flows. There were no other significant changes to our accounting policies during the three months ended December 31, 2013.
	Regulatory assets and liabilities
	Accounting principles generally accepted in the United States require cost-based, rate-regulated entities that meet certain criteria to reflect the authorized recovery of costs due to regulatory decisions in their financial statements. As a result, certain costs are permitted to be capitalized rather than expensed because they can be recovered through rates. We record certain costs as regulatory assets when future recovery through customer rates is considered probable. Regulatory liabilities are recorded when it is probable that revenues will be reduced for amounts that will be credited to customers through the ratemaking process. Substantially all of our regulatory assets are recorded as a component of deferred charges and other assets and substantially all of our regulatory liabilities are recorded as a component of deferred credits and other liabilities. Deferred gas costs are recorded either in other current assets or liabilities and the regulatory cost of removal obligation is reported separately.

	Significant regulatory assets and liabilities as of December 31, 2013 and September 30, 2013 included the following:


		December 31,		September 30,
		2013		2013
		(In thousands)
	Regulatory assets:
	Pension and postretirement benefit costs(1)	$	180,512	$	187,977

	Merger and integration costs, net	5,120		5,250

	Deferred gas costs	8,630		15,152

	Regulatory cost of removal asset	9,998		10,008

	Rate case costs	5,806		6,329

	Texas Rule 8.209(2)	31,838		30,364

	APT annual adjustment mechanism	5,773		5,853

	Recoverable loss on reacquired debt	20,796		21,435

	Other	4,480		4,380

		$	272,953	$	286,748

	Regulatory liabilities:
	Deferred gas costs	$	50,094	$	16,481

	Deferred franchise fees	4,792		1,689

	Regulatory cost of removal obligation	425,028		427,524

	Other	9,788		7,887

		$	489,702	$	453,581



	(1)	Includes $18.2 million and $17.4 million of pension and postretirement expense deferred pursuant to regulatory authorization.

	(2)	Texas Rule 8.209 is a Railroad Commission rule that allows for the deferral of all expenses associated with capital expenditures incurred pursuant to this rule, including the recording of interest on the deferred expenses until the next rate proceeding (rate case or annual rate filing), at which time investment and costs would be recovered through base rates.
	Currently authorized rates do not include a return on certain of our merger and integration costs; however, we recover the amortization of these costs. Merger and integration costs, net, are generally amortized on a straight-line basis over estimated useful lives ranging up to 20 years.

Segment_Information

Segment Information	3 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Information	'
	Segment Information
	As discussed in Note 1 above, we operate the Company through the following three segments:

	•	The natural gas distribution segment, which includes our regulated natural gas distribution and related sales operations,

	•	The regulated transmission and storage segment, which includes the regulated pipeline and storage operations of our Atmos Pipeline — Texas Division and

	•	The nonregulated segment, which is comprised of our nonregulated natural gas management, nonregulated natural gas transmission, storage and other services.

	Our determination of reportable segments considers the strategic operating units under which we manage sales of various products and services to customers in differing regulatory environments. Although our natural gas distribution segment operations are geographically dispersed, they are reported as a single segment as each natural gas distribution division has similar economic characteristics. The accounting policies of the segments are the same as those described in the summary of significant accounting policies found in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. We evaluate performance based on net income or loss of the respective operating units.
	Income statements for the three month periods ended December 31, 2013 and 2012 by segment are presented in the following tables:


		Three Months Ended December 31, 2013
		Natural				Regulated				Nonregulated			Eliminations				Consolidated
		Gas				Transmission
		Distribution				and Storage
		(In thousands)
	Operating revenues from external parties	$	842,432			$	21,170			$	391,546		$	—			$	1,255,148

	Intersegment revenues	1,433				50,171				56,175			(107,779		)		—

		843,865				71,341				447,721			(107,779		)		1,255,148

	Purchased gas cost	544,694				—				429,155			(107,658		)		866,191

	Gross profit	299,171				71,341				18,566			(121		)		388,957

	Operating expenses
	Operation and maintenance	89,663				17,300				8,915			(121		)		115,757

	Depreciation and amortization	49,551				9,786				1,132			—				60,469

	Taxes, other than income	37,084				4,663				264			—				42,011

	Total operating expenses	176,298				31,749				10,311			(121		)		218,237

	Operating income	122,873				39,592				8,255			—				170,720

	Miscellaneous income (expense)	(471		)		(1,181		)		324			(804		)		(2,132		)

	Interest charges	23,325				8,957				637			(804		)		32,115

	Income before income taxes	99,077				29,454				7,942			—				136,473

	Income tax expense	36,320				10,008				3,129			—				49,457

	Net income	$	62,757			$	19,446			$	4,813		$	—			$	87,016

	Capital expenditures	$	127,506			$	52,921			$	140		$	—			$	180,567






		Three Months Ended December 31, 2012
		Natural				Regulated				Nonregulated			Eliminations				Consolidated
		Gas				Transmission
		Distribution				and Storage
		(In thousands)
	Operating revenues from external parties	$	665,549			$	18,699			$	349,907		$	—			$	1,034,155

Intersegment revenues	1,238				41,982				49,987			(93,207		)		—

	666,787				60,681				399,894			(93,207		)		1,034,155

Purchased gas cost	387,156				—				377,435			(92,798		)		671,793

Gross profit	279,631				60,681				22,459			(409		)		362,362

Operating expenses
Operation and maintenance	83,736				16,320				6,882			(411		)		106,527

Depreciation and amortization	50,060				8,390				1,129			—				59,579

Taxes, other than income	36,751				3,949				634			—				41,334

Total operating expenses	170,547				28,659				8,645			(411		)		207,440

Operating income	109,084				32,022				13,814			2				154,922

Miscellaneous income (expense)	(131		)		(127		)		1,667			(711		)		698

Interest charges	23,563				6,871				797			(709		)		30,522

Income from continuing operations before income taxes	85,390				25,024				14,684			—				125,098

Income tax expense	32,297				8,919				6,534			—				47,750

Income from continuing operations	53,093				16,105				8,150			—				77,348

Income from discontinued operations, net of tax	3,117				—				—			—				3,117

Net income	$	56,210			$	16,105			$	8,150		$	—			$	80,465

Capital expenditures	$	145,871			$	43,831			$	325		$	—			$	190,027













Balance sheet information at December 31, 2013 and September 30, 2013 by segment is presented in the following tables.



	31-Dec-13
	Natural				Regulated				Nonregulated			Eliminations				Consolidated
	Gas				Transmission
	Distribution				and Storage
	(In thousands)
ASSETS
Property, plant and equipment, net	$	4,799,657			$	1,293,093			$	60,213		$	—			$	6,152,963

Investment in subsidiaries	863,214				—				(2,096		)	(861,118		)		—

Current assets
Cash and cash equivalents	152,058				—				42,505			—				194,563

Assets from risk management activities	88,934				—				9,001			—				97,935

Other current assets	740,359				11,184				564,079			(308,550		)		1,007,072

Intercompany receivables	793,589				—				—			(793,589		)		—

Total current assets	1,774,940				11,184				615,585			(1,102,139		)		1,299,570

Intangible assets	—				—				110			—				110

Goodwill	574,190				132,462				34,711			—				741,363

Noncurrent assets from risk management activities	45,878				—				2,614			—				48,492

Deferred charges and other assets	345,075				20,960				7,558			—				373,593

	$	8,402,954			$	1,457,699			$	718,695		$	(1,963,257	)		$	8,616,091

CAPITALIZATION AND LIABILITIES
Shareholders’ equity	$	2,661,314			$	415,868			$	447,346		$	(863,214	)		$	2,661,314

Long-term debt	1,955,750				—				—			—				1,955,750

Total capitalization	4,617,064				415,868				447,346			(863,214		)		4,617,064

Current liabilities
Current maturities of long-term debt	500,000				—				—			—				500,000

Short-term debt	972,795				—				—			(283,000		)		689,795

Liabilities from risk management activities	36				—				—			—				36

Other current liabilities	645,433				20,429				181,262			(23,454		)		823,670

Intercompany payables	—				719,438				74,151			(793,589		)		—

Total current liabilities	2,118,264				739,867				255,413			(1,100,043		)		2,013,501

Deferred income taxes	916,095				299,819				14,138			—				1,230,052

Regulatory cost of removal obligation	356,617				—				—			—				356,617

Pension and postretirement liabilities	359,534				—				—			—				359,534

Deferred credits and other liabilities	35,380				2,145				1,798			—				39,323

	$	8,402,954			$	1,457,699			$	718,695		$	(1,963,257	)		$	8,616,091





	30-Sep-13
	Natural				Regulated				Nonregulated			Eliminations				Consolidated
	Gas				Transmission
	Distribution				and Storage
	(In thousands)
ASSETS
Property, plant and equipment, net	$	4,719,873			$	1,249,767			$	61,015		$	—			$	6,030,655

Investment in subsidiaries	831,136				—				(2,096		)	(829,040		)		—

Current assets
Cash and cash equivalents	4,237				—				61,962			—				66,199

Assets from risk management activities	1,837				—				10,129			—				11,966

Other current assets	428,366				11,709				452,126			(293,233		)		598,968

Intercompany receivables	783,738				—				—			(783,738		)		—

Total current assets	1,218,178				11,709				524,217			(1,076,971		)		677,133

Intangible assets	—				—				121			—				121

Goodwill	574,190				132,462				34,711			—				741,363

Noncurrent assets from risk management activities	109,354				—				—			—				109,354

Deferred charges and other assets	347,687				19,227				8,728			—				375,642

	$	7,800,418			$	1,413,165			$	626,696		$	(1,906,011	)		$	7,934,268

CAPITALIZATION AND LIABILITIES
Shareholders’ equity	$	2,580,409			$	396,421			$	434,715		$	(831,136	)		$	2,580,409

Long-term debt	2,455,671				—				—			—				2,455,671

Total capitalization	5,036,080				396,421				434,715			(831,136		)		5,036,080

Current liabilities
Current maturities of long-term debt	—				—				—			—				—

Short-term debt	645,984				—				—			(278,000		)		367,984

Liabilities from risk management activities	1,543				—				—			—				1,543

Other current liabilities	491,681				20,288				110,306			(13,316		)		608,959

Intercompany payables	—				712,768				70,970			(783,738		)		—

Total current liabilities	1,139,208				733,056				181,276			(1,075,054		)		978,486

Deferred income taxes	871,360				283,554				8,960			179				1,164,053

Regulatory cost of removal obligation	359,299				—				—			—				359,299

Pension and postretirement liabilities	358,787				—				—			—				358,787

Deferred credits and other liabilities	35,684				134				1,745			—				37,563

	$	7,800,418			$	1,413,165			$	626,696		$	(1,906,011	)		$	7,934,268

Earnings_Per_Share

Earnings Per Share	3 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	Earnings Per Share
	We use the two-class method of computing earnings per share because we have participating securities in the form of non-vested restricted stock units with a nonforfeitable right to dividend equivalents, for which vesting is predicated solely on the passage of time. The calculation of earnings per share using the two-class method excludes income attributable to these participating securities from the numerator and excludes the dilutive impact of those shares from the denominator. Basic and diluted earnings per share for the three months ended December 31, 2013 and 2012 are calculated as follows:


		Three Months Ended
		December 31
		2013			2012
		(In thousands, except per share amounts)
	Basic Earnings Per Share from continuing operations
	Income from continuing operations	$	87,016		$	77,348

	Less: Income from continuing operations allocated to participating securities	235			260

	Income from continuing operations available to common shareholders	$	86,781		$	77,088

	Basic weighted average shares outstanding	90,833			90,359

	Income from continuing operations per share — Basic	$	0.96		$	0.85


	Basic Earnings Per Share from discontinued operations
	Income from discontinued operations	$	—		$	3,117

	Less: Income from discontinued operations allocated to participating securities	—			10

	Income from discontinued operations available to common shareholders	$	—		$	3,107

	Basic weighted average shares outstanding	90,833			90,359

	Income from discontinued operations per share — Basic	$	—		$	0.04

	Net income per share — Basic	$	0.96		$	0.89




		Three Months Ended
		December 31
		2013			2012
		(In thousands, except per share amounts)
	Diluted Earnings Per Share from continuing operations
	Income from continuing operations available to common shareholders	$	86,781		$	77,088

	Effect of dilutive stock options and other shares	1			2

	Income from continuing operations available to common shareholders	$	86,782		$	77,090

	Basic weighted average shares outstanding	90,833			90,359

	Additional dilutive stock options and other shares	913			950

	Diluted weighted average shares outstanding	91,746			91,309

	Income from continuing operations per share — Diluted	$	0.95		$	0.85


	Diluted Earnings Per Share from discontinued operations
	Income from discontinued operations available to common shareholders	$	—		$	3,107

	Effect of dilutive stock options and other shares	—			—

	Income from discontinued operations available to common shareholders	$	—		$	3,107

Basic weighted average shares outstanding	90,833			90,359

Additional dilutive stock options and other shares	913			950

Diluted weighted average shares outstanding	91,746			91,309

Income from discontinued operations per share — Diluted	$	—		$	0.03

Net income per share — Diluted	$	0.95		$	0.88

There were no out-of-the-money stock options excluded from the computation of diluted earnings per share for the three months ended December 31, 2013 and 2012 as their exercise price was less than the average market price of the common stock during those periods.
2011 Share Repurchase Program
We did not repurchase any shares during the three months ended December 31, 2013 and 2012 under our 2011 share repurchase program.

Debt

Debt	3 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	The nature and terms of our debt instruments and credit facilities are described in detail in Note 5 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. Except as noted below, there were no material changes in the terms of our debt instruments during the three months ended December 31, 2013.
	Long-term debt
	Long-term debt at December 31, 2013 and September 30, 2013 consisted of the following:



		31-Dec-13		30-Sep-13
		(In thousands)
	Unsecured 4.95% Senior Notes, due October 2014	$	500,000	$	500,000

	Unsecured 6.35% Senior Notes, due 2017	250,000		250,000

	Unsecured 8.50% Senior Notes, due 2019	450,000		450,000

	Unsecured 5.95% Senior Notes, due 2034	200,000		200,000

	Unsecured 5.50% Senior Notes, due 2041	400,000		400,000

	Unsecured 4.15% Senior Notes, due 2043	500,000		500,000

	Medium-term note Series A, 1995-1, 6.67%, due 2025	10,000		10,000

	Unsecured 6.75% Debentures, due 2028	150,000		150,000

	Total long-term debt	2,460,000		2,460,000

	Less:
	Original issue discount on unsecured senior notes and debentures	4,250		4,329

	Current maturities	500,000		—

		$	1,955,750	$	2,455,671


	Short-term debt
	Our short-term debt is utilized to fund ongoing working capital needs, such as our seasonal requirements for gas supply, general corporate liquidity and capital expenditures. Our short-term borrowing requirements are affected primarily by the seasonal nature of the natural gas business. Changes in the price of natural gas and the amount of natural gas we need to supply our customers’ needs could significantly affect our borrowing requirements. Our short-term borrowings typically reach their highest levels in the winter months.
	We currently finance our short-term borrowing requirements through a combination of a $950 million commercial paper program, four committed revolving credit facilities and one uncommitted revolving credit facility with third-party lenders. These facilities provide approximately $1.0 billion of working capital funding. At December 31, 2013 and September 30, 2013, a total of $689.8 million and $368.0 million was outstanding under our commercial paper program.
	Regulated Operations
	We fund our regulated operations as needed, primarily through our commercial paper program and three committed revolving credit facilities with third-party lenders that provide approximately $985 million of working capital funding, including a five-year $950 million unsecured facility with an accordion feature, which, if utilized would increased the borrowing capacity to $1.2 billion, a $25 million unsecured facility and a $10 million unsecured revolving credit facility, which is used primarily to issue letters of credit. Due to outstanding letters of credit, the total amount available to us under our $10 million revolving credit facility was $4.1 million at December 31, 2013.
	In addition to these third-party facilities, our regulated operations have a $500 million intercompany revolving credit facility with AEH, which bears interest at the lower of (i) the Eurodollar rate under the five-year revolving credit facility or (ii) the rate outstanding under the commercial paper program. Applicable state regulatory commissions have approved our use of this facility through December 31, 2014.
	Nonregulated Operations
	Atmos Energy Marketing, LLC (AEM), which is wholly owned by AEH, had two $25 million 364-day bilateral credit facilities that expired in December 2013. The $25 million 364-day uncommitted bilateral facility was extended to December 2014. The $25 million committed bilateral facility was replaced with a $15 million committed 364-day bilateral credit facility. These facilities are used primarily to issue letters of credit. Due to outstanding letters of credit, the total amount available to us under these bilateral credit facilities was $15.4 million at December 31, 2013. On January 29, 2014, the $25 million 364-day uncommitted bilateral facility was amended to temporarily increase the amount available under this facility to $50 million to address the increase in volumes and prices driven by colder than normal weather this winter-heating season. The maximum available under the facility will return to $25 million on June 30, 2014.
	AEH has a $500 million intercompany demand credit facility with AEC. This facility bears interest at a rate equal to the one-month LIBOR rate plus 3.00 percent or (ii) the rate for AEM's borrowings under its committed credit facility plus 0.75 percent. Applicable state regulatory commissions have approved our use of this facility through December 31, 2014.
	Shelf Registration

	We have an effective shelf registration statement with the Securities and Exchange Commission (SEC) that permits us to issue a total of $1.75 billion in common stock and/or debt securities. As of December 31, 2013, $1.75 billion was available under the shelf registration statement.
	Debt Covenants
	The availability of funds under our regulated credit facilities is subject to conditions specified in the respective credit agreements, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in these agreements. We are required by the financial covenants in each of these facilities to maintain, at the end of each fiscal quarter, a ratio of total debt to total capitalization of no greater than 70 percent. At December 31, 2013, our total-debt-to-total-capitalization ratio, as defined in the agreements, was 56 percent. In addition, both the interest margin and the fee that we pay on unused amounts under certain of these facilities are subject to adjustment depending upon our credit ratings.
	In addition to these financial covenants, our credit facilities and public indentures contain usual and customary covenants for our business, including covenants substantially limiting liens, substantial asset sales and mergers.
	Additionally, our public debt indentures relating to our senior notes and debentures, as well as certain of our revolving credit agreements, each contain a default provision that is triggered if outstanding indebtedness arising out of any other credit agreements in amounts ranging from in excess of $15 million to in excess of $100 million becomes due by acceleration or is not paid at maturity.
	We were in compliance with all of our debt covenants as of December 31, 2013. If we were unable to comply with our debt covenants, we would likely be required to repay our outstanding balances on demand, provide additional collateral or take other corrective actions.

