New Jersey Resources (NJR) 10-Q 7 May 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Mar. 31, 2014	2-May-14
Document Information [Line Items]	'	'
Entity Registrant Name	'NEW JERSEY RESOURCES CORP	'
Entity Central Index Key	'0000356309	'
Current Fiscal Year End Date	'--09-30	'
Entity Well-known Seasoned Issuer	'Yes	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	42,136,052
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	31-Mar-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended				6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013		Mar. 31, 2014		Mar. 31, 2013
OPERATING REVENUES	'		'		'		'
Utility	$394,528		$351,750		$627,997		$570,599
Nonutility	1,185,041		609,135		1,829,977		1,126,305
Total operating revenues	1,579,569		960,885		2,457,974		1,696,904
OPERATING EXPENSES	'		'		'		'
Gas Purchases - Utility	147,946		189,040		259,148		300,361
Gas Purchases - Nonutility	1,047,870		611,567		1,711,400		1,066,994
Operation and maintenance	61,273		43,067		103,296		83,137
Regulatory rider expenses	38,211		23,774		58,043		37,756
Depreciation and amortization	12,828		11,721		25,394		23,024
Energy and other taxes	24,429		24,747		41,457		41,472
Total operating expenses	1,332,557		903,916		2,198,738		1,552,744
OPERATING INCOME	247,012		56,969		259,236		144,160
Other income	712		2,781		1,839		3,046
Interest expense, net of capitalized interest	6,306		5,746		12,601		11,571
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	241,418		54,004		248,474		135,635
Income tax provision	71,680		12,065		73,185		36,045
Equity in earnings of affiliates	3,233		3,530		5,375		6,085
NET INCOME	$172,971		$45,469		$180,664		$105,675
EARNINGS PER COMMON SHARE	'		'		'		'
BASIC (usd per share)	$4.11		$1.09		$4.30		$2.53
DILUTED (usd per share)	$4.07	[1]	$1.08	[1]	$4.26	[1]	$2.52	[1]
DIVIDENDS PER COMMON SHARE (usd per share)	$0.42		$0.40		$0.84		$0.80
WEIGHTED AVERAGE SHARES OUTSTANDING	'		'		'		'
BASIC (in shares)	42,079		41,789		42,050		41,742
DILUTED (in shares)	42,457		41,972		42,428		41,925
[1]	There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and six months ended March 31, 2014 and 2013.

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
Net income	$172,971	$45,469	$180,664	$105,675
Other comprehensive income, net of tax	'	'	'	'
Unrealized gain (loss) on available for sale securities, net of tax of $(11), $(447), $203, and $(226), respectively	15	647	-295	327
Net unrealized (loss) on derivatives, net of tax of $89, $4, $109, and $10, respectively	-152	-7	-186	-17
Adjustment to postemployment benefit obligation, net of tax of $(112), $(202), $(223) and $(405), respectively	161	296	322	709
Other comprehensive income (loss)	24	936	-159	1,019
Comprehensive income	$172,995	$46,405	$180,505	$106,694

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parentheticals) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
Tax on Unrealized gain (loss) on available for sale securities	($11)	($447)	$203	($226)
Tax on Net unrealized loss on derivatives	89	4	109	10
Tax on adjustment for postemployment benefit obligation	($112)	($202)	($223)	($405)