Interim_Pension_and_Other_Post

Interim Pension and Other Postretirement Benefit Plan Information	3 Months Ended
	Dec. 31, 2013
General Discussion of Pension and Other Postretirement Benefits [Abstract]	'
Interim Pension and Postretirement Benefit Plans	'
	Interim Pension and Other Postretirement Benefit Plan Information
	The components of our net periodic pension cost for our pension and other postretirement benefit plans for the three months ended December 31, 2013 and 2012 are presented in the following table. Most of these costs are recoverable through our gas distribution rates; however, a portion of these costs is capitalized into our gas distribution rate base. The remaining costs are recorded as a component of operation and maintenance expense. On October 2, 2013, due to the retirement of one of our executives, we recognized a settlement loss of $4.5 million associated with our Supplemental Executive Benefits Plan (SEBP). In association with the retirement, on October 2, 2013, we made a $16.8 million benefit payment from the SEBP.


		Three Months Ended December 31
		Pension Benefits								Other Benefits
		2013				2012				2013			2012
		(In thousands)
	Components of net periodic pension cost:
	Service cost	$	4,738			$	5,202			$	4,196		$	4,700

	Interest cost	6,824				6,025				3,988			3,241

	Expected return on assets	(5,901		)		(5,739		)		(1,292		)	(997		)
	Amortization of transition obligation	—				—				68			270

	Amortization of prior service credit	(34		)		(35		)		(363		)	(362		)
	Amortization of actuarial loss	3,932				5,561				158			1,049

	Settlement loss	4,539				—				—			—

	Net periodic pension cost	$	14,098			$	11,014			$	6,755		$	7,901




	The assumptions used to develop our net periodic pension cost for the three months ended December 31, 2013 and 2012 are as follows:


		Pension Benefits						Other Benefits
		2013			2012			2013			2012
	Discount rate	4.95	%		4.04	%		4.95	%		4.04	%
	Rate of compensation increase	3.5	%		3.5	%		N/A			N/A

	Expected return on plan assets	7.25	%		7.75	%		4.6	%		4.7	%
	The discount rate used to compute the present value of a plan’s liabilities generally is based on rates of high-grade corporate bonds with maturities similar to the average period over which the benefits will be paid. Generally, our funding policy has been to contribute annually an amount in accordance with the requirements of the Employee Retirement Income Security Act of 1974. In accordance with the Pension Protection Act of 2006 (PPA), we determined the funded status of our plans as of January 1, 2014. During the first three months of fiscal 2014, we contributed $4.7 million to our defined benefit plans and we anticipate contributing approximately $10 million to $15 million during the remainder of the fiscal year.
	We contributed $5.9 million to our other post-retirement benefit plans during the three months ended December 31, 2013. We expect to contribute a total of approximately $15 million to $20 million to these plans during the remainder of the fiscal year.

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
Commitments and Contingencies	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Litigation and Environmental Matters
	With respect to the specific litigation and environmental-related matters or claims that were disclosed in Note 10 to the financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013, except as noted below, there were no material changes in the status of such litigation and environmental-related matters or claims during the three months ended December 31, 2013.
	Kentucky Litigation
	Since April 2009, Atmos Energy and two subsidiaries of AEH, Atmos Energy Marketing, LLC (AEM) and Atmos Gathering Company, LLC (AGC) (collectively, the Atmos Entities), have been involved in a lawsuit filed in the Circuit Court of Edmonson County, Kentucky related to our Park City Gathering Project. The dispute which gave rise to the litigation involves the amount of royalties due from a third party producer to landowners (who own the mineral rights) for natural gas produced from the landowners’ properties. The third party producer was operating pursuant to leases between the landowners and certain investors/working interest owners. The third party producer filed a petition in bankruptcy, which was subsequently dismissed due to the lack of meaningful assets to reorganize or liquidate.
	Although certain Atmos Energy companies entered into contracts with the third party producer to gather, treat and ultimately sell natural gas produced from the landowners’ properties, no Atmos Energy company had a contractual relationship with the landowners or the investors/working interest owners. After the lawsuit was filed, the landowners were successful in terminating for non-payment of royalties the leases related to the production of natural gas from their properties. Subsequent to termination, the investors/working interest owners under such leases filed additional claims against us for the termination of the leases.
	During the trial, the landowners and the investors/working interest owners requested an award of compensatory damages plus punitive damages against us. On December 17, 2010, the jury returned a verdict in favor of the landowners and investor/working interest owners and awarded compensatory damages of $3.8 million and punitive damages of $27.5 million payable by Atmos Energy and the two AEH subsidiaries.
	A hearing was held on February 28, 2011 to hear a number of motions, including a motion to dismiss the jury verdict and a motion for a new trial. The motions to dismiss the jury verdict and for a new trial were denied. However, the total punitive damages award was reduced from $27.5 million to $24.7 million. On October 17, 2011, we filed our brief of appellants with the Kentucky Court of Appeals, appealing the verdict of the trial court. The appellees in this case subsequently filed their appellees’ brief with the Court of Appeals on January 16, 2012, with our reply brief being filed with the Court of Appeals on March 19, 2012. Oral arguments were held in the case on August 27, 2012.
	In an opinion handed down on January 25, 2013, the Court of Appeals overturned the $28.5 million jury verdict returned against the Atmos Entities. In a unanimous decision by a three-judge panel, the Court of Appeals reversed the claims asserted by the landowners and investors/working interest owners. The Court of Appeals concluded that all of such claims that the Atmos Entities appealed should have been dismissed by the trial court as a matter of law. The Court of Appeals let stand the jury verdict on one claim that Atmos Energy and our subsidiaries chose not to appeal, which was a trespass claim. The jury had awarded a total of $10,000 in compensatory damages to one landowner on that claim. The Court of Appeals vacated all of the other damages awarded by the jury and remanded the case to the trial court for a new trial, solely on the issue of whether punitive damages should be awarded to that landowner and, if so, in what amount.
	The investors/working interest owners, on February 25, 2013, and the landowners, on March 19, 2013, each filed with the Supreme Court of Kentucky, separate motions for discretionary review of the opinion of the Court of Appeals. We filed a response to the motion filed by the investors/working owners on March 27, 2013 and to the landowners’ motion on April 17, 2013. The decision of the Court of Appeals will not become final until the appellate process is completed. We had previously accrued what we believed to be an adequate amount for the anticipated resolution of this matter and we will continue to maintain this amount in legal reserves until the appellate process in this case has been completed. We continue to believe that the final outcome will not have a material adverse effect on our financial condition, results of operations or cash flows.
	In addition, in a related matter, on July 12, 2011, the Atmos Entities filed a lawsuit in the United States District Court, Western District of Kentucky, Atmos Energy Corporation et al.vs. Resource Energy Technologies, LLC and Robert Thorpe and John F. Charles, against the third party producer and its affiliates to recover all costs, including attorneys’ fees, incurred by the Atmos Entities, which are associated with the defense and appeal of the case discussed above as well as for all damages awarded to the plaintiffs in such case against the Atmos Entities. The total amount of damages being claimed in the lawsuit is “open-ended” since the appellate process and related costs are ongoing. This lawsuit is based upon the indemnification provisions agreed to by the third party producer in favor of Atmos Gathering that are contained in an agreement entered into between Atmos Gathering and the third party producer in May 2009. The defendants filed a motion to dismiss the case on August 25, 2011, with Atmos Energy filing a brief in response to such motion on September 19, 2011. On March 27, 2012 the court denied the motion to dismiss. Since that time, we have been engaged in discovery activities in this case.
	Tennessee Business License Tax
	Atmos Energy, through its affiliate, AEM, has been involved in a dispute with the Tennessee Department of Revenue (TDOR) regarding sales business tax audits over a period of several years. AEM has challenged the assessment of the business tax. With respect to certain issues, AEM and the TDOR filed competing Partial Motions for Summary Judgment with the Chancery Court. On August 2, 2013, the Chancery Court granted the TDOR's Partial Motion for Summary Judgment and denied AEM's Partial Motion for Summary Judgment and set February 1, 2014 as the date by which AEM and the TDOR will set a date for filing any cross motions for partial summary judgment as to the remaining issue. The Company anticipates a decision by the Chancery Court on the remaining issue in fiscal 2014. The cumulative assessment is expected to be approximately $11 million for the period December 2002 through December 2013, including tax, interest and penalties. We have accrued what we believe to be an adequate amount for the anticipated resolution of this matter and we will continue to review and if appropriate adjust this reserve until this matter is resolved. We continue to believe the final outcome will not have a material adverse effect on our financial condition, results of operations or cash flows.
	We are a party to other litigation and environmental-related matters or claims that have arisen in the ordinary course of our business. While the results of such litigation and response actions to such environmental-related matters or claims cannot be predicted with certainty, we continue to believe the final outcome of such litigation and matters or claims will not have a material adverse effect on our financial condition, results of operations or cash flows.
	Purchase Commitments
	AEH has commitments to purchase physical quantities of natural gas under contracts indexed to the forward NYMEX strip or fixed price contracts. At December 31, 2013, AEH was committed to purchase 91.1 Bcf within one year, 14.8 Bcf within one to three years and 0.9 Bcf after three years under indexed contracts. AEH is committed to purchase 4.4 Bcf within one year under fixed price contracts with prices ranging from $3.60 to $6.36 per Mcf. Purchases under these contracts totaled $350.2 million and $289.5 million for the three months ended December 31, 2013 and 2012.
	Our natural gas distribution divisions maintain supply contracts with several vendors that generally cover a period of up to one year. Commitments for estimated base gas volumes are established under these contracts on a monthly basis at contractually negotiated prices. Commitments for incremental daily purchases are made as necessary during the month in accordance with the terms of the individual contract.
	Our nonregulated segment maintains long-term contracts related to storage and transportation. The estimated contractual demand fees for contracted storage and transportation under these contracts are detailed in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. There were no material changes to the estimated storage and transportation fees for the three months ended December 31, 2013.
	Regulatory Matters
	Various regulatory agencies, including the SEC and the Commodities Futures Trading Commission, continue to adopt regulations implementing many of the provisions of the Dodd-Frank Act of 2010. We continue to enact new procedures and modify existing business practices and contractual arrangements to comply with such regulations. Additional rulemakings are pending which we believe will result in new reporting and disclosure obligations. The costs associated with hedging certain risks inherent in our business may be further increased when these expected additional regulations are adopted.
	As of December 31, 2013, rate cases were in progress in our Colorado, Kentucky and West Texas service areas, annual rate filing mechanisms were in progress in Louisiana and Mississippi and an infrastructure program filing and ad valorem filing were in progress in Kansas. These regulatory proceedings are discussed in further detail below in Management’s Discussion and Analysis — Recent Ratemaking Developments.

Financial_Instruments

Financial Instruments	3 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Financial Instruments	'
	Financial Instruments
	We use financial instruments to mitigate commodity price risk and interest rate risk. The objectives and strategies for using financial instruments have been tailored to our regulated and nonregulated businesses. The accounting for these financial instruments is fully described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. During the three months ended December 31, 2013 there were no changes in our objectives, strategies and accounting for these financial instruments. Currently, we utilize financial instruments in our natural gas distribution and nonregulated segments. We currently do not manage commodity price risk with financial instruments in our regulated transmission and storage segment.
	Our financial instruments do not contain any credit-risk-related or other contingent features that could cause payments to be accelerated when our financial instruments are in net liability positions.
	Regulated Commodity Risk Management Activities
	Although our purchased gas cost adjustment mechanisms essentially insulate our natural gas distribution segment from commodity price risk, our customers are exposed to the effects of volatile natural gas prices. We manage this exposure through a combination of physical storage, fixed-price forward contracts and financial instruments, primarily over-the-counter swap and option contracts, in an effort to minimize the impact of natural gas price volatility on our customers during the winter heating season.
	Our natural gas distribution gas supply department is responsible for executing this segment’s commodity risk management activities in conformity with regulatory requirements. In jurisdictions where we are permitted to mitigate commodity price risk through financial instruments, the relevant regulatory authorities may establish the level of heating season gas purchases that can be hedged. Historically, if the regulatory authority does not establish this level, we seek to hedge between 25 and 50 percent of anticipated heating season gas purchases using financial instruments. For the 2013-2014 heating season (generally October through March), in the jurisdictions where we are permitted to utilize financial instruments, we anticipate hedging approximately 39 percent, or 24.8 Bcf of the winter flowing gas requirements. We have not designated these financial instruments as hedges for accounting purposes.
	The costs associated with and the gains and losses arising from the use of financial instruments to mitigate commodity price risk are included in our purchased gas cost adjustment mechanisms in accordance with regulatory requirements. Therefore, changes in the fair value of these financial instruments are initially recorded as a component of deferred gas costs and recognized in the consolidated statement of income as a component of purchased gas cost when the related costs are recovered through our rates and recognized in revenue in accordance with applicable authoritative accounting guidance. Accordingly, there is no earnings impact on our natural gas distribution segment as a result of the use of financial instruments.
	Nonregulated Commodity Risk Management Activities
	Our nonregulated operations aggregate and purchase gas supply, arrange transportation and/or storage logistics and ultimately deliver gas to our customers at competitive prices. To provide these services, we utilize proprietary and customer-owned transportation and storage assets to provide the various services our customers request. In an effort to offset the demand fees paid to contract for storage capacity and to maximize the value of this capacity, AEH sells financial instruments to earn a gross profit margin through the arbitrage of pricing differences in various locations and by recognizing pricing differences that occur over time.
	As a result of these activities, our nonregulated segment is exposed to risks associated with changes in the market price of natural gas. We manage our exposure to such risks through a combination of physical storage and financial instruments, including futures, over-the-counter and exchange traded options and swap contracts with counterparties. Future contracts provide the right, but not the obligation, to buy or sell the commodity at a fixed price. Option contracts provide the right, but not the requirement, to buy or sell the commodity at a fixed price. Swap contracts require receipt of payment for the commodity based on the difference between a fixed price and the market price on the settlement date.
	We use financial instruments, designated as cash flow hedges of anticipated purchases and sales at index prices, to mitigate the commodity price risk in our nonregulated operations associated with deliveries under fixed-priced forward contracts to deliver gas to customers. These financial instruments have maturity dates ranging from one to 52 months. We use financial instruments, designated as fair value hedges, to hedge our natural gas inventory used in asset optimization activities in our nonregulated segment.
	Our nonregulated operations also use storage swaps and futures to capture additional storage arbitrage opportunities that arise subsequent to the execution of the original fair value hedge associated with our physical natural gas inventory, basis swaps to insulate and protect the economic value of our fixed price and storage books and various over-the-counter and exchange-traded options. These financial instruments have not been designated as hedges for accounting purposes.
	Interest Rate Risk Management Activities
	We periodically manage interest rate risk by entering into financial instruments to fix the Treasury yield component of the interest cost associated with anticipated financings.
	As of December 31, 2013, we have forward starting interest rate swaps to fix the Treasury yield component associated with the anticipated issuance of $500 million and $250 million unsecured senior notes in fiscal 2015 and fiscal 2017, which we designated as cash flow hedges at the time the agreements were executed. Accordingly, unrealized gains and losses associated with the forward starting interest rate swaps are being recorded as a component of accumulated other comprehensive income (loss). When the forward starting interest rate swaps settle, the realized gain or loss will be recorded as a component of accumulated other comprehensive income (loss) and recognized as a component of interest expense over the life of the related financing arrangement. Hedge ineffectiveness to the extent incurred is reported as a component of interest expense.
	In prior years, we entered into Treasury lock agreements to fix the Treasury yield component of the interest cost of financing various issuances of long-term debt and senior notes. The gains and losses realized upon settlement of these Treasury locks were recorded as a component of accumulated other comprehensive income (loss) when they were settled and are being recognized as a component of interest expense over the life of the associated notes from the date of settlement. As of December 31, 2013, the remaining amortization periods for the settled Treasury locks extend through fiscal 2043.

	Quantitative Disclosures Related to Financial Instruments
	The following tables present detailed information concerning the impact of financial instruments on our condensed consolidated balance sheet and income statements.
	As of December 31, 2013, our financial instruments were comprised of both long and short commodity positions. A long position is a contract to purchase the commodity, while a short position is a contract to sell the commodity. As of December 31, 2013, we had net long/(short) commodity contracts outstanding in the following quantities:


	Contract Type		Hedge Designation		Natural Gas			Nonregulated
					Distribution
					Quantity (MMcf)
	Commodity contracts		Fair Value		—			(18,585	)

			Cash Flow		—			31,500

			Not designated		15,796			59,095

					15,796			72,010

	Financial Instruments on the Balance Sheet
	The following tables present the fair value and balance sheet classification of our financial instruments by operating segment as of December 31, 2013 and September 30, 2013. The gross amounts of recognized assets and liabilities are netted within our unaudited Condensed Consolidated Balance Sheets to the extent that we have netting arrangements with the counterparties.


				Natural Gas Distribution								Nonregulated
		Balance Sheet Location		Assets				Liabilities				Assets				Liabilities
				(In thousands)
	31-Dec-13
	Designated As Hedges:
	Commodity contracts	Other current assets /		$	—			$	—			$	12,238			$	(12,089	)
		Other current liabilities
	Interest rate contracts	Other current assets /		83,578				—				—				—
		Other current liabilities
	Commodity contracts	Deferred charges and other assets /		—				—				783				(983		)
		Deferred credits and other liabilities
	Interest rate contracts	Deferred charges and other assets /		44,833				—				—				—
		Deferred credits and other liabilities
	Total			128,411				—				13,021				(13,072		)

	Not Designated As Hedges:
	Commodity contracts	Other current assets /		5,356				(36		)		55,288				(63,144		)
		Other current liabilities
	Commodity contracts	Deferred charges and other assets /		1,045				—				35,740				(32,926		)
		Deferred credits and other liabilities
	Total			6,401				(36		)		91,028				(96,070		)

	Gross Financial Instruments			134,812				(36		)		104,049				(109,142		)

	Gross Amounts Offset on Consolidated Balance Sheet:
	Contract netting			—				—				(101,435		)		101,435

Net Financial Instruments			134,812				(36		)		2,614				(7,707		)

Cash collateral			—				—				9,001				7,707

Net Assets/Liabilities from Risk Management Activities			$	134,812			$	(36	)		$	11,615			$	—





			Natural Gas Distribution								Nonregulated
	Balance Sheet Location		Assets				Liabilities				Assets				Liabilities
			(In thousands)
30-Sep-13
Designated As Hedges:
Commodity contracts	Other current assets /		$	—			$	—			$	9,094			$	(12,173	)
	Other current liabilities
Commodity contracts	Deferred charges and other assets /		—				—				416				(1,639		)
	Deferred credits and other liabilities
Interest rate contracts	Deferred charges and other assets /		107,512				—				—				—
	Deferred credits and other liabilities
Total			107,512				—				9,510				(13,812		)

Not Designated As Hedges:
Commodity contracts	Other current assets /		1,837				(1,543		)		65,388				(70,876		)
	Other current liabilities
Commodity contracts	Deferred charges and other assets /		1,842				—				40,982				(45,892		)
	Deferred credits and other liabilities
Total			3,679				(1,543		)		106,370				(116,768		)

Gross Financial Instruments			111,191				(1,543		)		115,880				(130,580		)

Gross Amounts Offset on Consolidated Balance Sheet:
Contract netting			—				—				(115,875		)		115,875

Net Financial Instruments			111,191				(1,543		)		5				(14,705		)

Cash collateral			—				—				10,124				14,705

Net Assets/Liabilities from Risk Management Activities			$	111,191			$	(1,543	)		$	10,129			$	—


Impact of Financial Instruments on the Income Statement
Hedge ineffectiveness for our nonregulated segment is recorded as a component of unrealized gross profit and primarily results from differences in the location and timing of the derivative instrument and the hedged item. Hedge ineffectiveness could materially affect our results of operations for the reported period. For the three months ended December 31, 2013 and 2012 we recognized a gain arising from fair value and cash flow hedge ineffectiveness of $5.1 million and $16.1 million. Additional information regarding ineffectiveness recognized in the income statement is included in the tables below.

Fair Value Hedges
The impact of our nonregulated commodity contracts designated as fair value hedges and the related hedged item on our condensed consolidated income statement for the three months ended December 31, 2013 and 2012 is presented below.


	Three Months Ended
	December 31
	2013				2012
	(In thousands)
Commodity contracts	$	(8,561	)		$	7,314

Fair value adjustment for natural gas inventory designated as the hedged item	13,779				8,818

Total decrease in purchased gas cost	$	5,218			$	16,132

The (increase) decrease in purchased gas cost is comprised of the following:
Basis ineffectiveness	$	(620	)		$	(241	)
Timing ineffectiveness	5,838				16,373

	$	5,218			$	16,132




Basis ineffectiveness arises from natural gas market price differences between the locations of the hedged inventory and the delivery location specified in the hedge instruments. Timing ineffectiveness arises due to changes in the difference between the spot price and the futures price, as well as the difference between the timing of the settlement of the futures and the valuation of the underlying physical commodity. As the commodity contract nears the settlement date, spot-to-forward price differences should converge, which should reduce or eliminate the impact of this ineffectiveness on purchased gas cost. To the extent that the Company’s natural gas inventory does not qualify as a hedged item in a fair-value hedge, or has not been designated as such, the natural gas inventory is valued at the lower of cost or market.

Cash Flow Hedges
The impact of cash flow hedges on our condensed consolidated income statements for the three months ended December 31, 2013 and 2012 is presented below. Note that this presentation does not reflect the financial impact arising from the hedged physical transaction. Therefore, this presentation is not indicative of the economic gross profit we realized when the underlying physical and financial transactions were settled.


	Three Months Ended December 31, 2013
	Natural				Nonregulated				Consolidated
	Gas
	Distribution
	(In thousands)
Loss reclassified from AOCI for effective portion of commodity contracts	$	—			$	(2,609	)		$	(2,609	)

Loss arising from ineffective portion of commodity contracts	—				(119		)		(119		)

Total impact on purchased gas cost	—				(2,728		)		(2,728		)

Net loss on settled interest rate agreements reclassified from AOCI into interest expense	(1,058		)		—				(1,058		)

Total Impact from Cash Flow Hedges	$	(1,058	)		$	(2,728	)		$	(3,786	)


	Three Months Ended December 31, 2012
	Natural				Nonregulated				Consolidated
	Gas
	Distribution
	(In thousands)
Loss reclassified from AOCI for effective portion of commodity contracts	$	—			$	(5,160	)		$	(5,160	)

Loss arising from ineffective portion of commodity contracts	—				(19		)		(19		)

Total impact on purchased gas cost	—				(5,179		)		(5,179		)

Net loss on settled interest rate agreements reclassified from AOCI into interest expense	(502		)		—				(502		)

Total Impact from Cash Flow Hedges	$	(502	)		$	(5,179	)		$	(5,681	)







The following table summarizes the gains and losses arising from hedging transactions that were recognized as a component of other comprehensive income (loss), net of taxes, for the three months ended December 31, 2013 and 2012. The amounts included in the table below exclude gains and losses arising from ineffectiveness because those amounts are immediately recognized in the income statement as incurred.


	Three Months Ended
	December 31
	2013				2012
	(In thousands)
Increase (decrease) in fair value:
Interest rate agreements	$	13,270			$	11,945

Forward commodity contracts	6,226				(3,513		)

Recognition of (gains) losses in earnings due to settlements:
Interest rate agreements	672				319

Forward commodity contracts	1,592				3,148

Total other comprehensive income from hedging, net of tax(1)	$	21,760			$	11,899



(1)	Utilizing an income tax rate ranging from 37 percent to 39 percent based on the effective rates in each taxing jurisdiction.
Deferred gains (losses) recorded in accumulated other comprehensive income (AOCI) associated with our interest rate agreements are recognized in earnings as they are amortized over the terms of the underlying debt instruments, while deferred gains (losses) associated with commodity contracts are recognized in earnings upon settlement. The following amounts, net of deferred taxes, represent the expected recognition in earnings of the deferred gains (losses) recorded in AOCI associated with our financial instruments, based upon the fair values of these financial instruments as of December 31, 2013. However, the table below does not include the expected recognition in earnings of our outstanding interest rate agreements as those instruments have not yet settled.


	Interest Rate				Commodity				Total
	Agreements				Contracts
	(In thousands)
Next twelve months	$	(2,343	)		$	3,458			$	1,115

Thereafter	(27,350		)		(116		)		(27,466		)
Total(1)	$	(29,693	)		$	3,342			$	(26,351	)



(1)	Utilizing an income tax rate ranging from 37 percent to 39 percent based on the effective rates in each taxing jurisdiction.

Financial Instruments Not Designated as Hedges
The impact of financial instruments that have not been designated as hedges on our condensed consolidated income statements for the three months ended December 31, 2013 and 2012 was a decrease in gross profit of $0.8 million and $0.1 million. Note that this presentation does not reflect the expected gains or losses arising from the underlying physical transactions associated with these financial instruments. Therefore, this presentation is not indicative of the economic gross profit we realized when the underlying physical and financial transactions were settled.
As discussed above, financial instruments used in our natural gas distribution segment are not designated as hedges. However, there is no earnings impact on our natural gas distribution segment as a result of the use of these financial instruments because the gains and losses arising from the use of these financial instruments are recognized in the consolidated statement of income as a component of purchased gas cost when the related costs are recovered through our rates and recognized in revenue. Accordingly, the impact of these financial instruments is excluded from this presentation.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income	3 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Accumulated Other Comprehensive Income	'
	Accumulated Other Comprehensive Income
	We record deferred gains (losses) in accumulated other comprehensive income (AOCI) related to available-for-sale securities, interest rate agreement cash flow hedges and commodity contract cash flow hedges. Deferred gains (losses) for our available-for-sale securities and commodity contract cash flow hedges are recognized in earnings upon settlement, while deferred gains (losses) related to our interest rate agreement cash flow hedges are recognized in earnings as they are amortized. The following tables provide the components of our accumulated other comprehensive income (loss) balances, net of the related tax effects allocated to each component of other comprehensive income.


		Available-				Interest			Commodity			Total
		for-Sale				Rate			Contracts
		Securities				Agreement			Cash Flow
						Cash Flow			Hedges
						Hedges
		(In thousands)
	30-Sep-13	$	5,448			$	37,906		$	(4,476	)	$	38,878

	Other comprehensive income before reclassifications	2,394				13,270			6,226			21,890

	Amounts reclassified from accumulated other comprehensive income	—				672			1,592			2,264

	Net current-period other comprehensive income	2,394				13,942			7,818			24,154

	31-Dec-13	$	7,842			$	51,848		$	3,342		$	63,032




		Available-				Interest			Commodity			Total
		for-Sale				Rate			Contracts
		Securities				Agreement			Cash Flow
						Cash Flow			Hedges
						Hedges
		(In thousands)
	30-Sep-12	$	5,661			$	(44,273	)	$	(8,995	)	$	(47,607	)

	Other comprehensive income before reclassifications	(373		)		11,945			(3,513		)	8,059

	Amounts reclassified from accumulated other comprehensive income	—				319			3,148			3,467

	Net current-period other comprehensive income	(373		)		12,264			(365		)	11,526

	31-Dec-12	$	5,288			$	(32,009	)	$	(9,360	)	$	(36,081	)


	The following tables detail reclassifications out of AOCI for the three months ended December 31, 2013 and 2012. Amounts in parentheses below indicate decreases to net income in the statement of income.


		Three Months Ended December 31, 2013
	Accumulated Other Comprehensive Income Components	Amount Reclassified from				Affected Line Item in the
		Accumulated Other				Statement of Income
		Comprehensive Income
		(In thousands)
	Cash flow hedges
	Interest rate agreements	$	(1,058	)		Interest charges
	Commodity contracts	(2,609		)		Purchased gas cost
		(3,667		)		Total before tax
		1,403				Tax benefit

	Total reclassifications	$	(2,264	)		Net of tax


		Three Months Ended December 31, 2012
	Accumulated Other Comprehensive Income Components	Amount Reclassified from				Affected Line Item in the
		Accumulated Other				Statement of Income
		Comprehensive Income
		(In thousands)
	Cash flow hedges
Interest rate agreements	$	(502	)		Interest charges
Commodity contracts	(5,160		)		Purchased gas cost
	(5,662		)		Total before tax
	2,195				Tax benefit

Total reclassifications	$	(3,467	)		Net of tax

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We record cash and cash equivalents, accounts receivable and accounts payable at carrying value, which substantially approximates fair value due to the short-term nature of these assets and liabilities. For other financial assets and liabilities, we primarily use quoted market prices and other observable market pricing information to minimize the use of unobservable pricing inputs in our measurements when determining fair value. The methods used to determine fair value for our assets and liabilities are fully described in Note 2 to the financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. During the three months ended December 31, 2013, there were no changes in these methods.
	Fair value measurements also apply to the valuation of our pension and postretirement plan assets. Current accounting guidance requires employers to annually disclose information about fair value measurements of the assets of a defined benefit pension or other postretirement plan. The fair value of these assets is presented in Note 6 to the financial statements in our Annual Report on Form 10-K for the fiscal year ending September 30, 2013.
	Quantitative Disclosures
	Financial Instruments
	The classification of our fair value measurements requires judgment regarding the degree to which market data are observable or corroborated by observable market data. Authoritative accounting literature establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1), with the lowest priority given to unobservable inputs (Level 3). The following tables summarize, by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2013 and September 30, 2013. Assets and liabilities are categorized in their entirety based on the lowest level of input that is significant to the fair value measurement.


		Quoted				Significant			Significant			Netting and				31-Dec-13
		Prices in				Other			Other			Cash
		Active				Observable			Unobservable			Collateral(2)
		Markets				Inputs			Inputs
		(Level 1)				(Level 2)(1)			(Level 3)
		(In thousands)
	Assets:
	Financial instruments
	Natural gas distribution segment	$	—			$	134,812		$	—		$	—			$	134,812

	Nonregulated segment	184				103,865			—			(92,434		)		11,615

	Total financial instruments	184				238,677			—			(92,434		)		146,427

	Hedged portion of gas stored underground	76,151				—			—			—				76,151

	Available-for-sale securities
	Money market funds	—				3,376			—			—				3,376

	Registered investment companies	44,000				—			—			—				44,000

	Bonds	—				28,014			—			—				28,014

	Total available-for-sale securities	44,000				31,390			—			—				75,390

	Total assets	$	120,335			$	270,067		$	—		$	(92,434	)		$	297,968

	Liabilities:
	Financial instruments
	Natural gas distribution segment	$	—			$	36		$	—		$	—			$	36

	Nonregulated segment	1,172				107,970			—			(109,142		)		—

	Total liabilities	$	1,172			$	108,006		$	—		$	(109,142	)		$	36



		Quoted				Significant			Significant			Netting and				30-Sep-13
		Prices in				Other			Other			Cash
		Active				Observable			Unobservable			Collateral(3)
		Markets				Inputs			Inputs
		(Level 1)				(Level 2)(1)			(Level 3)
		(In thousands)
	Assets:
	Financial instruments
	Natural gas distribution segment	$	—			$	111,191		$	—		$	—			$	111,191

	Nonregulated segment	745				115,135			—			(105,751		)		10,129

	Total financial instruments	745				226,326			—			(105,751		)		121,320

	Hedged portion of gas stored underground	44,758				—			—			—				44,758

	Available-for-sale securities
	Money market funds	—				4,428			—			—				4,428

Registered investment companies	40,094				—			—			—				40,094

Bonds	—				28,160			—			—				28,160

Total available-for-sale securities	40,094				32,588			—			—				72,682

Total assets	$	85,597			$	258,914		$	—		$	(105,751	)		$	238,760

Liabilities:
Financial instruments
Natural gas distribution segment	$	—			$	1,543		$	—		$	—			$	1,543

Nonregulated segment	158				130,422			—			(130,580		)		—

Total liabilities	$	158			$	131,965		$	—		$	(130,580	)		$	1,543



(1)	Our Level 2 measurements consist of over-the-counter options and swaps which are valued using a market-based approach in which observable market prices are adjusted for criteria specific to each instrument, such as the strike price, notional amount or basis differences, municipal and corporate bonds which are valued based on the most recent available quoted market prices and money market funds which are valued at cost.

(2)	This column reflects adjustments to our gross financial instrument assets and liabilities to reflect netting permitted under our master netting agreements and the relevant authoritative accounting literature. In addition, as of December 31, 2013, we had $16.7 million of cash held in margin accounts to collateralize certain financial instruments. Of this amount, $7.7 million was used to offset current risk management liabilities under master netting arrangements and the remaining $9.0 million is classified as current risk management assets.

(3)	This column reflects adjustments to our gross financial instrument assets and liabilities to reflect netting permitted under our master netting agreements and the relevant authoritative accounting literature. In addition, as of September 30, 2013 we had $24.8 million of cash held in margin accounts to collateralize certain financial instruments. Of this amount, $14.7 million was used to offset current and noncurrent risk management liabilities under master netting arrangements and the remaining $10.1 million is classified as current risk management assets.