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES	'	'
Net income	$180,664	$105,675
Adjustments to reconcile net income to cash flows from operating activities:	'	'
Unrealized loss on derivative instruments	52,394	20,466
Depreciation and amortization	25,394	23,024
Allowance for equity used during construction	-603	-1,333
Allowance for bad debt expense	1,205	1,341
Deferred income taxes	22,970	14,639
Manufactured gas plant remediation costs	-1,845	-3,254
Equity in earnings of equity investees, net of distributions received	1,626	1,835
Cost of removal - asset retirement obligations	-164	-137
Contributions to postemployment benefit plans	-2,348	-23,102
Changes in:	'	'
Components of working capital	96,040	-44,510
Other noncurrent assets	6,038	5,198
Other noncurrent liabilities	2,071	8,539
Cash flows from operating activities	383,442	108,381
CASH FLOWS (USED IN) INVESTING ACTIVITIES	'	'
Utility plant expenditures	-59,971	-51,376
Solar and wind equipment expenditures	-45,403	-24,865
Real estate properties and other expenditures	-477	-298
Cost of removal expenditures	-10,914	-14,323
Distribution from equity investees in excess of equity in earnings	464	648
Proceeds from sale of asset	6,000	0
Withdrawal from restricted cash construction fund	85	0
Cash flows (used in) investing activities	-110,216	-90,214
CASH FLOWS (USED IN) FINANCING ACTIVITIES	'	'
Proceeds from issuance of common stock	7,757	6,922
Tax benefit from stock options exercised	94	79
Proceeds from sale-leaseback transaction	7,576	7,076
Proceeds from long-term debt	125,000	0
Payments of long-term debt	-65,017	-3,833
Purchases of treasury stock	-4,387	-1,311
Payments of common stock dividends	-35,264	-33,913
Net (payments)/proceeds from short-term debt	-302,400	8,300
Cash flows (used in) financing activities	-266,641	-16,680
Change in cash and cash equivalents	6,585	1,487
Cash and cash equivalents at beginning of period	2,969	4,509
Cash and cash equivalents at end of period	9,554	5,996
CHANGES IN COMPONENTS OF WORKING CAPITAL	'	'
Receivables	-294,939	-245,241
Inventories	178,955	92,822
Recovery of gas costs	6,866	-542
Gas purchases payable	138,044	88,263
Prepaid and accrued taxes	67,164	46,900
Accounts payable and other	3,992	-5,070
Restricted broker margin accounts	-21,329	-10,196
Customers' credit balances and deposits	-8,819	-30,579
Other current assets	26,106	19,133
Components of working capital	96,040	-44,510
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION	'	'
Cash paid for Interest (net of amounts capitalized)	11,221	10,207
Cash paid for Income taxes	8,648	4,111
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING ACTIVITIES	'	'
Accrued capital expenditures	$1,347	($9,463)

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2014	Sep. 30, 2013
In Thousands, unless otherwise specified
PROPERTY, PLANT AND EQUIPMENT	'	'
Utility plant, at cost	$1,726,124	$1,681,585
Construction work in progress	135,721	114,961
Solar equipment, real estate properties and other, at cost	269,613	249,516
Construction work in progress	36,172	9,093
Total property, plant and equipment	2,167,630	2,055,155
Accumulated depreciation and amortization, utility plant	-395,457	-383,895
Accumulated depreciation and amortization, solar equipment, real estate properties and other	-33,728	-28,144
Property, plant and equipment, net	1,738,445	1,643,116
CURRENT ASSETS	'	'
Cash and cash equivalents	9,554	2,969
Customer accounts receivable	'	'
Billed	487,941	240,281
Unbilled revenues	53,664	7,429
Allowance for doubtful accounts	-5,491	-5,330
Regulatory assets	18,970	34,372
Gas in storage, at average cost	139,021	314,477
Materials and supplies, at average cost	10,835	14,334
Prepaid and accrued taxes	431	42,645
Asset held for sale	0	5,428
Derivatives, at fair value	45,182	53,327
Restricted broker margin accounts	38,490	6,581
Deferred taxes	11,859	8,432
Other	25,603	20,953
Total current assets	836,059	745,898
NONCURRENT ASSETS	'	'
Investments in equity investees	160,228	161,591
Prepaid pension asset	6,126	6,287
Regulatory assets	368,319	402,202
Derivatives, at fair value	2,270	2,761
Other	49,763	42,928
Total noncurrent assets	586,706	615,769
Total assets	3,161,210	3,004,783
CAPITALIZATION	'	'
Common stock, $2.50 par value; authorized 75,000,000 shares; outstanding March 31, 2014-42,074,766; September 30, 2013-41,961,534	112,706	112,563
Premium on common stock	303,107	300,196
Accumulated other comprehensive (loss), net of tax	-1,780	-1,621
Treasury stock at cost and other; shares March 31, 2014-3,007,914; September 30, 2013-3,060,356	-125,085	-128,638
Retained earnings	750,234	604,884
Common stock equity	1,039,182	887,384
Long-term debt	628,490	512,886
Total capitalization	1,667,672	1,400,270
CURRENT LIABILITIES	'	'
Current maturities of long-term debt	21,526	68,643
Short-term debt	63,200	365,600
Gas purchases payable	392,857	254,813
Accounts payable and other	65,263	60,342
Dividends payable	17,665	17,624
Deferred and accrued taxes	26,914	4,040
Regulatory liabilities	20,360	1,456
New Jersey clean energy program	5,979	14,532
Derivatives, at fair value	71,223	40,390
Broker margin accounts	10,573	0
Customers' credit balances and deposits	15,574	24,393
Total current liabilities	711,134	851,833
NONCURRENT LIABILITIES	'	'
Deferred income taxes	401,537	372,773
Deferred investment tax credits	5,423	5,584
Deferred revenue	4,402	4,763
Derivatives, at fair value	5,192	2,458
Manufactured gas plant remediation	183,600	183,600
Postemployment employee benefit liability	68,494	67,897
Regulatory liabilities	76,857	79,647
Asset retirement obligation	29,534	28,711
Other	7,365	7,247
Total noncurrent liabilities	782,404	752,680
Commitments and contingent liabilities (Note 12)	'	'
Total capitalization and liabilities	$3,161,210	$3,004,783