Available-for-sale securities are comprised of the following:


	Amortized				Gross			Gross			Fair
	Cost				Unrealized			Unrealized			Value
					Gain			Loss
	(In thousands)
As of December 31, 2013
Domestic equity mutual funds	$	27,129			$	10,575		$	—		$	37,704

Foreign equity mutual funds	4,536				1,760			—			6,296

Bonds	27,860				176			(22		)	28,014

Money market funds	3,376				—			—			3,376

	$	62,901			$	12,511		$	(22	)	$	75,390

As of September 30, 2013
Domestic equity mutual funds	$	27,043			$	7,476		$	(23	)	$	34,496

Foreign equity mutual funds	4,536				1,062			—			5,598

Bonds	28,016				168			(24		)	28,160

Money market funds	4,428				—			—			4,428

	$	64,023			$	8,706		$	(47	)	$	72,682

At December 31, 2013 and September 30, 2013, our available-for-sale securities included $47.4 million and $44.5 million related to assets held in separate rabbi trusts for our supplemental executive benefit plans. At December 31, 2013, we maintained investments in bonds that have contractual maturity dates ranging from January 2014 through December 2019.
These securities are reported at market value with unrealized gains and losses shown as a component of accumulated other comprehensive income (loss). We regularly evaluate the performance of these investments on a fund by fund basis for impairment, taking into consideration the fund’s purpose, volatility and current returns. If a determination is made that a decline in fair value is other than temporary, the related fund is written down to its estimated fair value and the other-than-temporary impairment is recognized in the income statement.
Other Fair Value Measures
Our debt is recorded at carrying value. The fair value of our debt is determined using third party market value quotations, which are considered Level 1 fair value measurements for debt instruments with a recent, observable trade or Level 2 fair value measurements for debt instruments where fair value is determined using the most recent available quoted market price. The following table presents the carrying value and fair value of our debt as of December 31, 2013:


	31-Dec-13			30-Sep-13
	(In thousands)
Carrying Amount	$	2,460,000		$	2,460,000

Fair Value	$	2,661,390		$	2,676,487

Concentration_of_Credit_Risk

Concentration of Credit Risk	3 Months Ended
Concentration of Credit Risk	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
Concentration of Credit Risk	'
	Concentration of Credit Risk
	Information regarding our concentration of credit risk is disclosed in Note 15 to the financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. During the three months ended December 31, 2013, there were no material changes in our concentration of credit risk.

Discontinued_Operations

Discontinued Operations	3 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Discontinued Operations	'
	Discontinued Operations
	On April 1, 2013, we completed the sale of substantially all of our natural gas distribution assets and certain related nonregulated assets located in Georgia to Liberty Energy (Georgia) Corp., an affiliate of Algonquin Power & Utilities Corp. for a cash price of approximately $153 million. In connection with the sale, we recognized a net of tax gain of $5.3 million.
	For the three months ended December 31, 2012, net income from discontinued operations includes the operating results of our Georgia operations. As required under generally accepted accounting principles, the operating results from our discontinued Georgia operations have been aggregated and reported on the condensed consolidated statements of income as income from discontinued operations, net of income tax. Expenses related to general corporate overhead and interest expense allocated to their operations are not included in discontinued operations.
	The table below sets forth statement of income data related to discontinued operations. At December 31, 2013 and September 30, 2013 we did not have any assets or liabilities held for sale.


		Three Months Ended
		December 31
		2013		2012
		(In thousands)
	Operating revenues	$	—	$	16,284

	Purchased gas cost	—		8,967

	Gross profit	—		7,317

	Operating expenses	—		2,820

	Operating income	—		4,497

	Other nonoperating income	—		348

	Income from discontinued operations before income taxes	—		4,845

	Income tax expense	—		1,728

	Net income from discontinued operations	$	—	$	3,117

Accounting_Policies_Policy

Accounting Policies (Policy)	3 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Regulatory assets and liabilities	'Regulatory assets and liabilitiesAccounting principles generally accepted in the United States require cost-based, rate-regulated entities that meet certain criteria to reflect the authorized recovery of costs due to regulatory decisions in their financial statements. As a result, certain costs are permitted to be capitalized rather than expensed because they can be recovered through rates. We record certain costs as regulatory assets when future recovery through customer rates is considered probable. Regulatory liabilities are recorded when it is probable that revenues will be reduced for amounts that will be credited to customers through the ratemaking process. Substantially all of our regulatory assets are recorded as a component of deferred charges and other assets and substantially all of our regulatory liabilities are recorded as a component of deferred credits and other liabilities. Deferred gas costs are recorded either in other current assets or liabilities and the regulatory cost of removal obligation is reported separately.
Fair Value Measurements	'
	Fair Value Measurements
	We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We record cash and cash equivalents, accounts receivable and accounts payable at carrying value, which substantially approximates fair value due to the short-term nature of these assets and liabilities. For other financial assets and liabilities, we primarily use quoted market prices and other observable market pricing information to minimize the use of unobservable pricing inputs in our measurements when determining fair value. The methods used to determine fair value for our assets and liabilities are fully described in Note 2 to the financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. During the three months ended December 31, 2013, there were no changes in these methods.
Earnings Per Share	'
	We use the two-class method of computing earnings per share because we have participating securities in the form of non-vested restricted stock units with a nonforfeitable right to dividend equivalents, for which vesting is predicated solely on the passage of time. The calculation of earnings per share using the two-class method excludes income attributable to these participating securities from the numerator and excludes the dilutive impact of those shares from the denominator.
Segment Reporting	'
	Segment Information
	As discussed in Note 1 above, we operate the Company through the following three segments:

	•	The natural gas distribution segment, which includes our regulated natural gas distribution and related sales operations,

	•	The regulated transmission and storage segment, which includes the regulated pipeline and storage operations of our Atmos Pipeline — Texas Division and

	•	The nonregulated segment, which is comprised of our nonregulated natural gas management, nonregulated natural gas transmission, storage and other services.

	Our determination of reportable segments considers the strategic operating units under which we manage sales of various products and services to customers in differing regulatory environments. Although our natural gas distribution segment operations are geographically dispersed, they are reported as a single segment as each natural gas distribution division has similar economic characteristics. The accounting policies of the segments are the same as those described in the summary of significant accounting policies found in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013. We evaluate performance based on net income or loss of the respective operating units.

Unaudited_Financial_Informatio1

Unaudited Financial Information (Table)	3 Months Ended
	Dec. 31, 2013
Regulatory Assets And Liabilities Table [Abstract]	'
Regulatory assets and liabilities table	'
	Significant regulatory assets and liabilities as of December 31, 2013 and September 30, 2013 included the following:


		December 31,		September 30,
		2013		2013
		(In thousands)
	Regulatory assets:
	Pension and postretirement benefit costs(1)	$	180,512	$	187,977

	Merger and integration costs, net	5,120		5,250

	Deferred gas costs	8,630		15,152

	Regulatory cost of removal asset	9,998		10,008

	Rate case costs	5,806		6,329

	Texas Rule 8.209(2)	31,838		30,364

	APT annual adjustment mechanism	5,773		5,853

	Recoverable loss on reacquired debt	20,796		21,435

	Other	4,480		4,380

		$	272,953	$	286,748

	Regulatory liabilities:
	Deferred gas costs	$	50,094	$	16,481

	Deferred franchise fees	4,792		1,689

	Regulatory cost of removal obligation	425,028		427,524

	Other	9,788		7,887

		$	489,702	$	453,581



	(1)	Includes $18.2 million and $17.4 million of pension and postretirement expense deferred pursuant to regulatory authorization.

	(2)	Texas Rule 8.209 is a Railroad Commission rule that allows for the deferral of all expenses associated with capital expenditures incurred pursuant to this rule, including the recording of interest on the deferred expenses until the next rate proceeding (rate case or annual rate filing), at which time investment and costs would be recovered through base rates.

Segment_Information_Table

Segment Information (Table)	3 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment	'
	Income statements for the three month periods ended December 31, 2013 and 2012 by segment are presented in the following tables:


		Three Months Ended December 31, 2013
		Natural				Regulated				Nonregulated			Eliminations				Consolidated
		Gas				Transmission
		Distribution				and Storage
		(In thousands)
	Operating revenues from external parties	$	842,432			$	21,170			$	391,546		$	—			$	1,255,148

	Intersegment revenues	1,433				50,171				56,175			(107,779		)		—

		843,865				71,341				447,721			(107,779		)		1,255,148

	Purchased gas cost	544,694				—				429,155			(107,658		)		866,191

	Gross profit	299,171				71,341				18,566			(121		)		388,957

	Operating expenses
	Operation and maintenance	89,663				17,300				8,915			(121		)		115,757

	Depreciation and amortization	49,551				9,786				1,132			—				60,469

	Taxes, other than income	37,084				4,663				264			—				42,011

	Total operating expenses	176,298				31,749				10,311			(121		)		218,237

	Operating income	122,873				39,592				8,255			—				170,720

	Miscellaneous income (expense)	(471		)		(1,181		)		324			(804		)		(2,132		)

	Interest charges	23,325				8,957				637			(804		)		32,115

	Income before income taxes	99,077				29,454				7,942			—				136,473

	Income tax expense	36,320				10,008				3,129			—				49,457

	Net income	$	62,757			$	19,446			$	4,813		$	—			$	87,016

	Capital expenditures	$	127,506			$	52,921			$	140		$	—			$	180,567






		Three Months Ended December 31, 2012
		Natural				Regulated				Nonregulated			Eliminations				Consolidated
		Gas				Transmission
		Distribution				and Storage
		(In thousands)
	Operating revenues from external parties	$	665,549			$	18,699			$	349,907		$	—			$	1,034,155

	Intersegment revenues	1,238				41,982				49,987			(93,207		)		—

		666,787				60,681				399,894			(93,207		)		1,034,155

	Purchased gas cost	387,156				—				377,435			(92,798		)		671,793

	Gross profit	279,631				60,681				22,459			(409		)		362,362

	Operating expenses
	Operation and maintenance	83,736				16,320				6,882			(411		)		106,527

Depreciation and amortization	50,060				8,390				1,129			—				59,579

Taxes, other than income	36,751				3,949				634			—				41,334

Total operating expenses	170,547				28,659				8,645			(411		)		207,440

Operating income	109,084				32,022				13,814			2				154,922

Miscellaneous income (expense)	(131		)		(127		)		1,667			(711		)		698

Interest charges	23,563				6,871				797			(709		)		30,522

Income from continuing operations before income taxes	85,390				25,024				14,684			—				125,098

Income tax expense	32,297				8,919				6,534			—				47,750

Income from continuing operations	53,093				16,105				8,150			—				77,348

Income from discontinued operations, net of tax	3,117				—				—			—				3,117

Net income	$	56,210			$	16,105			$	8,150		$	—			$	80,465

Capital expenditures	$	145,871			$	43,831			$	325		$	—			$	190,027













Balance sheet information at December 31, 2013 and September 30, 2013 by segment is presented in the following tables.



	31-Dec-13
	Natural				Regulated				Nonregulated			Eliminations				Consolidated
	Gas				Transmission
	Distribution				and Storage
	(In thousands)
ASSETS
Property, plant and equipment, net	$	4,799,657			$	1,293,093			$	60,213		$	—			$	6,152,963

Investment in subsidiaries	863,214				—				(2,096		)	(861,118		)		—

Current assets
Cash and cash equivalents	152,058				—				42,505			—				194,563

Assets from risk management activities	88,934				—				9,001			—				97,935

Other current assets	740,359				11,184				564,079			(308,550		)		1,007,072

Intercompany receivables	793,589				—				—			(793,589		)		—

Total current assets	1,774,940				11,184				615,585			(1,102,139		)		1,299,570

Intangible assets	—				—				110			—				110

Goodwill	574,190				132,462				34,711			—				741,363

Noncurrent assets from risk management activities	45,878				—				2,614			—				48,492

Deferred charges and other assets	345,075				20,960				7,558			—				373,593

	$	8,402,954			$	1,457,699			$	718,695		$	(1,963,257	)		$	8,616,091

CAPITALIZATION AND LIABILITIES
Shareholders’ equity	$	2,661,314			$	415,868			$	447,346		$	(863,214	)		$	2,661,314

Long-term debt	1,955,750				—				—			—				1,955,750

Total capitalization	4,617,064				415,868				447,346			(863,214		)		4,617,064

Current liabilities
Current maturities of long-term debt	500,000				—				—			—				500,000

Short-term debt	972,795				—				—			(283,000		)		689,795

Liabilities from risk management activities	36				—				—			—				36

Other current liabilities	645,433				20,429				181,262			(23,454		)		823,670

Intercompany payables	—				719,438				74,151			(793,589		)		—

Total current liabilities	2,118,264				739,867				255,413			(1,100,043		)		2,013,501

Deferred income taxes	916,095				299,819				14,138			—				1,230,052

Regulatory cost of removal obligation	356,617				—				—			—				356,617

Pension and postretirement liabilities	359,534				—				—			—				359,534

Deferred credits and other liabilities	35,380				2,145				1,798			—				39,323

	$	8,402,954			$	1,457,699			$	718,695		$	(1,963,257	)		$	8,616,091





	30-Sep-13
	Natural				Regulated				Nonregulated			Eliminations				Consolidated
	Gas				Transmission
	Distribution				and Storage
	(In thousands)
ASSETS
Property, plant and equipment, net	$	4,719,873			$	1,249,767			$	61,015		$	—			$	6,030,655

Investment in subsidiaries	831,136				—				(2,096		)	(829,040		)		—

Current assets
Cash and cash equivalents	4,237				—				61,962			—				66,199

Assets from risk management activities	1,837				—				10,129			—				11,966

Other current assets	428,366				11,709				452,126			(293,233		)		598,968

Intercompany receivables	783,738				—				—			(783,738		)		—

Total current assets	1,218,178				11,709				524,217			(1,076,971		)		677,133

Intangible assets	—				—				121			—				121

Goodwill	574,190				132,462				34,711			—				741,363

Noncurrent assets from risk management activities	109,354				—				—			—				109,354

Deferred charges and other assets	347,687				19,227				8,728			—				375,642

	$	7,800,418			$	1,413,165			$	626,696		$	(1,906,011	)		$	7,934,268

CAPITALIZATION AND LIABILITIES
Shareholders’ equity	$	2,580,409			$	396,421			$	434,715		$	(831,136	)		$	2,580,409

Long-term debt	2,455,671				—				—			—				2,455,671

Total capitalization	5,036,080				396,421				434,715			(831,136		)		5,036,080

Current liabilities
Current maturities of long-term debt	—				—				—			—				—

Short-term debt	645,984				—				—			(278,000		)		367,984

Liabilities from risk management activities	1,543				—				—			—				1,543

Other current liabilities	491,681				20,288				110,306			(13,316		)		608,959

Intercompany payables	—				712,768				70,970			(783,738		)		—

Total current liabilities	1,139,208				733,056				181,276			(1,075,054		)		978,486

Deferred income taxes	871,360				283,554				8,960			179				1,164,053

Regulatory cost of removal obligation	359,299				—				—			—				359,299

Pension and postretirement liabilities	358,787				—				—			—				358,787

Deferred credits and other liabilities	35,684				134				1,745			—				37,563

	$	7,800,418			$	1,413,165			$	626,696		$	(1,906,011	)		$	7,934,268

Earnings_Per_Share_Table

Earnings Per Share (Table)	3 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings per share table	'
	Basic and diluted earnings per share for the three months ended December 31, 2013 and 2012 are calculated as follows:


		Three Months Ended
		December 31
		2013			2012
		(In thousands, except per share amounts)
	Basic Earnings Per Share from continuing operations
	Income from continuing operations	$	87,016		$	77,348

	Less: Income from continuing operations allocated to participating securities	235			260

	Income from continuing operations available to common shareholders	$	86,781		$	77,088

	Basic weighted average shares outstanding	90,833			90,359

	Income from continuing operations per share — Basic	$	0.96		$	0.85


	Basic Earnings Per Share from discontinued operations
	Income from discontinued operations	$	—		$	3,117

	Less: Income from discontinued operations allocated to participating securities	—			10

	Income from discontinued operations available to common shareholders	$	—		$	3,107

	Basic weighted average shares outstanding	90,833			90,359

	Income from discontinued operations per share — Basic	$	—		$	0.04

	Net income per share — Basic	$	0.96		$	0.89




		Three Months Ended
		December 31
		2013			2012
		(In thousands, except per share amounts)
	Diluted Earnings Per Share from continuing operations
	Income from continuing operations available to common shareholders	$	86,781		$	77,088

	Effect of dilutive stock options and other shares	1			2

	Income from continuing operations available to common shareholders	$	86,782		$	77,090

	Basic weighted average shares outstanding	90,833			90,359

	Additional dilutive stock options and other shares	913			950

	Diluted weighted average shares outstanding	91,746			91,309

	Income from continuing operations per share — Diluted	$	0.95		$	0.85


	Diluted Earnings Per Share from discontinued operations
	Income from discontinued operations available to common shareholders	$	—		$	3,107

	Effect of dilutive stock options and other shares	—			—

	Income from discontinued operations available to common shareholders	$	—		$	3,107

	Basic weighted average shares outstanding	90,833			90,359

Additional dilutive stock options and other shares	913			950

Diluted weighted average shares outstanding	91,746			91,309

Income from discontinued operations per share — Diluted	$	—		$	0.03

Net income per share — Diluted	$	0.95		$	0.88

Debt_Table

Debt (Table)	3 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Components of Debt	'
	Long-term debt at December 31, 2013 and September 30, 2013 consisted of the following:



		31-Dec-13		30-Sep-13
		(In thousands)
	Unsecured 4.95% Senior Notes, due October 2014	$	500,000	$	500,000

	Unsecured 6.35% Senior Notes, due 2017	250,000		250,000

	Unsecured 8.50% Senior Notes, due 2019	450,000		450,000

	Unsecured 5.95% Senior Notes, due 2034	200,000		200,000

	Unsecured 5.50% Senior Notes, due 2041	400,000		400,000

	Unsecured 4.15% Senior Notes, due 2043	500,000		500,000

	Medium-term note Series A, 1995-1, 6.67%, due 2025	10,000		10,000

	Unsecured 6.75% Debentures, due 2028	150,000		150,000

	Total long-term debt	2,460,000		2,460,000

	Less:
	Original issue discount on unsecured senior notes and debentures	4,250		4,329

	Current maturities	500,000		—

		$	1,955,750	$	2,455,671

Interim_Pension_and_Other_Post1

Interim Pension and Other Postretirement Benefits (Table)	3 Months Ended
	Dec. 31, 2013
General Discussion of Pension and Other Postretirement Benefits [Abstract]	'
Components of net periodic pension cost table	'
	The components of our net periodic pension cost for our pension and other postretirement benefit plans for the three months ended December 31, 2013 and 2012 are presented in the following table. Most of these costs are recoverable through our gas distribution rates; however, a portion of these costs is capitalized into our gas distribution rate base. The remaining costs are recorded as a component of operation and maintenance expense. On October 2, 2013, due to the retirement of one of our executives, we recognized a settlement loss of $4.5 million associated with our Supplemental Executive Benefits Plan (SEBP). In association with the retirement, on October 2, 2013, we made a $16.8 million benefit payment from the SEBP.


		Three Months Ended December 31
		Pension Benefits								Other Benefits
		2013				2012				2013			2012
		(In thousands)
	Components of net periodic pension cost:
	Service cost	$	4,738			$	5,202			$	4,196		$	4,700

	Interest cost	6,824				6,025				3,988			3,241

	Expected return on assets	(5,901		)		(5,739		)		(1,292		)	(997		)
	Amortization of transition obligation	—				—				68			270

	Amortization of prior service credit	(34		)		(35		)		(363		)	(362		)
	Amortization of actuarial loss	3,932				5,561				158			1,049

	Settlement loss	4,539				—				—			—

	Net periodic pension cost	$	14,098			$	11,014			$	6,755		$	7,901




Schedule of assumptions used table text block	'
	The assumptions used to develop our net periodic pension cost for the three months ended December 31, 2013 and 2012 are as follows:


		Pension Benefits						Other Benefits
		2013			2012			2013			2012
	Discount rate	4.95	%		4.04	%		4.95	%		4.04	%
	Rate of compensation increase	3.5	%		3.5	%		N/A			N/A

	Expected return on plan assets	7.25	%		7.75	%		4.6	%		4.7	%

Financial_Instruments_Table

Financial Instruments (Table)	3 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Oustanding commodity contracts volumes table	'
	As of December 31, 2013, we had net long/(short) commodity contracts outstanding in the following quantities:


	Contract Type		Hedge Designation		Natural Gas			Nonregulated
					Distribution
					Quantity (MMcf)
	Commodity contracts		Fair Value		—			(18,585	)

			Cash Flow		—			31,500

			Not designated		15,796			59,095

					15,796			72,010

Financial instruments on the balance sheet	'


				Natural Gas Distribution								Nonregulated
		Balance Sheet Location		Assets				Liabilities				Assets				Liabilities
				(In thousands)
	30-Sep-13
	Designated As Hedges:
	Commodity contracts	Other current assets /		$	—			$	—			$	9,094			$	(12,173	)
		Other current liabilities
	Commodity contracts	Deferred charges and other assets /		—				—				416				(1,639		)
		Deferred credits and other liabilities
	Interest rate contracts	Deferred charges and other assets /		107,512				—				—				—
		Deferred credits and other liabilities
	Total			107,512				—				9,510				(13,812		)

	Not Designated As Hedges:
	Commodity contracts	Other current assets /		1,837				(1,543		)		65,388				(70,876		)
		Other current liabilities
	Commodity contracts	Deferred charges and other assets /		1,842				—				40,982				(45,892		)
		Deferred credits and other liabilities
	Total			3,679				(1,543		)		106,370				(116,768		)

	Gross Financial Instruments			111,191				(1,543		)		115,880				(130,580		)

	Gross Amounts Offset on Consolidated Balance Sheet:
	Contract netting			—				—				(115,875		)		115,875

	Net Financial Instruments			111,191				(1,543		)		5				(14,705		)

	Cash collateral			—				—				10,124				14,705

	Net Assets/Liabilities from Risk Management Activities			$	111,191			$	(1,543	)		$	10,129			$	—


	The following tables present the fair value and balance sheet classification of our financial instruments by operating segment as of December 31, 2013 and September 30, 2013. The gross amounts of recognized assets and liabilities are netted within our unaudited Condensed Consolidated Balance Sheets to the extent that we have netting arrangements with the counterparties.


				Natural Gas Distribution								Nonregulated
		Balance Sheet Location		Assets				Liabilities				Assets				Liabilities
				(In thousands)
	31-Dec-13
	Designated As Hedges:
	Commodity contracts	Other current assets /		$	—			$	—			$	12,238			$	(12,089	)
		Other current liabilities
	Interest rate contracts	Other current assets /		83,578				—				—				—
		Other current liabilities
	Commodity contracts	Deferred charges and other assets /		—				—				783				(983		)
		Deferred credits and other liabilities
	Interest rate contracts	Deferred charges and other assets /		44,833				—				—				—
		Deferred credits and other liabilities
	Total			128,411				—				13,021				(13,072		)

	Not Designated As Hedges:
	Commodity contracts	Other current assets /		5,356				(36		)		55,288				(63,144		)
		Other current liabilities
	Commodity contracts	Deferred charges and other assets /		1,045				—				35,740				(32,926		)
		Deferred credits and other liabilities
	Total			6,401				(36		)		91,028				(96,070		)

	Gross Financial Instruments			134,812				(36		)		104,049				(109,142		)

	Gross Amounts Offset on Consolidated Balance Sheet:
	Contract netting			—				—				(101,435		)		101,435

Net Financial Instruments			134,812				(36		)		2,614				(7,707		)

Cash collateral			—				—				9,001				7,707

Net Assets/Liabilities from Risk Management Activities			$	134,812			$	(36	)		$	11,615			$	—

Fair value hedges table	'
	The impact of our nonregulated commodity contracts designated as fair value hedges and the related hedged item on our condensed consolidated income statement for the three months ended December 31, 2013 and 2012 is presented below.


		Three Months Ended
		December 31
		2013				2012
		(In thousands)
	Commodity contracts	$	(8,561	)		$	7,314

	Fair value adjustment for natural gas inventory designated as the hedged item	13,779				8,818

	Total decrease in purchased gas cost	$	5,218			$	16,132

	The (increase) decrease in purchased gas cost is comprised of the following:
	Basis ineffectiveness	$	(620	)		$	(241	)
	Timing ineffectiveness	5,838				16,373

		$	5,218			$	16,132




Cash flow hedges	'
	The impact of cash flow hedges on our condensed consolidated income statements for the three months ended December 31, 2013 and 2012 is presented below. Note that this presentation does not reflect the financial impact arising from the hedged physical transaction. Therefore, this presentation is not indicative of the economic gross profit we realized when the underlying physical and financial transactions were settled.


		Three Months Ended December 31, 2013
		Natural				Nonregulated				Consolidated
		Gas
		Distribution
		(In thousands)
	Loss reclassified from AOCI for effective portion of commodity contracts	$	—			$	(2,609	)		$	(2,609	)

	Loss arising from ineffective portion of commodity contracts	—				(119		)		(119		)

	Total impact on purchased gas cost	—				(2,728		)		(2,728		)

	Net loss on settled interest rate agreements reclassified from AOCI into interest expense	(1,058		)		—				(1,058		)

	Total Impact from Cash Flow Hedges	$	(1,058	)		$	(2,728	)		$	(3,786	)


		Three Months Ended December 31, 2012
		Natural				Nonregulated				Consolidated
		Gas
		Distribution
		(In thousands)
	Loss reclassified from AOCI for effective portion of commodity contracts	$	—			$	(5,160	)		$	(5,160	)

	Loss arising from ineffective portion of commodity contracts	—				(19		)		(19		)

	Total impact on purchased gas cost	—				(5,179		)		(5,179		)

	Net loss on settled interest rate agreements reclassified from AOCI into interest expense	(502		)		—				(502		)

	Total Impact from Cash Flow Hedges	$	(502	)		$	(5,179	)		$	(5,681	)







Other comprehensive income from hedging table	'
	The following table summarizes the gains and losses arising from hedging transactions that were recognized as a component of other comprehensive income (loss), net of taxes, for the three months ended December 31, 2013 and 2012. The amounts included in the table below exclude gains and losses arising from ineffectiveness because those amounts are immediately recognized in the income statement as incurred.


		Three Months Ended
		December 31
		2013				2012
		(In thousands)
	Increase (decrease) in fair value:
	Interest rate agreements	$	13,270			$	11,945

	Forward commodity contracts	6,226				(3,513		)

	Recognition of (gains) losses in earnings due to settlements:
	Interest rate agreements	672				319

	Forward commodity contracts	1,592				3,148

	Total other comprehensive income from hedging, net of tax(1)	$	21,760			$	11,899



	(1)	Utilizing an income tax rate ranging from 37 percent to 39 percent based on the effective rates in each taxing jurisdiction.
Expected recognition in earnings of deferred gains/(losses) in AOCI table	'
	The following amounts, net of deferred taxes, represent the expected recognition in earnings of the deferred gains (losses) recorded in AOCI associated with our financial instruments, based upon the fair values of these financial instruments as of December 31, 2013. However, the table below does not include the expected recognition in earnings of our outstanding interest rate agreements as those instruments have not yet settled.


		Interest Rate				Commodity				Total
		Agreements				Contracts
		(In thousands)
	Next twelve months	$	(2,343	)		$	3,458			$	1,115

	Thereafter	(27,350		)		(116		)		(27,466		)
	Total(1)	$	(29,693	)		$	3,342			$	(26,351	)



	(1)	Utilizing an income tax rate ranging from 37 percent to 39 percent based on the effective rates in each taxing jurisdiction.

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Table)	3 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	The following tables provide the components of our accumulated other comprehensive income (loss) balances, net of the related tax effects allocated to each component of other comprehensive income.


		Available-			Interest			Commodity			Total
		for-Sale			Rate			Contracts
		Securities			Agreement			Cash Flow
					Cash Flow			Hedges
					Hedges
		(In thousands)
	30-Sep-13	$	5,448		$	37,906		$	(4,476	)	$	38,878

	Other comprehensive income before reclassifications	2,394			13,270			6,226			21,890

	Amounts reclassified from accumulated other comprehensive income	—			672			1,592			2,264

	Net current-period other comprehensive income	2,394			13,942			7,818			24,154

	31-Dec-13	$	7,842		$	51,848		$	3,342		$	63,032




		Available-			Interest			Commodity			Total
		for-Sale			Rate			Contracts
		Securities			Agreement			Cash Flow
					Cash Flow			Hedges
					Hedges
		(In thousands)
	30-Sep-12	$	5,661		$	(44,273	)	$	(8,995	)	$	(47,607	)

	Other comprehensive income before reclassifications	(373		)	11,945			(3,513		)	8,059

	Amounts reclassified from accumulated other comprehensive income	—			319			3,148			3,467

	Net current-period other comprehensive income	(373		)	12,264			(365		)	11,526

	31-Dec-12	$	5,288		$	(32,009	)	$	(9,360	)	$	(36,081	)

Reclassification out of Accumulated Other Comprehensive Income	'
	The following tables detail reclassifications out of AOCI for the three months ended December 31, 2013 and 2012. Amounts in parentheses below indicate decreases to net income in the statement of income.


		Three Months Ended December 31, 2013
	Accumulated Other Comprehensive Income Components	Amount Reclassified from			Affected Line Item in the
		Accumulated Other			Statement of Income
		Comprehensive Income
		(In thousands)
	Cash flow hedges
	Interest rate agreements	$	(1,058	)	Interest charges
	Commodity contracts	(2,609		)	Purchased gas cost
		(3,667		)	Total before tax
		1,403			Tax benefit

	Total reclassifications	$	(2,264	)	Net of tax


		Three Months Ended December 31, 2012
	Accumulated Other Comprehensive Income Components	Amount Reclassified from			Affected Line Item in the
		Accumulated Other			Statement of Income
		Comprehensive Income
		(In thousands)
	Cash flow hedges
	Interest rate agreements	$	(502	)	Interest charges
	Commodity contracts	(5,160		)	Purchased gas cost
		(5,662		)	Total before tax
		2,195			Tax benefit

	Total reclassifications	$	(3,467	)	Net of tax

Fair_Value_Measurements_Table

Fair Value Measurements (Table)	3 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair value measurements table	'
	The following tables summarize, by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2013 and September 30, 2013. Assets and liabilities are categorized in their entirety based on the lowest level of input that is significant to the fair value measurement.


		Quoted			Significant			Significant				Netting and				31-Dec-13
		Prices in			Other			Other				Cash
		Active			Observable			Unobservable				Collateral(2)
		Markets			Inputs			Inputs
		(Level 1)			(Level 2)(1)			(Level 3)
		(In thousands)
	Assets:
	Financial instruments
	Natural gas distribution segment	$	—		$	134,812		$	—			$	—			$	134,812

	Nonregulated segment	184			103,865			—				(92,434		)		11,615

	Total financial instruments	184			238,677			—				(92,434		)		146,427

	Hedged portion of gas stored underground	76,151			—			—				—				76,151

	Available-for-sale securities
	Money market funds	—			3,376			—				—				3,376

	Registered investment companies	44,000			—			—				—				44,000

	Bonds	—			28,014			—				—				28,014

	Total available-for-sale securities	44,000			31,390			—				—				75,390

	Total assets	$	120,335		$	270,067		$	—			$	(92,434	)		$	297,968

	Liabilities:
	Financial instruments
	Natural gas distribution segment	$	—		$	36		$	—			$	—			$	36

	Nonregulated segment	1,172			107,970			—				(109,142		)		—

	Total liabilities	$	1,172		$	108,006		$	—			$	(109,142	)		$	36



		Quoted			Significant			Significant				Netting and				30-Sep-13
		Prices in			Other			Other				Cash
		Active			Observable			Unobservable				Collateral(3)
		Markets			Inputs			Inputs
		(Level 1)			(Level 2)(1)			(Level 3)
		(In thousands)
	Assets:
	Financial instruments
	Natural gas distribution segment	$	—		$	111,191		$	—			$	—			$	111,191

	Nonregulated segment	745			115,135			—				(105,751		)		10,129

	Total financial instruments	745			226,326			—				(105,751		)		121,320

	Hedged portion of gas stored underground	44,758			—			—				—				44,758

	Available-for-sale securities
	Money market funds	—			4,428			—				—				4,428

	Registered investment companies	40,094			—			—				—				40,094

	Bonds	—			28,160			—				—				28,160

Total available-for-sale securities	40,094			32,588			—				—				72,682

Total assets	$	85,597		$	258,914		$	—			$	(105,751	)		$	238,760

Liabilities:
Financial instruments
Natural gas distribution segment	$	—		$	1,543		$	—			$	—			$	1,543

Nonregulated segment	158			130,422			—				(130,580		)		—

Total liabilities	$	158		$	131,965		$	—			$	(130,580	)		$	1,543



(1)	Our Level 2 measurements consist of over-the-counter options and swaps which are valued using a market-based approach in which observable market prices are adjusted for criteria specific to each instrument, such as the strike price, notional amount or basis differences, municipal and corporate bonds which are valued based on the most recent available quoted market prices and money market funds which are valued at cost.

(2)	This column reflects adjustments to our gross financial instrument assets and liabilities to reflect netting permitted under our master netting agreements and the relevant authoritative accounting literature. In addition, as of December 31, 2013, we had $16.7 million of cash held in margin accounts to collateralize certain financial instruments. Of this amount, $7.7 million was used to offset current risk management liabilities under master netting arrangements and the remaining $9.0 million is classified as current risk management assets.

(3)	This column reflects adjustments to our gross financial instrument assets and liabilities to reflect netting permitted under our master netting agreements and the relevant authoritative accounting literature. In addition, as of September 30, 2013 we had $24.8 million of cash held in margin accounts to collateralize certain financial instruments. Of this amount, $14.7 million was used to offset current and noncurrent risk management liabilities under master netting arrangements and the remaining $10.1 million is classified as current risk management assets.
Schedule of Available-for-sale Securities Reconciliation [Table Text Block]	'
	Available-for-sale securities are comprised of the following:


		Amortized			Gross			Gross				Fair
		Cost			Unrealized			Unrealized				Value
					Gain			Loss
		(In thousands)
	As of December 31, 2013
	Domestic equity mutual funds	$	27,129		$	10,575		$	—			$	37,704

	Foreign equity mutual funds	4,536			1,760			—				6,296

	Bonds	27,860			176			(22		)		28,014

	Money market funds	3,376			—			—				3,376

		$	62,901		$	12,511		$	(22	)		$	75,390

	As of September 30, 2013
	Domestic equity mutual funds	$	27,043		$	7,476		$	(23	)		$	34,496

	Foreign equity mutual funds	4,536			1,062			—				5,598

	Bonds	28,016			168			(24		)		28,160

	Money market funds	4,428			—			—				4,428

		$	64,023		$	8,706		$	(47	)		$	72,682

Other fair value measurements table	'
	The following table presents the carrying value and fair value of our debt as of December 31, 2013:


		31-Dec-13		30-Sep-13
		(In thousands)
	Carrying Amount	$	2,460,000	$	2,460,000

	Fair Value	$	2,661,390	$	2,676,487

Discontinued_Operations_Table

Discontinued Operations (Table)	3 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Discontinued operations income statement detail table	'
	The table below sets forth statement of income data related to discontinued operations. At December 31, 2013 and September 30, 2013 we did not have any assets or liabilities held for sale.