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) (USD $)	Mar. 31, 2014	Sep. 30, 2013
Statement of Financial Position [Abstract]	'	'
Common stock, par value (usd per share)	$2.50	$2.50
Common stock, shares authorized	75,000,000	75,000,000
Common stock, shares outstanding	42,074,766	41,961,534
Treasury stock at cost and other, shares	3,007,914	3,060,356

NATURE_OF_THE_BUSINESS

NATURE OF THE BUSINESS	6 Months Ended
	Mar. 31, 2014
NATURE OF THE BUSINESS [Abstract]	'
NATURE OF THE BUSINESS	'
	NATURE OF THE BUSINESS
	New Jersey Resources Corporation provides regulated gas distribution services and operates certain non-regulated businesses primarily through the following subsidiaries:
	New Jersey Natural Gas Company provides natural gas utility service to approximately 503,700 retail customers in central and northern New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment;
	NJR Energy Services Company comprises the Energy Services segment that maintains and transacts around a portfolio of natural gas storage and transportation positions and provides wholesale energy and energy management services;
	NJR Clean Energy Ventures, the company’s unregulated distributed power subsidiary, comprises the Clean Energy Ventures segment and reports the results of operations and assets related to the Company's capital investments in distributed power projects, including commercial and residential solar projects and on-shore wind investments;
	NJR Midstream Holdings Corporation primarily invests in energy-related ventures through its subsidiaries, NJR Steckman Ridge Storage Company, which holds the Company's 50 percent combined interest in Steckman Ridge and NJNR Pipeline Company, which holds the Company's 5.53 percent ownership interest in Iroquois Gas Transmission L.P. Steckman Ridge and Iroquois comprise the Midstream segment. On November 7, 2013, NJR Energy Holdings Corporation changed its name to NJR Midstream Holdings Corporation; and
	NJR Retail Holdings Corporation has two principal subsidiaries, NJR Home Services Company and Commercial Realty & Resources Corporation. Retail Holdings and NJR Energy Corporation are included in Retail and Other operations.