		Three Months Ended
		December 31
		2013		2012
		(In thousands)
	Operating revenues	$	—	$	16,284

	Purchased gas cost	—		8,967

	Gross profit	—		7,317

	Operating expenses	—		2,820

	Operating income	—		4,497

	Other nonoperating income	—		348

	Income from discontinued operations before income taxes	—		4,845

	Income tax expense	—		1,728

	Net income from discontinued operations	$	—	$	3,117

Nature_of_Business_Details

Nature of Business (Details)	3 Months Ended
	Dec. 31, 2013
	segment
	customers
	state
	regulated_gas_distributions_divisions
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Number of Customers, Natural Gas Distribution	3,000,000
Number of Divisions, Natural Gas Distribution	6
Number of States in which Entity Operates	8
Number of Customers, discontinued operations	64,000
Number of operating segments	3

Unaudited_Interim_Financial_In

Unaudited Interim Financial Information (Details) (USD $)	3 Months Ended
Unaudited Interim Financial Information (Details) (USD $)	Dec. 31, 2013		Sep. 30, 2013
Regulatory Asset [Line Items]	'		'
Regulatory assets	$272,953,000		$286,748,000
Regulatory Liabilities [Line Items]	'		'
Regulatory liabilities	489,702,000		453,581,000
Regulatory asset - future recoverable pension costs	18,200,000		17,400,000
Regulatory noncurrent asset, amortization period	'20		'
Deferred Gas Costs [Member]	'		'
Regulatory Liabilities [Line Items]	'		'
Regulatory liabilities	50,094,000		16,481,000
Deferred Franchise Fees [Member]	'		'
Regulatory Liabilities [Line Items]	'		'
Regulatory liabilities	4,792,000		1,689,000
Regulatory Cost of Removal Obligation [Member]	'		'
Regulatory Liabilities [Line Items]	'		'
Regulatory liabilities	425,028,000		427,524,000
Other [Member]	'		'
Regulatory Liabilities [Line Items]	'		'
Regulatory liabilities	9,788,000		7,887,000
Pension And Postretirement Benefit Costs [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	180,512,000	[1]	187,977,000	[1]
Merger And Integration Costs Net [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	5,120,000		5,250,000
Deferred Gas Costs Asset [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	8,630,000		15,152,000
Regulatory Cost of Removal Asset [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	9,998,000		10,008,000
Rate Case Costs [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	5,806,000		6,329,000
Texas 8.209 [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	31,838,000	[2]	30,364,000	[2]
APT Annual Adjustment Mechanism [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	5,773,000		5,853,000
Recoverable Loss On Reacquired Debt [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	20,796,000		21,435,000
Other [Member]	'		'
Regulatory Asset [Line Items]	'		'
Regulatory assets	$4,480,000		$4,380,000

[1]	Includes $18.2 million and $17.4 million of pension and postretirement expense deferred pursuant to regulatory authorization.
[2]	Texas Rule 8.209 is a Railroad Commission rule that allows for the deferral of all expenses associated with capital expenditures incurred pursuant to this rule, including the recording of interest on the deferred expenses until the next rate proceeding (rate case or annual rate filing), at which time investment and costs would be recovered through base rates.

Segment_Information_Details

Segment Information (Details) (USD $)	0 Months Ended	3 Months Ended
	Apr. 02, 2013	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012
	Apr. 02, 2013	segment	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012
Segment Reporting Information [Line Items]	'	'	'	'	'
Number of operating segments	'	3	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Total operating revenues	'	$1,255,148,000	$1,034,155,000	'	'
Purchased gas cost	'	866,191,000	671,793,000	'	'
Gross profit	'	388,957,000	362,362,000	'	'
Operating expenses	'	'	'	'	'
Operation and maintenance	'	115,757,000	106,527,000	'	'
Depreciation and amortization	'	60,469,000	59,579,000	'	'
Taxes, other than income	'	42,011,000	41,334,000	'	'
Total operating expenses	'	218,237,000	207,440,000	'	'
Operating income	'	170,720,000	154,922,000	'	'
Miscellaneous income (expense)	'	-2,132,000	698,000	'	'
Interest charges	'	32,115,000	30,522,000	'	'
Income (loss) before income taxes	'	136,473,000	125,098,000	'	'
Income tax expense (benefit)	'	49,457,000	47,750,000	'	'
Income (loss) from continuing operations	'	87,016,000	77,348,000	'	'
Income from discontinued operations, net of tax	'	0	3,117,000	'	'
Gain (loss) on sale of discontinued operations, net of tax	5,300,000	'	'	'	'
Net income (loss)	'	87,016,000	80,465,000	'	'
Capital expenditures	'	180,567,000	190,027,000	'	'
ASSETS	'	'	'	'	'
Net property, plant and equipment	'	6,152,963,000	'	6,030,655,000	'
Investment in subsidiaries	'	0	'	0	'
Current assets	'	'	'	'	'
Cash and cash equivalents	'	194,563,000	124,601,000	66,199,000	64,239,000
Assets from risk management activities	'	97,935,000	'	11,966,000	'
Other current assets	'	1,007,072,000	'	598,968,000	'
Intercompany receivables	'	0	'	0	'
Total current assets	'	1,299,570,000	'	677,133,000	'
Intangible assets	'	110,000	'	121,000	'
Goodwill	'	741,363,000	'	741,363,000	'
Noncurrent assets from risk management activities	'	48,492,000	'	109,354,000	'
Deferred charges and other assets	'	373,593,000	'	375,642,000	'
Total Assets	'	8,616,091,000	'	7,934,268,000	'
CAPITALIZATION AND LIABILITIES	'	'	'	'	'
Shareholders' equity	'	2,661,314,000	'	2,580,409,000	'
Long-term debt	'	1,955,750,000	'	2,455,671,000	'
Total capitalization	'	4,617,064,000	'	5,036,080,000	'
Current liabilities	'	'	'	'	'
Current maturities of long-term debt	'	500,000,000	'	0	'
Short-term debt	'	689,795,000	'	367,984,000	'
Liabilities from risk management activities	'	36,000	'	1,543,000	'
Other current liabilities	'	823,670,000	'	608,959,000	'
Intercompany payables	'	0	'	0	'
Total current liabilities	'	2,013,501,000	'	978,486,000	'
Deferred income taxes	'	1,230,052,000	'	1,164,053,000	'
Regulatory cost of removal obligation	'	356,617,000	'	359,299,000	'
Pension and postretirement liabilities	'	359,534,000	'	358,787,000	'
Deferred credits and other liabilities	'	39,323,000	'	37,563,000	'
Total Equity and Liabilities	'	8,616,091,000	'	7,934,268,000	'
Reportable Subsegments [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	1,255,148,000	1,034,155,000	'	'
Intersubsegment Eliminations [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	0	0	'	'
Natural Gas Distribution Segment [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Total operating revenues	'	843,865,000	666,787,000	'	'
Purchased gas cost	'	544,694,000	387,156,000	'	'
Gross profit	'	299,171,000	279,631,000	'	'
Operating expenses	'	'	'	'	'
Operation and maintenance	'	89,663,000	83,736,000	'	'
Depreciation and amortization	'	49,551,000	50,060,000	'	'
Taxes, other than income	'	37,084,000	36,751,000	'	'
Total operating expenses	'	176,298,000	170,547,000	'	'
Operating income	'	122,873,000	109,084,000	'	'
Miscellaneous income (expense)	'	-471,000	-131,000	'	'
Interest charges	'	23,325,000	23,563,000	'	'
Income (loss) before income taxes	'	99,077,000	85,390,000	'	'
Income tax expense (benefit)	'	36,320,000	32,297,000	'	'
Income (loss) from continuing operations	'	'	53,093,000	'	'
Income from discontinued operations, net of tax	'	'	3,117,000	'	'
Net income (loss)	'	62,757,000	56,210,000	'	'
Capital expenditures	'	127,506,000	145,871,000	'	'
ASSETS	'	'	'	'	'
Net property, plant and equipment	'	4,799,657,000	'	4,719,873,000	'
Investment in subsidiaries	'	863,214,000	'	831,136,000	'
Current assets	'	'	'	'	'
Cash and cash equivalents	'	152,058,000	'	4,237,000	'
Assets from risk management activities	'	88,934,000	'	1,837,000	'
Other current assets	'	740,359,000	'	428,366,000	'
Intercompany receivables	'	793,589,000	'	783,738,000	'
Total current assets	'	1,774,940,000	'	1,218,178,000	'
Intangible assets	'	0	'	0	'
Goodwill	'	574,190,000	'	574,190,000	'
Noncurrent assets from risk management activities	'	45,878,000	'	109,354,000	'
Deferred charges and other assets	'	345,075,000	'	347,687,000	'
Total Assets	'	8,402,954,000	'	7,800,418,000	'
CAPITALIZATION AND LIABILITIES	'	'	'	'	'
Shareholders' equity	'	2,661,314,000	'	2,580,409,000	'
Long-term debt	'	1,955,750,000	'	2,455,671,000	'
Total capitalization	'	4,617,064,000	'	5,036,080,000	'
Current liabilities	'	'	'	'	'
Current maturities of long-term debt	'	500,000,000	'	0	'
Short-term debt	'	972,795,000	'	645,984,000	'
Liabilities from risk management activities	'	36,000	'	1,543,000	'
Other current liabilities	'	645,433,000	'	491,681,000	'
Intercompany payables	'	0	'	0	'
Total current liabilities	'	2,118,264,000	'	1,139,208,000	'
Deferred income taxes	'	916,095,000	'	871,360,000	'
Regulatory cost of removal obligation	'	356,617,000	'	359,299,000	'
Pension and postretirement liabilities	'	359,534,000	'	358,787,000	'
Deferred credits and other liabilities	'	35,380,000	'	35,684,000	'
Total Equity and Liabilities	'	8,402,954,000	'	7,800,418,000	'
Natural Gas Distribution Segment [Member] \| Reportable Subsegments [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	842,432,000	665,549,000	'	'
Natural Gas Distribution Segment [Member] \| Intersubsegment Eliminations [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	1,433,000	1,238,000	'	'
Regulated Transmission and Storage Segment [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Total operating revenues	'	71,341,000	60,681,000	'	'
Purchased gas cost	'	0	0	'	'
Gross profit	'	71,341,000	60,681,000	'	'
Operating expenses	'	'	'	'	'
Operation and maintenance	'	17,300,000	16,320,000	'	'
Depreciation and amortization	'	9,786,000	8,390,000	'	'
Taxes, other than income	'	4,663,000	3,949,000	'	'
Total operating expenses	'	31,749,000	28,659,000	'	'
Operating income	'	39,592,000	32,022,000	'	'
Miscellaneous income (expense)	'	-1,181,000	-127,000	'	'
Interest charges	'	8,957,000	6,871,000	'	'
Income (loss) before income taxes	'	29,454,000	25,024,000	'	'
Income tax expense (benefit)	'	10,008,000	8,919,000	'	'
Income (loss) from continuing operations	'	'	16,105,000	'	'
Income from discontinued operations, net of tax	'	'	0	'	'
Net income (loss)	'	19,446,000	16,105,000	'	'
Capital expenditures	'	52,921,000	43,831,000	'	'
ASSETS	'	'	'	'	'
Net property, plant and equipment	'	1,293,093,000	'	1,249,767,000	'
Investment in subsidiaries	'	0	'	0	'
Current assets	'	'	'	'	'
Cash and cash equivalents	'	0	'	0	'
Assets from risk management activities	'	0	'	0	'
Other current assets	'	11,184,000	'	11,709,000	'
Intercompany receivables	'	0	'	0	'
Total current assets	'	11,184,000	'	11,709,000	'
Intangible assets	'	0	'	0	'
Goodwill	'	132,462,000	'	132,462,000	'
Noncurrent assets from risk management activities	'	0	'	0	'
Deferred charges and other assets	'	20,960,000	'	19,227,000	'
Total Assets	'	1,457,699,000	'	1,413,165,000	'
CAPITALIZATION AND LIABILITIES	'	'	'	'	'
Shareholders' equity	'	415,868,000	'	396,421,000	'
Long-term debt	'	0	'	0	'
Total capitalization	'	415,868,000	'	396,421,000	'
Current liabilities	'	'	'	'	'
Current maturities of long-term debt	'	0	'	0	'
Short-term debt	'	0	'	0	'
Liabilities from risk management activities	'	0	'	0	'
Other current liabilities	'	20,429,000	'	20,288,000	'
Intercompany payables	'	719,438,000	'	712,768,000	'
Total current liabilities	'	739,867,000	'	733,056,000	'
Deferred income taxes	'	299,819,000	'	283,554,000	'
Regulatory cost of removal obligation	'	0	'	0	'
Pension and postretirement liabilities	'	0	'	0	'
Deferred credits and other liabilities	'	2,145,000	'	134,000	'
Total Equity and Liabilities	'	1,457,699,000	'	1,413,165,000	'
Regulated Transmission and Storage Segment [Member] \| Reportable Subsegments [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	21,170,000	18,699,000	'	'
Regulated Transmission and Storage Segment [Member] \| Intersubsegment Eliminations [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	50,171,000	41,982,000	'	'
Nonregulated Segment [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Total operating revenues	'	447,721,000	399,894,000	'	'
Purchased gas cost	'	429,155,000	377,435,000	'	'
Gross profit	'	18,566,000	22,459,000	'	'
Operating expenses	'	'	'	'	'
Operation and maintenance	'	8,915,000	6,882,000	'	'
Depreciation and amortization	'	1,132,000	1,129,000	'	'
Taxes, other than income	'	264,000	634,000	'	'
Total operating expenses	'	10,311,000	8,645,000	'	'
Operating income	'	8,255,000	13,814,000	'	'
Miscellaneous income (expense)	'	324,000	1,667,000	'	'
Interest charges	'	637,000	797,000	'	'
Income (loss) before income taxes	'	7,942,000	14,684,000	'	'
Income tax expense (benefit)	'	3,129,000	6,534,000	'	'
Income (loss) from continuing operations	'	'	8,150,000	'	'
Income from discontinued operations, net of tax	'	'	0	'	'
Net income (loss)	'	4,813,000	8,150,000	'	'
Capital expenditures	'	140,000	325,000	'	'
ASSETS	'	'	'	'	'
Net property, plant and equipment	'	60,213,000	'	61,015,000	'
Investment in subsidiaries	'	-2,096,000	'	-2,096,000	'
Current assets	'	'	'	'	'
Cash and cash equivalents	'	42,505,000	'	61,962,000	'
Assets from risk management activities	'	9,001,000	'	10,129,000	'
Other current assets	'	564,079,000	'	452,126,000	'
Intercompany receivables	'	0	'	0	'
Total current assets	'	615,585,000	'	524,217,000	'
Intangible assets	'	110,000	'	121,000	'
Goodwill	'	34,711,000	'	34,711,000	'
Noncurrent assets from risk management activities	'	2,614,000	'	0	'
Deferred charges and other assets	'	7,558,000	'	8,728,000	'
Total Assets	'	718,695,000	'	626,696,000	'
CAPITALIZATION AND LIABILITIES	'	'	'	'	'
Shareholders' equity	'	447,346,000	'	434,715,000	'
Long-term debt	'	0	'	0	'
Total capitalization	'	447,346,000	'	434,715,000	'
Current liabilities	'	'	'	'	'
Current maturities of long-term debt	'	0	'	0	'
Short-term debt	'	0	'	0	'
Liabilities from risk management activities	'	0	'	0	'
Other current liabilities	'	181,262,000	'	110,306,000	'
Intercompany payables	'	74,151,000	'	70,970,000	'
Total current liabilities	'	255,413,000	'	181,276,000	'
Deferred income taxes	'	14,138,000	'	8,960,000	'
Regulatory cost of removal obligation	'	0	'	0	'
Pension and postretirement liabilities	'	0	'	0	'
Deferred credits and other liabilities	'	1,798,000	'	1,745,000	'
Total Equity and Liabilities	'	718,695,000	'	626,696,000	'
Nonregulated Segment [Member] \| Reportable Subsegments [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	391,546,000	349,907,000	'	'
Nonregulated Segment [Member] \| Intersubsegment Eliminations [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	56,175,000	49,987,000	'	'
Intersegment Elimination [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Total operating revenues	'	-107,779,000	-93,207,000	'	'
Purchased gas cost	'	-107,658,000	-92,798,000	'	'
Gross profit	'	-121,000	-409,000	'	'
Operating expenses	'	'	'	'	'
Operation and maintenance	'	-121,000	-411,000	'	'
Depreciation and amortization	'	0	0	'	'
Taxes, other than income	'	0	0	'	'
Total operating expenses	'	-121,000	-411,000	'	'
Operating income	'	0	2,000	'	'
Miscellaneous income (expense)	'	-804,000	-711,000	'	'
Interest charges	'	-804,000	-709,000	'	'
Income (loss) before income taxes	'	0	0	'	'
Income tax expense (benefit)	'	0	0	'	'
Income (loss) from continuing operations	'	'	0	'	'
Income from discontinued operations, net of tax	'	'	0	'	'
Net income (loss)	'	0	0	'	'
Capital expenditures	'	0	0	'	'
ASSETS	'	'	'	'	'
Net property, plant and equipment	'	0	'	0	'
Investment in subsidiaries	'	-861,118,000	'	-829,040,000	'
Current assets	'	'	'	'	'
Cash and cash equivalents	'	0	'	0	'
Assets from risk management activities	'	0	'	0	'
Other current assets	'	-308,550,000	'	-293,233,000	'
Intercompany receivables	'	-793,589,000	'	-783,738,000	'
Total current assets	'	-1,102,139,000	'	-1,076,971,000	'
Intangible assets	'	0	'	0	'
Goodwill	'	0	'	0	'
Noncurrent assets from risk management activities	'	0	'	0	'
Deferred charges and other assets	'	0	'	0	'
Total Assets	'	-1,963,257,000	'	-1,906,011,000	'
CAPITALIZATION AND LIABILITIES	'	'	'	'	'
Shareholders' equity	'	-863,214,000	'	-831,136,000	'
Long-term debt	'	0	'	0	'
Total capitalization	'	-863,214,000	'	-831,136,000	'
Current liabilities	'	'	'	'	'
Current maturities of long-term debt	'	0	'	0	'
Short-term debt	'	-283,000,000	'	-278,000,000	'
Liabilities from risk management activities	'	0	'	0	'
Other current liabilities	'	-23,454,000	'	-13,316,000	'
Intercompany payables	'	-793,589,000	'	-783,738,000	'
Total current liabilities	'	-1,100,043,000	'	-1,075,054,000	'
Deferred income taxes	'	0	'	179,000	'
Regulatory cost of removal obligation	'	0	'	0	'
Pension and postretirement liabilities	'	0	'	0	'
Deferred credits and other liabilities	'	0	'	0	'
Total Equity and Liabilities	'	-1,963,257,000	'	-1,906,011,000	'
Intersegment Elimination [Member] \| Reportable Subsegments [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	0	0	'	'
Intersegment Elimination [Member] \| Intersubsegment Eliminations [Member]	'	'	'	'	'
Segment Reporting Information Profit Loss [Abstract]	'	'	'	'	'
Revenues from external customers	'	($107,779,000)	($93,207,000)	'	'