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by NJR in accordance with the rules and regulations of the Securities and Exchange Commission and ASC 270. The September 30, 2013, Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in NJR's 2013 Annual Report on Form 10-K.
	The Unaudited Condensed Consolidated Financial Statements include the accounts of NJR and its subsidiaries. In the opinion of management, the accompanying Unaudited Condensed Consolidated Financial Statements reflect all adjustments necessary, for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of NJR's utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ended September 30, 2014.
	Intercompany transactions and accounts have been eliminated.
	Gas in Storage
	The following table summarizes gas in storage, at average cost by company as of:
		March 31,					September 30,
		2014					2013
	($ in thousands)	Gas in Storage				Bcf	Gas in Storage				Bcf
	NJNG		$	12,582		2.1		$	104,979		20.4
	NJRES		126,439			23.2		209,498			62.3
	Total		$	139,021		25.3		$	314,477		82.7
	Available for Sale Securities
	Included in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets are certain investments in equity securities of a publicly traded energy company that have a fair value of $11.2 million and $11.7 million as of March 31, 2014 and September 30, 2013, respectively. Total unrealized gains associated with these equity securities, which are included as a part of accumulated other comprehensive income, a component of common stock equity, were $8.6 million ($5.1 million, after tax) and $9.1 million ($5.4 million, after tax) as of March 31, 2014 and September 30, 2013, respectively. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.
	Sale of Asset
	On October 22, 2013, CR&R sold approximately 25.4 acres of undeveloped land located in Monmouth County with a net book value of $5.4 million for $6 million, generating a pre-tax gain after closing costs of $313,000, which was recognized in other income on the Unaudited Condensed Consolidated Statements of Operations.
	Customer Accounts Receivable
	Customer accounts receivable include outstanding billings from the following subsidiaries as of:
	(Thousands)	March 31,					September 30,
		2014					2013
	NJRES	$	328,544		67	%	$	194,263		81	%
	NJNG (1)	156,272			32		43,045			18
	NJRCEV	565			—		293			—
	NJRHS and other	2,560			1		2,680			1
	Total	$	487,941		100	%	$	240,281		100	%
	-1	Does not include unbilled revenues of $53.7 million and $7.4 million as of March 31, 2014 and September 30, 2013, respectively.
	Loan Receivable
	NJNG provides interest-free loans, with terms ranging from two to ten years, to customers that elect to purchase and install certain energy efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at net present value on the Unaudited Condensed Consolidated Balance Sheets. The Company has recorded $3 million and $1.9 million in other current assets and $21.9 million and $14.3 million in other noncurrent assets as of March 31, 2014 and September 30, 2013, respectively, on the Unaudited Condensed Consolidated Balance Sheets.
	NJR's policy is to establish an allowance for doubtful accounts when loan balances are outstanding for more than 60 days. As of March 31, 2014 and September 30, 2013, there was no allowance for doubtful accounts established.
	Recent Updates to the Accounting Standards Codification
	In December 2011, the FASB issued ASU No. 2011-11, an amendment to ASC Topic 210, Balance Sheet, requiring additional disclosures about the effect of an entity's rights of setoff and related master netting arrangements to its financial statements. ASU 2013-01, issued in January 2013, further clarified that the amended guidance was applicable to certain financial and derivative instruments. The Company applied the provisions of the amended guidance retrospectively effective October 1, 2013. The guidance did not impact the Company's financial position, results of operations or cash flows, however, it required additional disclosures that are included in Note 4. Derivative Instruments.
	In July 2013, the FASB issued ASU No. 2013-11, an amendment to ASC Topic 740, Income Taxes, which clarifies financial statement presentation for unrecognized tax benefits. The ASU requires that an unrecognized tax benefit, or portion thereof, shall be presented in the balance sheet as a reduction to a deferred tax asset for a net operating loss carryforward, similar tax loss or a tax credit carryforward. To the extent such a deferred tax asset is not available or the company does not intend to use it to settle any additional taxes that would result from the disallowance of a tax position, the related unrecognized tax benefit will be presented as a liability in the financial statements. The amended guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The Company will apply the provisions of the new guidance at the effective date, if applicable, on a prospective basis.

REGULATION

REGULATION	6 Months Ended
	Mar. 31, 2014
Regulated Operations [Abstract]	'
REGULATION	'
	REGULATION
	NJNG is subject to cost-based regulation, therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility investment based on the BPU's approval, in accordance with accounting guidance applicable to regulated operations. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities.
	Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets are comprised of the following:
	(Thousands)	March 31,		September 30,
		2014		2013
	Regulatory assets-current
	Conservation Incentive Program	$	—	$	18,887
	Underrecovered gas costs	12,991		953
	New Jersey Clean Energy Program	5,979		14,532
	Total current	$	18,970	$	34,372
	Regulatory assets-noncurrent
	Environmental remediation costs
	Expended, net of recoveries	$	32,661	$	46,968
	Liability for future expenditures	183,600		183,600
	Deferred income taxes	10,718		10,718
	Derivatives at fair value, net	—		19
	SAVEGREEN	23,988		30,004
	Postemployment and other benefit costs	98,029		101,415
	Deferred Superstorm Sandy costs	15,207		14,822
	Other	4,116		14,656
	Total noncurrent	$	368,319	$	402,202
	Regulatory liability-current
	Conservation Incentive Program	$	5,964	$	—
	Derivatives at fair value, net	14,396		1,456
	Total current	$	20,360	$	1,456
	Regulatory liabilities-noncurrent
	Cost of removal obligation	$	75,327	$	79,315
	Other	1,530		332
	Total noncurrent	$	76,857	$	79,647
	NJNG's recovery of costs is facilitated through its base tariff rates, BGSS and other regulatory tariff riders. As recovery of regulatory assets is subject to BPU approval, if there are any changes in regulatory positions that indicate recovery is not probable, the related cost would be charged to income in the period of such determination.
	Recent regulatory filings and/or actions include the following:
	•	On September 18, 2013, the BPU approved NJNG's filing to reduce the USF recovery rate resulting in a .5 percent decrease for the average residential heating customer effective October 1, 2013.
	•	On October 16, 2013, the BPU provisionally approved NJNG's filing to maintain its current BGSS rate along with reductions to its CIP factors effective November 1, 2013 which resulted in a 1 percent reduction to an average residential heat customer's bill.
	•	On November 21, 2013, NJNG notified the BPU of its intent to reduce its BGSS rate, effective December 1, 2013, resulting in a 6 percent decrease to the average residential heating customer bill.
	•	On November 22, 2013, the BPU provisionally approved a Stipulation of Settlement for SBC factors that included recovery of MGP expenditures through June 30, 2013 and a .2 percent reduction to the average residential heat customer related to the SBC RA factor to recover $18.7 million annually, and a 1.9 percent increase related to its NJCEP factor, effective December 1, 2013.
	•	On December 18, 2013, the BPU approved a gas service agreement which will allow NJNG to provide transportation service to Red Oak Power, LLC, an electric generation facility, through September 2022.
	•	On April 23, 2014, the BPU approved a petition filed by NJNG requesting authorization over a three-year period to issue up to $300 million of medium-term notes with a maturity of not more than 30 years, renew its revolving credit facility expiring August 2014 for up to five years, enter into interest rate risk management transactions related to debt securities and redeem, refinance or defease any of NJNG’s outstanding long-term debt securities.