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended
Earnings Per Share (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Basic Earnings per Share from Continuing Operations	'	'
Income from continuing operations	$87,016,000	$77,348,000
Less: Income from continuing operations allocated to participating securities	235,000	260,000
Income from continuing operations available to common shareholders	86,781,000	77,088,000
Basic weighted average shares outstanding	90,833,000	90,359,000
Income from continuing operations per share - Basic	$0.96	$0.85
Basic Earnings per Share from Discontinued Operations	'	'
Income from discontinued operations, net of tax	0	3,117,000
Less: Income from discontinued operations allocated to participating securities	0	10,000
Income from discontinued operations available to common shareholders	0	3,107,000
Basic weighted average shares outstanding	90,833,000	90,359,000
Income from discontinued operations per share - Basic	$0	$0.04
Net income per share - Basic	$0.96	$0.89
Diluted Earnings per Share from Continuing Operations	'	'
Income from continuing operations available to common shareholders	86,781,000	77,088,000
Effect of dilutive stock options and other shares	1,000	2,000
Income from continuing operations available to common shareholders	86,782,000	77,090,000
Basic weighted average shares outstanding	90,833,000	90,359,000
Additional dilutive stock options and other shares	913,000	950,000
Diluted weighted average shares outstanding	91,746,000	91,309,000
Income from continuing operations per share - Diluted	$0.95	$0.85
Diluted Earnings per Share from Discontinued Operations	'	'
Income from discontinued operations available to common shareholders	0	3,107,000
Effect of dilutive stock options and other shares	0	0
Net Income Loss From Discontinued Operations Available To Common Stockholders Diluted	0	3,107,000
Basic weighted average shares outstanding	90,833,000	90,359,000
Additional dilutive stock options and other shares	913,000	950,000
Diluted weighted average shares outstanding	91,746,000	91,309,000
Income from discontinued operations per share - Diluted	$0	$0.03
Net income per share - Diluted	$0.95	$0.88
Earnings Per Share Diluted Other Disclosures Abstract	'	'
Anti-dilutive stock options excluded from computation of diluted earnings per share (in shares)	0	0
Share Repurchase Program - Shares Purchased	0	0
Share Repurchase Program - Amount Purchased	$0	$0

Debt_Details

Debt (Details) (USD $)

3 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Jan. 29, 2014

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Minimum [Member]

Maximum [Member]

First Facility Regulated Operations [Member]

Second Facility Regulated Operations [Member]

Third Facility Regulated Operations [Member]

Intercompany Facility Regulated Operations [Member]

Committed Facility Nonregulated Operations [Member]

Uncommitted Facility Nonregulated Operations [Member]

Intercompany Facility Nonregulated Operations [Member]

Nonregulated Facilities [Member]

Regulated Facilities [Member]

Unsecured Senior Notes Due 2014 [Member]

Unsecured Senior Notes Due 2017 [Member]

Unsecured Senior Notes Due 2019 [Member]

Unsecured Senior Notes Due 2034 [Member]

Unsecured Senior Notes Due 2041 [Member]

Unsecured Senior Notes Due 2043 [Member]

Medium Term Notes Due 2025 [Member]

Unsecured Debentures Due 2028 [Member]

Debt Instrument [Line Items]

Debt Instrument Carrying Amount

$2,460,000,000

$500,000,000

$250,000,000

$450,000,000

$200,000,000

$400,000,000

$500,000,000

$10,000,000

$150,000,000

Debt Instrument, Interest Rate, Stated Percentage

4.95%

6.35%

8.50%

5.95%

5.50%

4.15%

6.67%

6.75%

Debt Instrument, Maturity Date

15-Oct-14

15-Jun-17

15-Mar-19

15-Oct-34

15-Jun-41

15-Jan-43

15-Dec-25

15-Jul-28

Debt Instrument, Unamortized Discount

4,250,000

4,329,000

Current maturities of long-term debt

500,000,000

Long-term debt

1,955,750,000

2,455,671,000

Line Of Credit Facility [Line Items]

Line Of Credit Facility Maximum Borrowing Capacity

1,000,000,000

950,000,000

25,000,000

10,000,000

500,000,000

15,000,000

25,000,000

50,000,000

25,000,000

500,000,000

985,000,000

Line of Credit Facility, Current Available Borrowing Capacity

4,100,000

15,400,000

Line of Credit Facility, Maximum Borrowing Capacity with Accordion Feature

1,200,000,000

Line Of Credit Facility Description

'which bears interest at the lower of (i)B the Eurodollar rate under the five-year revolving credit facility or (ii)B the rate outstanding under the commercial paper program

'This facility bears interest at a rate equal to the one-month LIBOR rate plus 3.00 percent or (ii) the rate for AEM's borrowings under its committed credit facility plus 0.75 percent.

Debt Instrument, Covenant, Excess Debt Trigger

15,000,000

100,000,000

Long Term Debt Other Disclosures [Abstract]

Authorized Commercial Paper

950,000,000

Commercial Paper

689,800,000

368,000,000

Debt and Equity Securities Authorized for Issuance

1,750,000,000

Debt And Equity Securities Available For Issuance

$1,750,000,000

Regulated Operations Line of Credit Facilities, Covenant Terms

'We are required by the financial covenants in each of these facilities to maintain, at the end of each fiscal quarter, a ratio of total debt to total capitalization of no greater than 70 percent.

Ratio of Total Debt to Total Capital

56.00%

Debt Instrument Covenant Description

'In addition to these financial covenants, our credit facilities and public indentures contain usual and customary covenants for our business, including covenants substantially limiting liens, substantial asset sales and mergers. Additionally, our public debt indentures relating to our senior notes and debentures, as well as our revolving credit agreements, each contain a default provision that is triggered if outstanding indebtedness arising out of any other credit agreements in amounts ranging from in excess of $15 million to in excess of $100 million becomes due by acceleration or is not paid at maturity.

Debt Instrument Covenant Compliance

'We were in compliance with all of our debt covenants as of December 31, 2013.

Interim_Pension_and_Other_Post2

Interim Pension and Other Postretirement Benefits (Details) (USD $)	0 Months Ended	3 Months Ended
	Oct. 02, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013
		Pension Benefits [Member]	Pension Benefits [Member]	Pension Benefits [Member]	Pension Benefits [Member]	Other Benefits [Member]	Other Benefits [Member]	Other Benefits [Member]	Other Benefits [Member]
				Minimum [Member]	Maximum [Member]			Minimum [Member]	Maximum [Member]
Components of net periodic pension cost [Abstract]	'	'	'	'	'	'	'	'	'
Service Cost	'	$4,738,000	$5,202,000	'	'	$4,196,000	$4,700,000	'	'
Interest Cost	'	6,824,000	6,025,000	'	'	3,988,000	3,241,000	'	'
Expected return on assets	'	-5,901,000	-5,739,000	'	'	-1,292,000	-997,000	'	'
Amortization of transition (asset)/obligation	'	0	0	'	'	68,000	270,000	'	'
Amortization of prior service (credit)/cost	'	-34,000	-35,000	'	'	-363,000	-362,000	'	'
Amortization of actuarial (gain) loss	'	3,932,000	5,561,000	'	'	158,000	1,049,000	'	'
Settlement loss	'	4,539,000	0	'	'	0	0	'	'
Net periodic pension cost	'	14,098,000	11,014,000	'	'	6,755,000	7,901,000	'	'
Defined Benefit Plan Weighted Average Assumptions Used In Calculating Net Periodic Benefit Cost Abstract	'	'	'	'	'	'	'	'	'
Discount Rate	'	4.95%	4.04%	'	'	4.95%	4.04%	'	'
Rate of compensation increase	'	3.50%	3.50%	'	'	'	'	'	'
Expected return on plan assets	'	7.25%	7.75%	'	'	4.60%	4.70%	'	'
Current Year Benefit Plan Contributions [Abstract]	'	'	'	'	'	'	'	'	'
Contributions Actual	'	4,700,000	'	'	'	5,900,000	'	'	'
Contributions Remaining, Estimate	'	'	'	10,000,000	15,000,000	'	'	15,000,000	20,000,000
Benefit Payment	$16,800,000	'	'	'	'	'	'	'	'

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	0 Months Ended	3 Months Ended
Commitments and Contingencies (Details) (USD $)	Jan. 25, 2013	Dec. 31, 2013	Dec. 31, 2012
Loss Contingency Information About Litigation Matters Abstract	'	'	'
Description of Pending Litigation	'	'Since April 2009, Atmos Energy and two subsidiaries of AEH, Atmos Energy Marketing, LLC (AEM) and Atmos Gathering Company, LLC (AGC) (collectively, the Atmos Entities), have been involved in a lawsuit filed in the Circuit Court of Edmonson County, Kentucky related to our Park City Gathering Project. The dispute which gave rise to the litigation involves the amount of royalties due from a third party producer to landowners (who own the mineral rights) for natural gas produced from the landownersb properties. The third party producer was operating pursuant to leases between the landowners and certain investors/working interest owners. The third party producer filed a petition in bankruptcy, which was subsequently dismissed due to the lack of meaningful assets to reorganize or liquidate.Although certain Atmos Energy companies entered into contracts with the third party producer to gather, treat and ultimately sell natural gas produced from the landownersb properties, no Atmos Energy company had a contractual relationship with the landowners or the investors/working interest owners. After the lawsuit was filed, the landowners were successful in terminating for non-payment of royalties the leases related to the production of natural gas from their properties. Subsequent to termination, the investors/working interest owners under such leases filed additional claims against us for the termination of the leases.During the trial, the landowners and the investors/working interest owners requested an award of compensatory damages plus punitive damages against us. On DecemberB 17, 2010, the jury returned a verdict in favor of the landowners and investor/working interest owners and awarded compensatory damages of $3.8 million and punitive damages of $27.5 million payable by Atmos Energy and the two AEH subsidiaries.A hearing was held on FebruaryB 28, 2011 to hear a number of motions, including a motion to dismiss the jury verdict and a motion for a new trial. The motions to dismiss the jury verdict and for a new trial were denied. However, the total punitive damages award was reduced from $27.5 million to $24.7 million. On OctoberB 17, 2011, we filed our brief of appellants with the Kentucky Court of Appeals, appealing the verdict of the trial court. The appellees in this case subsequently filed their appelleesb brief with the Court of Appeals on JanuaryB 16, 2012, with our reply brief being filed with the Court of Appeals on MarchB 19, 2012. Oral arguments were held in the case on AugustB 27, 2012.In an opinion handed down on JanuaryB 25, 2013, the Court of Appeals overturned the $28.5 million jury verdict returned against the Atmos Entities. In a unanimous decision by a three-judge panel, the Court of Appeals reversed the claims asserted by the landowners and investors/working interest owners. The Court of Appeals concluded that all of such claims that the Atmos Entities appealed should have been dismissed by the trial court as a matter of law. The Court of Appeals let stand the jury verdict on one claim that Atmos Energy and our subsidiaries chose not to appeal, which was a trespass claim. The jury had awarded a total of $10,000 in compensatory damages to one landowner on that claim. The Court of Appeals vacated all of the other damages awarded by the jury and remanded the case to the trial court for a new trial, solely on the issue of whether punitive damages should be awarded to that landowner and, if so, in what amount.The investors/working interest owners, on FebruaryB 25, 2013, and the landowners, on MarchB 19, 2013, each filed with the Supreme Court of Kentucky, separate motions for discretionary review of the opinion of the Court of Appeals. We filed a response to the motion filed by the investors/working owners on MarchB 27, 2013 and to the landownersb motion on AprilB 17, 2013. The decision of the Court of Appeals will not become final until the appellate process is completed. We had previously accrued what we believed to be an adequate amount for the anticipated resolution of this matter and we will continue to maintain this amount in legal reserves until the appellate process in this case has been completed. We continue to believe that the final outcome will not have a material adverse effect on our financial condition, results of operations or cash flows.In addition, in a related matter, on JulyB 12, 2011, the Atmos Entities filed a lawsuit in the United States District Court, Western District of Kentucky, Atmos Energy Corporation et al.vs. Resource Energy Technologies, LLC and Robert Thorpe and John F. Charles, against the third party producer and its affiliates to recover all costs, including attorneysb fees, incurred by the Atmos Entities, which are associated with the defense and appeal of the case discussed above as well as for all damages awarded to the plaintiffs in such case against the Atmos Entities. The total amount of damages being claimed in the lawsuit is bopen-endedb since the appellate process and related costs are ongoing. This lawsuit is based upon the indemnification provisions agreed to by the third party producer in favor of Atmos Gathering that are contained in an agreement entered into between Atmos Gathering and the third party producer in May 2009. The defendants filed a motion to dismiss the case on AugustB 25, 2011, with Atmos Energy filing a brief in response to such motion on SeptemberB 19, 2011. On MarchB 27, 2012 the court denied the motion to dismiss. Since that time, we have been engaged in discovery activities in this case.	'
Loss Contingency, Compensatory Damages Awarded, Value	$10,000	'	'
Business License Tax [Abstract]	'	'	'
Business License Tax Examination, Description	'	'Atmos Energy, through its affiliate, AEM, has been involved in a dispute with the Tennessee Department of Revenue (TDOR) regarding sales business tax audits over a period of several years. AEM has challenged the assessment of the business tax. With respect to certain issues, AEM and the TDOR filed competing Partial Motions for Summary Judgment with the Chancery Court. On August 2, 2013, the Chancery Court granted the TDOR's Partial Motion for Summary Judgment and denied AEM's Partial Motion for Summary Judgment and set February 1, 2014 as the date by which AEM and the TDOR will set a date for filing any cross motions for partial summary judgment as to the remaining issue. The Company anticipates a decision by the Chancery Court on the remaining issue in fiscal 2014. The cumulative assessment is expected to be approximately $11 million for the period December 2002 through December 2013, including tax, interest and penalties.	'
Long Term Purchase Commitment [Line Items]	'	'	'
Significant Purchase Commitment Amount Description	'	$350,200,000	$289,500,000
Inventories Under Indexed Contracts [Member]	'	'	'
Long Term Purchase Commitment [Line Items]	'	'	'
Long Term Purchase Commitment Minimum Quantity Required Within One Year	'	91.1	'
Long Term Purchase Commitment Minimum Quantity Required One To Three Years	'	14.8	'
Long Term Purchase Commitment Minimum Quantity Required After Three Years	'	0.9	'
Inventories Under Fixed Price Contracts [Member]	'	'	'
Long Term Purchase Commitment [Line Items]	'	'	'
Long Term Purchase Commitment Minimum Quantity Required Within One Year	'	4.4	'
Purchase Commitment Amount Minimum	'	3.6	'
Purchase Commitment Amount Maximum	'	6.36	'

Financial_Instruments_Descript

Financial Instruments Descriptions (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
	MMcf	Dec. 31, 2012
General Discussion Of Derivative Instruments And Hedging Activities [Abstract]	'	'
Minimum Hedge Percentage Of Anticipated Heating Season Gas	25.00%	'
Maximum Hedge Percentage Of Anticipated Heating Season Gas	50.00%	'
Hedge Percentage Of Anticipated Heating Season Gas	39.00%	'
Hedge Volume Of Anticipated Heating Season Gas	24,800	'
Minimum Length Of Time Hedged In Cash Flow Hedge	'1 month	'
Maximum Length Of Time Hedged In Cash Flow Hedge	'52 months	'
Gain (Loss) On Hedge Ineffectiveness	$5.10	$16.10
Regulated Segments Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate	37.00%	'
Nonregulated Segment Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate	39.00%	'
Gain (Loss) On Derivative Instruments Not Designated Hedges Net Pretax	-0.8	-0.1
Interest Rate Hedges, Senior Notes 2015 Issuance [Member]	'	'
Derivative [Line Items]	'	'
Notional Amount of Interest Rate Cash Flow Hedge Derivatives	500	'
Interest Rate Hedges, Senior Notes 2017 Issuance [Member]	'	'
Derivative [Line Items]	'	'
Notional Amount of Interest Rate Cash Flow Hedge Derivatives	$250	'