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	6 Months Ended
	Mar. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
DERIVATIVE INSTRUMENTS	'
	DERIVATIVE INSTRUMENTS
	The Company is subject to commodity price risk due to fluctuations in the market price of natural gas, SREC, and electricity prices. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs, and electricity. In addition, the Company may utilize foreign currency derivatives as cash flow hedges of Canadian dollar denominated gas purchases. These contracts, with a few exceptions as described below, are accounted for as derivatives. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company's fair value measurement policies and level disclosures associated with the NJR's derivative instruments, see Note 5. Fair Value.
	Since the Company chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS as appropriate, changes in the fair value of these derivative instruments are recorded as a component of gas purchases or operating revenues, as appropriate for NJRES, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or (losses). For NJRES at settlement, realized gains and (losses) on all financial derivative instruments are recognized as a component of gas purchases and realized gains and (losses) on all physical derivatives follow the presentation of the related unrealized gains and (losses) as a component of either gas purchases or operating revenues.
	NJRES also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the US dollar. NJRES utilizes foreign currency derivatives to lock in the currency translation rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are being used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company has designated these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in OCI. When the foreign exchange contracts are settled and the related purchases are recognized in income, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.
	As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that may ultimately be repaid, based on changes in forward natural gas prices during the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings.
	Changes in fair value of NJNG's financial derivative instruments are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets, as NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff for gas service.
	The Company elects NPNS accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, gains or (losses) are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered.
	NJRCEV hedges certain of its expected production of SRECs through forward sale contracts. The Company intends to physically deliver the SRECs upon settlement and therefore applies NPNS accounting treatment to the contracts. NJRCEV recognizes revenue for SRECs upon transfer of the certificate.
	Fair Value of Derivatives
	The following table reflects the fair value of NJR's derivative assets and liabilities recognized on the Unaudited Condensed Consolidated Balance Sheets as of:
				Fair Value
				March 31, 2014								September 30, 2013
	(Thousands)	Balance Sheet Location	Asset				Liability				Asset				Liability
			Derivatives				Derivatives				Derivatives				Derivatives
	Derivatives designated as hedging instruments:
	NJRES:
	Foreign currency contracts	Derivatives - current		$	—			$	277			$	16			$	3
		Derivatives - noncurrent		—				7				—				2
	Fair value of derivatives designated as hedging instruments			$	—			$	284			$	16			$	5
	Derivatives not designated as hedging instruments:
	NJNG:
	Financial derivative contracts	Derivatives - current		$	15,387			$	998			$	3,502			$	2,045
		Derivatives - noncurrent		—				—				121				140
	NJRES:
	Physical forward commodity contracts	Derivatives - current		5,634				35,568				11,282				14,573
		Derivatives - noncurrent		197				111				541				22
	Financial derivative contracts	Derivatives - current		24,161				34,380				38,527				23,769
		Derivatives - noncurrent		2,073				5,074				2,099				2,294
	Fair value of derivatives not designated as hedging instruments			$	47,452			$	76,131			$	56,072			$	42,843
	Total fair value of derivatives			$	47,452			$	76,415			$	56,088			$	42,848
	At March 31, 2014, the gross notional amount of the foreign currency transactions was approximately $6.9 million, and ineffectiveness in the hedge relationship is immaterial to the financial results of NJR.
	Offsetting of Derivatives
	NJR transacts under master netting arrangements or similar agreements that allow it to offset derivative assets and liabilities with the same counterparty, however NJR's policy is to present its derivative assets and liabilities on a gross basis in the Unaudited Condensed Consolidated Balance Sheets. The tables below summarize the reported gross amounts, the amounts that NJR has the right to offset but elects not to, financial collateral, as well as the net amounts NJR could present in the Unaudited Condensed Consolidated Balance Sheets but elects not to.
	(Thousands)	Amounts Presented in Balance Sheets (1)				Offsetting Derivative Instruments (2)				Financial Collateral Received/Pledged (3)				Net Amounts (4)
	As of March 31, 2014:
	Derivative assets:
	NJRES
	Physical forward commodity contracts		$	5,831			$	(2,190	)		$	—			$	3,641
	Financial commodity contracts		26,234				(26,234		)		—				—
	Foreign currency contracts		—				—				—				—
	Total NJRES		$	32,065			$	(28,424	)		$	—			$	3,641
	NJNG
	Financial commodity contracts		$	15,387			$	(998	)		$	(10,772	)		$	3,617
	Derivative liabilities:
	NJRES
	Physical forward commodity contracts		$	35,679			$	(2,371	)		$	(500	)		$	32,808
	Financial commodity contracts		39,454				(26,233		)		(13,221		)		—
	Foreign currency contracts		284				—				—				284
	Total NJRES		$	75,417			$	(28,604	)		$	(13,721	)		$	33,092
	NJNG
	Financial commodity contracts		$	998			$	(998	)		$	—			$	—
	As of September 30, 2013:
	Derivative assets:
	NJRES
	Physical forward commodity contracts		$	11,823			$	(3,549	)		$	(100	)		$	8,174
	Financial commodity contracts		40,626				(26,063		)		6,870				21,433
	Foreign currency contracts		16				(5		)		—				11
	Total NJRES		$	52,465			$	(29,617	)		$	6,770			$	29,618
	NJNG
	Financial commodity contracts		$	3,623			$	(2,185	)		$	214			$	1,652
	Derivative liabilities:
	NJRES
	Physical forward commodity contracts		$	14,595			$	(3,549	)		$	(500	)		$	10,546
Financial commodity contracts		26,063				(26,063		)		—				—
Foreign currency contracts		5				(5		)		—				—
Total NJRES		$	40,663			$	(29,617	)		$	(500	)		$	10,546
NJNG
Financial commodity contracts		$	2,185			$	(2,185	)		$	—			$	—
-1	Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.
-2	Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.
-3	Financial collateral includes cash balances at FCM's as well as cash received from or pledged to other counterparties.
-4	Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.