Financial_Instruments_Commodit

Financial Instruments Commodity Contract Volume (Details)	Dec. 31, 2013
Financial Instruments Commodity Contract Volume (Details)	MMcf
Natural Gas Distribution Segment [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	15,796
Natural Gas Distribution Segment [Member] \| Nondesignated [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	15,796
Natural Gas Distribution Segment [Member] \| Fair Value Hedging [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	0
Natural Gas Distribution Segment [Member] \| Cash Flow Hedging [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	0
Nonregulated Segment [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	72,010
Nonregulated Segment [Member] \| Nondesignated [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	59,095
Nonregulated Segment [Member] \| Fair Value Hedging [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	-18,585
Nonregulated Segment [Member] \| Cash Flow Hedging [Member]	'
Commodity Contract Outstanding Volumes [Line Items]	'
Investment Contract Volume	31,500

Financial_Instruments_Balance_

Financial Instruments Balance Sheet Location (Details) (USD $)	Dec. 31, 2013	Sep. 30, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013
Derivatives Fair Value [Line Items]	'	'
Derivative, Collateral, Right to Reclaim Cash	$9,000	$10,100
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	7,700	14,700
Natural Gas Distribution Segment [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	134,812	111,191
Derivative Asset, Contract Netting	0	0
Derivative Asset, Net of Contract Netting	134,812	111,191
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Asset	134,812	111,191
Derivative Liability, Fair Value, Gross Liability	-36	-1,543
Derivative Liability, Contract Netting	0	0
Derivative Liability, Net of Contract Netting	-36	-1,543
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	0	0
Derivative Liability	-36	-1,543
Nonregulated Segment [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	104,049	115,880
Derivative Asset, Contract Netting	-101,435	-115,875
Derivative Asset, Net of Contract Netting	2,614	5
Derivative, Collateral, Right to Reclaim Cash	9,001	10,124
Derivative Asset	11,615	10,129
Derivative Liability, Fair Value, Gross Liability	-109,142	-130,580
Derivative Liability, Contract Netting	101,435	115,875
Derivative Liability, Net of Contract Netting	-7,707	-14,705
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	7,707	14,705
Derivative Liability	0	0
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	128,411	107,512
Derivative Liability, Fair Value, Gross Liability	0	0
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Other Current Assets [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	83,578	'
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Other Current Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	0	0
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Deferred Charges And Other Assets [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	44,833	107,512
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Deferred Charges And Other Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	0	0
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Other Current Liabilities [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	'
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Other Current Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	0
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Deferred Credits And Other Liabilities [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	0
Designated As Hedging Instrument [Member] \| Natural Gas Distribution Segment [Member] \| Deferred Credits And Other Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	0
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	13,021	9,510
Derivative Liability, Fair Value, Gross Liability	-13,072	-13,812
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Other Current Assets [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	0	'
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Other Current Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	12,238	9,094
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Deferred Charges And Other Assets [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	0	0
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Deferred Charges And Other Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	783	416
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Other Current Liabilities [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	'
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Other Current Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-12,089	-12,173
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Deferred Credits And Other Liabilities [Member] \| Interest Rate Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	0
Designated As Hedging Instrument [Member] \| Nonregulated Segment [Member] \| Deferred Credits And Other Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-983	-1,639
Nondesignated [Member] \| Natural Gas Distribution Segment [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	6,401	3,679
Derivative Liability, Fair Value, Gross Liability	-36	-1,543
Nondesignated [Member] \| Natural Gas Distribution Segment [Member] \| Other Current Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	5,356	1,837
Nondesignated [Member] \| Natural Gas Distribution Segment [Member] \| Deferred Charges And Other Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	1,045	1,842
Nondesignated [Member] \| Natural Gas Distribution Segment [Member] \| Other Current Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-36	-1,543
Nondesignated [Member] \| Natural Gas Distribution Segment [Member] \| Deferred Credits And Other Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	0
Nondesignated [Member] \| Nonregulated Segment [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	91,028	106,370
Derivative Liability, Fair Value, Gross Liability	-96,070	-116,768
Nondesignated [Member] \| Nonregulated Segment [Member] \| Other Current Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	55,288	65,388
Nondesignated [Member] \| Nonregulated Segment [Member] \| Deferred Charges And Other Assets [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	35,740	40,982
Nondesignated [Member] \| Nonregulated Segment [Member] \| Other Current Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-63,144	-70,876
Nondesignated [Member] \| Nonregulated Segment [Member] \| Deferred Credits And Other Liabilities [Member] \| Commodity Contract [Member]	'	'
Derivatives Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	($32,926)	($45,892)

Financial_Instruments_Fair_Val

Financial Instruments Fair Value Hedges and Cash Flow Hedges (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Effect of Fair Value Hedges on Results of Operations [Abstract]	'	'
Commodity contracts	$8,561	($7,314)
Fair value adjustment for natural gas inventory designated as the hedged item	-13,779	-8,818
Total (increase) decrease to purchased gas cost	5,218	16,132
Basis ineffectiveness	-620	-241
Timing ineffectiveness	5,838	16,373
Cash Flow Hedge [Line Items]	'	'
Gain (loss) reclassified from AOCI into purchased gas cost for effective portion of commodity contracts	-2,609	-5,160
Gain (loss) arising from ineffective portion of commodity contracts	-119	-19
Total impact on purchased gas cost	-2,728	-5,179
Loss on settled Treasury Lock agreements reclassified from AOCI into interest expense	-1,058	-502
Total Impact from Cash Flow Hedges	-3,786	-5,681
Natural Gas Distribution Segment [Member]	'	'
Cash Flow Hedge [Line Items]	'	'
Gain (loss) reclassified from AOCI into purchased gas cost for effective portion of commodity contracts	0	0
Gain (loss) arising from ineffective portion of commodity contracts	0	0
Total impact on purchased gas cost	0	0
Loss on settled Treasury Lock agreements reclassified from AOCI into interest expense	-1,058	-502
Total Impact from Cash Flow Hedges	-1,058	-502
Nonregulated Segment [Member]	'	'
Cash Flow Hedge [Line Items]	'	'
Gain (loss) reclassified from AOCI into purchased gas cost for effective portion of commodity contracts	-2,609	-5,160
Gain (loss) arising from ineffective portion of commodity contracts	-119	-19
Total impact on purchased gas cost	-2,728	-5,179
Loss on settled Treasury Lock agreements reclassified from AOCI into interest expense	0	0
Total Impact from Cash Flow Hedges	($2,728)	($5,179)

Financial_Instruments_Other_Co

Financial Instruments Other Comprehensive Income (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'		'
Interest rate agreements fair value	$13,270		$11,945
Forward commodity contracts fair value	6,226		-3,513
Interest rate agreements	672		319
Forward commodity contracts	1,592		3,148
Total other comprehensive income (loss) from hedging, net of tax	21,760	[1]	11,899	[1]
Expected Earnings [Line Items]	'		'
Interest Rate Agreement Gain (Loss) Reclassified To Earnings	-29,693	[2]	'
Commodity Contract Gain (Loss) Reclassified To Earnings	3,342	[2]	'
Total Hedge Gain (Loss) Reclassified To Earnings	-26,351		'
Next Twelve Months [Member]	'		'
Expected Earnings [Line Items]	'		'
Interest Rate Agreement Gain (Loss) Reclassified To Earnings	-2,343		'
Commodity Contract Gain (Loss) Reclassified To Earnings	3,458		'
Total Hedge Gain (Loss) Reclassified To Earnings	1,115		'
Thereafter [Member]	'		'
Expected Earnings [Line Items]	'		'
Interest Rate Agreement Gain (Loss) Reclassified To Earnings	-27,350		'
Commodity Contract Gain (Loss) Reclassified To Earnings	-116		'
Total Hedge Gain (Loss) Reclassified To Earnings	($27,466)		'

[1]	Utilizing an income tax rate ranging from 37 percent to 39 percent based on the effective rates in each taxing jurisdiction.
[2]	(1)B Utilizing an income tax rate ranging from 37 percent to 39 percent based on the effective rates in each taxing jurisdiction.

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income Components (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'
Accumulated other comprehensive income (loss), beginning balance	$38,878	($47,607)
Other comprehensive income before reclassifications	21,890	8,059
Amounts reclassified from accumulated other comprehensive income	2,264	3,467
Net current-period other comprehensive income	24,154	11,526
Accumulated other comprehensive income (loss), ending balance	63,032	-36,081
Accumulated Net Unrealized Investment Gain (Loss) [Member]	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'
Accumulated other comprehensive income (loss), beginning balance	5,448	5,661
Other comprehensive income before reclassifications	2,394	-373
Amounts reclassified from accumulated other comprehensive income	0	0
Net current-period other comprehensive income	2,394	-373
Accumulated other comprehensive income (loss), ending balance	7,842	5,288
Accumulated Net Gain (Loss) from Interest Rate Hedges [Member] [Member]	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'
Accumulated other comprehensive income (loss), beginning balance	37,906	-44,273
Other comprehensive income before reclassifications	13,270	11,945
Amounts reclassified from accumulated other comprehensive income	672	319
Net current-period other comprehensive income	13,942	12,264
Accumulated other comprehensive income (loss), ending balance	51,848	-32,009
Accumulated Net Gain (Loss) from Commodity Contracts Cash Flow Hedges [Member] [Member]	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'
Accumulated other comprehensive income (loss), beginning balance	-4,476	-8,995
Other comprehensive income before reclassifications	6,226	-3,513
Amounts reclassified from accumulated other comprehensive income	1,592	3,148
Net current-period other comprehensive income	7,818	-365
Accumulated other comprehensive income (loss), ending balance	$3,342	($9,360)

Accumulated_Other_Comprehensiv3

Accumulated Other Comprehensive Income Affected Line Item in the Statement of Income (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'
Operation and maintenance	$115,757	$106,527
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	136,473	125,098
Income Tax Expense (Benefit)	-49,457	-47,750
Income (loss) from continuing operations	87,016	77,348
Interest charges	-32,115	-30,522
Purchased gas cost	866,191	671,793
Reclassification out of Accumulated Other Comprehensive Income [Member]	'	'
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'
Income (loss) from continuing operations	-2,264	-3,467
Reclassification out of Accumulated Other Comprehensive Income [Member] \| Accumulated Net Gain (Loss) from Interest Rate Hedges [Member] [Member]	'	'
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'
Interest charges	-1,058	-502
Reclassification out of Accumulated Other Comprehensive Income [Member] \| Accumulated Net Gain (Loss) from Commodity Contracts Cash Flow Hedges [Member] [Member]	'	'
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'
Purchased gas cost	-2,609	-5,160
Reclassification out of Accumulated Other Comprehensive Income [Member] \| Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'	'
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest	-3,667	-5,662
Income Tax Expense (Benefit)	$1,403	$2,195

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Dec. 31, 2013	Sep. 30, 2013
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	$146,427,000	$121,320,000
Hedged portion of gas stored underground	76,151,000	44,758,000
Available-for-sale Securities	75,390,000	72,682,000
Total assets	297,968,000	238,760,000
Financial instruments, liabilities	36,000	1,543,000
Fair Value [Abstract]	'	'
Derivative, Cash Collateral	16,700,000	24,800,000
Cash Held In Margin Accounts Classified Current Risk Management Asset	9,000,000	10,100,000
Cash Held In Margin Accounts Offset Current Risk Management Liabilities	7,700,000	14,700,000
Debt Instrument Carrying Amount	2,460,000,000	2,460,000,000
Debt Instrument Fair Value	2,661,390,000	2,676,487,000
Money Market Funds [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	3,376,000	4,428,000
Equity Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	44,000,000	40,094,000
Debt Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	28,014,000	28,160,000
Natural Gas Distribution Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	134,812,000	111,191,000
Financial instruments, liabilities	36,000	1,543,000
Fair Value [Abstract]	'	'
Cash Held In Margin Accounts Classified Current Risk Management Asset	0	0
Cash Held In Margin Accounts Offset Current Risk Management Liabilities	0	0
Nonregulated Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	11,615,000	10,129,000
Financial instruments, liabilities	0	0
Fair Value [Abstract]	'	'
Cash Held In Margin Accounts Classified Current Risk Management Asset	9,001,000	10,124,000
Cash Held In Margin Accounts Offset Current Risk Management Liabilities	7,707,000	14,705,000
Fair Value Inputs Level 1 [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	184,000	745,000
Hedged portion of gas stored underground	76,151,000	44,758,000
Available-for-sale Securities	44,000,000	40,094,000
Total assets	120,335,000	85,597,000
Financial instruments, liabilities	1,172,000	158,000
Fair Value Inputs Level 1 [Member] \| Money Market Funds [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Fair Value Inputs Level 1 [Member] \| Equity Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	44,000,000	40,094,000
Fair Value Inputs Level 1 [Member] \| Debt Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Fair Value Inputs Level 1 [Member] \| Natural Gas Distribution Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	0	0
Financial instruments, liabilities	0	0
Fair Value Inputs Level 1 [Member] \| Nonregulated Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	184,000	745,000
Financial instruments, liabilities	1,172,000	158,000
Fair Value Inputs Level 2 [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	238,677,000	226,326,000
Hedged portion of gas stored underground	0	0
Available-for-sale Securities	31,390,000	32,588,000
Total assets	270,067,000	258,914,000
Financial instruments, liabilities	108,006,000	131,965,000
Fair Value Inputs Level 2 [Member] \| Money Market Funds [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	3,376,000	4,428,000
Fair Value Inputs Level 2 [Member] \| Equity Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Fair Value Inputs Level 2 [Member] \| Debt Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	28,014,000	28,160,000
Fair Value Inputs Level 2 [Member] \| Natural Gas Distribution Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	134,812,000	111,191,000
Financial instruments, liabilities	36,000	1,543,000
Fair Value Inputs Level 2 [Member] \| Nonregulated Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	103,865,000	115,135,000
Financial instruments, liabilities	107,970,000	130,422,000
Fair Value Inputs Level 3 [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	0	0
Hedged portion of gas stored underground	0	0
Available-for-sale Securities	0	0
Total assets	0	0
Financial instruments, liabilities	0	0
Fair Value Inputs Level 3 [Member] \| Money Market Funds [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Fair Value Inputs Level 3 [Member] \| Equity Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Fair Value Inputs Level 3 [Member] \| Debt Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Fair Value Inputs Level 3 [Member] \| Natural Gas Distribution Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	0	0
Financial instruments, liabilities	0	0
Fair Value Inputs Level 3 [Member] \| Nonregulated Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	0	0
Financial instruments, liabilities	0	0
Netting And Collateral [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	-92,434,000	-105,751,000
Hedged portion of gas stored underground	0	0
Available-for-sale Securities	0	0
Total assets	-92,434,000	-105,751,000
Financial instruments, liabilities	-109,142,000	-130,580,000
Netting And Collateral [Member] \| Money Market Funds [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Netting And Collateral [Member] \| Equity Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Netting And Collateral [Member] \| Debt Securities [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Available-for-sale Securities	0	0
Netting And Collateral [Member] \| Natural Gas Distribution Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	0	0
Financial instruments, liabilities	0	0
Netting And Collateral [Member] \| Nonregulated Segment [Member]	'	'
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]	'	'
Financial instruments, assets	-92,434,000	-105,751,000
Financial instruments, liabilities	($109,142,000)	($130,580,000)

Fair_Value_Measurements_Availa

Fair Value Measurements Available-For-Sale Securities (Details) (USD $)	Dec. 31, 2013	Sep. 30, 2013
Schedule Of Available For Sale Securities [Line Items]	'	'
Available For Sale Securities Amortized Cost	$62,901,000	$64,023,000
Gross Unrealized Gain	12,511,000	8,706,000
Gross Unrealized Loss	-22,000	-47,000
Fair value	75,390,000	72,682,000
Available-for-sale Securities, Other Disclosure Items [Abstract]	'	'
Available-for-sale Securities, Supplemental Executive Benefit Plans	47,400,000	44,500,000
Equity Funds Domestic [Member]	'	'
Schedule Of Available For Sale Securities [Line Items]	'	'
Available For Sale Securities Amortized Cost	27,129,000	27,043,000
Gross Unrealized Gain	10,575,000	7,476,000
Gross Unrealized Loss	0	-23,000
Fair value	37,704,000	34,496,000
Equity Funds Foreign [Member]	'	'
Schedule Of Available For Sale Securities [Line Items]	'	'
Available For Sale Securities Amortized Cost	4,536,000	4,536,000
Gross Unrealized Gain	1,760,000	1,062,000
Gross Unrealized Loss	0	0
Fair value	6,296,000	5,598,000
Debt Securities [Member]	'	'
Schedule Of Available For Sale Securities [Line Items]	'	'
Available For Sale Securities Amortized Cost	27,860,000	28,016,000
Gross Unrealized Gain	176,000	168,000
Gross Unrealized Loss	-22,000	-24,000
Fair value	28,014,000	28,160,000
Money Market Funds [Member]	'	'
Schedule Of Available For Sale Securities [Line Items]	'	'
Available For Sale Securities Amortized Cost	3,376,000	4,428,000
Gross Unrealized Gain	0	0
Gross Unrealized Loss	0	0
Fair value	$3,376,000	$4,428,000

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	0 Months Ended	3 Months Ended
Discontinued Operations (Details) (USD $)	Apr. 02, 2013	Dec. 31, 2013	Dec. 31, 2012
Discontinued Operations and Disposal Groups [Abstract]	'	'	'
Discontinued Operation, Cash Price Received from Disposal of Discontinued Operation	$153,000,000	'	'
Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]	'	'	'
Operating revenues	'	0	16,284,000
Purchased gas cost	'	0	8,967,000
Gross profit	'	0	7,317,000
Operating expenses	'	0	2,820,000
Operating income	'	0	4,497,000
Miscellaneous income (expense)	'	0	348,000
Income from discontinued operations before income taxes	'	0	4,845,000
Income tax expense	'	0	1,728,000
Income (loss) from discontinued operations	'	0	3,117,000
Gain (loss) on sale of discontinued operations, net of tax	5,300,000	'	'
Net income (loss) from discontinued operations	'	$0	$3,117,000