NJRES utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical gas for injection into storage and the subsequent sale of physical gas at a later date. The gains or (losses) on the financial transactions that are economic hedges of the cost of the purchased gas are recognized prior to the gains or (losses) on the physical transaction, which are recognized in earnings when the natural gas is sold. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments creates volatility in the results of NJRES, although the Company's intended economic results relating to the entire transaction are unaffected.
The following table reflects the effect of derivative instruments on the Unaudited Condensed Consolidated Statements of Operations as of:
(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized
		in income on derivatives
		Three Months Ended							Six Months Ended
		March 31,							March 31,
Derivatives not designated as hedging instruments:		2014				2013			2014				2013
NJRES:
Physical commodity contracts	Operating revenues	$	(57,916	)		$	(2,224	)	$	(57,998	)		$	(7,859	)
Physical commodity contracts	Gas purchases	(54,481		)		2,762			(79,474		)		2,556
Financial derivative contracts	Gas purchases	(101,629		)		(30,669		)	(141,699		)		(1,467		)
Total unrealized and realized (losses)		$	(214,026	)		$	(30,131	)	$	(279,171	)		$	(6,770	)
Not included in the previous table, are gains associated with NJNG's financial derivatives that totaled $6.2 million and $12.4 million for the three months ended March 31, 2014 and 2013, respectively, and gains that totaled $12.8 million and $6.2 million for the six months ended March 31, 2014 and 2013, respectively. These derivatives are part of NJNG's risk management activities that relate to its natural gas purchases and BGSS incentive programs. As these transactions are entered into pursuant to and recoverable through regulatory riders, any changes in the value of NJNG's financial derivatives are deferred in regulatory assets or liabilities resulting in no impact to earnings.
As previously noted, NJRES designates its foreign exchange contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges are recorded in OCI and, upon settlement of the contracts, realized gains and (losses) are reclassified from OCI to gas purchases on the Unaudited Condensed Consolidated Statements of Operations. The following tables reflect the effect of derivative instruments designated as cash flow hedges on OCI as of March 31:
(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)						Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Three Months Ended						Three Months Ended						Three Months Ended
	March 31,						March 31,						March 31,
Derivatives in cash flow hedging relationships:	2014			2013			2014			2013			2014			2013
Foreign currency contracts	$	(309	)	$	24		$	68		$	(35	)	$	—		$	—
(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion) (1)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)						Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Six Months Ended						Six Months Ended						Six Months Ended
	March 31,						March 31,						March 31,
Derivatives in cash flow hedging relationships:	2014			2013			2014			2013			2014			2013
Foreign currency contracts	$	(460	)	$	(71	)	$	165		$	44		$	—		$	—
-1	The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $277,000 from OCI into earnings. The maximum tenor is April 2015.
NJNG and NJRES had the following outstanding long (short) derivatives as of:
			Volume (Bcf)
			March 31,		September 30,
			2014		2013
NJNG	Futures		27.5		22.6
NJRES	Futures		(20.9	)	(64.2	)
	Options		—		1.5
	Physical		31		7.3
Broker Margin
Generally, exchange-traded futures contracts require posted collateral, referred to as margin, usually in the form of cash. The amount of margin required is comprised of a fixed initial amount based on the contract and a variable amount based on market price movements from the initial trade price. The Company maintains separate broker margin accounts for NJNG and NJRES. The balances by company, are as follows:
(Thousands)	Balance Sheet Location	March 31,			September 30,
		2014			2013
NJNG	Broker margin - Current assets	$	—		$	213
NJNG	Broker margin - Current (liabilities)	$	(10,573	)	$	—
NJRES	Broker margin - Current assets	$	38,490		$	6,368
Wholesale Credit Risk
NJNG and NJRES are exposed to credit risk as a result of their wholesale marketing activities. In addition, NJRCEV engages in SREC sales. As a result of the inherent volatility in the prices of natural gas commodities, derivatives and SRECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty failed to perform the obligations under its contract (e.g., failed to deliver or pay for natural gas), then the Company could sustain a loss.
NJR monitors and manages the credit risk of its wholesale marketing operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of current and prospective counterparties' financial statements and/or credit ratings, daily monitoring of counterparties' credit limits and exposure, daily communication with traders regarding credit status and the use of credit mitigation measures, such as collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit. Collateral may be requested due to NJR's election not to extend credit or because exposure exceeds defined thresholds. Most of NJR's wholesale marketing contracts contain standard netting provisions. These contracts include those governed by ISDA and the NAESB. The netting provisions refer to payment netting, whereby receivables and payables with the same counterparty are offset and the resulting net amount is paid to the party to which it is due.
The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of March 31, 2014. Internally-rated exposure applies to counterparties that are not rated by S&P or Moody's. In these cases, the Company's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by S&P and/or Moody's are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received. The amounts presented below have not been reduced by any collateral received or netting and exclude accounts receivable for NJNG retail natural gas sales and services.
(Thousands)	Gross Credit Exposure
Investment grade		$	299,185
Noninvestment grade		6,104
Internally rated investment grade		43,953
Internally rated noninvestment grade		27,356
Total		$	376,598
Conversely, certain of NJNG's and NJRES' derivative instruments are linked to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG's credit rating were to fall below its current level. NJNG's credit rating, with respect to S&P, reflects the overall corporate credit profile of NJR. Specifically, most, but not all, of these additional payments will be triggered if NJNG's debt is downgraded by the major credit agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings, but are based on certain financial metrics.
Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company's credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on March 31, 2014 and September 30, 2013, was $200,000 and $2 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on March 31, 2014 and September 30, 2013, the Company would have been required to post an additional $200,000 and $1.1 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.

FAIR_VALUE

FAIR VALUE	6 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
FAIR VALUE	'
	FAIR VALUE
	Fair Value of Assets and Liabilities
	The fair value of cash and temporary investments, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. Non-current loan receivables are recorded based on what the company expects to receive, which approximates fair value. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.
	The estimated fair value of long-term debt, including current maturities and excluding capital leases, is as follows:
	(Thousands)	March 31,			September 30,
		2014			2013
	Carrying value	$	594,845		$	529,845
	Fair market value	$	622,213		$	556,518
	NJR utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific issue and the Company's credit rating. As of March 31, 2014, NJR discloses its debt within Level 2 of the fair value hierarchy.
	Fair Value Hierarchy
	NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following:
	Level 1	Unadjusted quoted prices for identical assets or liabilities in active markets. NJR's Level 1 assets and liabilities include exchange traded futures and options contracts, listed equities, and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX/CME and ICE that NJR refers internally to as basis swaps, fixed swaps, futures and options that are cleared through a FCM.
	Level 2	Other significant observable inputs such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input was considered to be a “model”, it would still be considered to be a Level 2 input as:
	1)     The data is widely accepted and public
	2)    The data is non-proprietary and sourced from an independent third party
	3)    The data is observable and published
	These additional adjustments are generally not considered to be significant to the ultimate recognized values.
	Level 3	Inputs derived from a significant amount of unobservable market data; these include NJR's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.
	Assets and liabilities measured at fair value on a recurring basis are summarized as follows:
		Quoted Prices in Active Markets for Identical Assets					Significant Other Observable Inputs			Significant
										Unobservable
										Inputs
	(Thousands)	(Level 1)					(Level 2)			(Level 3)			Total
	As of March 31, 2014:
	Assets:
	Physical forward commodity contracts		$	—				$	5,832		$	—	$	5,832
	Financial derivative contracts - natural gas		41,620					—			—		41,620
	Financial derivative contracts - foreign exchange		—					—			—		—
	Available for sale equity securities - energy industry (1)		11,218					—			—		11,218
	Other (2)		1,263					—			—		1,263
	Total assets at fair value		$	54,101				$	5,832		$	—	$	59,933
	Liabilities:
	Physical forward commodity contracts		$	—				$	35,680		$	—	$	35,680
	Financial derivative contracts - natural gas		40,451					—			—		40,451
	Financial derivative contracts - foreign exchange		—					284			—		284
	Total liabilities at fair value		$	40,451				$	35,964		$	—	$	76,415
	As of September 30, 2013:
	Assets:
	Physical forward commodity contracts		$	—				$	11,823		$	—	$	11,823
	Financial derivative contracts - natural gas		44,249					—			—		44,249
	Financial derivative contracts - foreign exchange		—					16			—		16
	Available for sale equity securities - energy industry (1)		11,716					—			—		11,716
	Other (2)		1,129					—			—		1,129
	Total assets at fair value		$	57,094				$	11,839		$	—	$	68,933
	Liabilities:
	Physical forward commodity contracts		$	—				$	14,595		$	—	$	14,595
	Financial derivative contracts - natural gas		28,248					—			—		28,248
	Financial derivative contracts - foreign exchange		—					5			—		5
	Total liabilities at fair value		$	28,248				$	14,600		$	—	$	42,848
	-1	Included in Other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets.
	-2	Includes various money market funds.

INVESTMENTS_IN_EQUITY_INVESTEE

INVESTMENTS IN EQUITY INVESTEES	6 Months Ended
	Mar. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]	'
INVESTMENTS IN EQUITY INVESTEES	'
	INVESTMENTS IN EQUITY INVESTEES
	Investment in equity investees includes NJR's equity method and cost method investments.
	Equity Method Investments
	(Thousands)	March 31,		September 30,
		2014		2013
	Steckman Ridge	$	129,171	$	129,707
	Iroquois	23,166		23,084
	Total	$	152,337	$	152,791
	As of March 31, 2014, the investment in Steckman Ridge includes loans with a total outstanding principal balance of $70.4 million. The loans accrue interest at a variable rate that resets quarterly and are due October 1, 2023.
	NJRES and NJNG have entered into transportation, storage and park and loan agreements with Steckman Ridge and Iroquois. See Note 14. Related Party Transactions for more information on these intercompany transactions.
	Cost Method Investments
	During the fourth quarter of fiscal 2012, NJR invested $8.8 million in OwnEnergy, a developer of on-shore wind projects, for an 18.7 percent ownership interest and the right, but not the obligation, to purchase certain qualified projects. This investment is accounted for in accordance with the cost method of accounting.
	On October 11, 2013, NJRCEV acquired the development rights of the Two Dot wind project in Montana, which is its first onshore wind project. NJRCEV expects to invest approximately $22 million to construct the 9.7 MW wind project, which NJRCEV expects to be operational in the third quarter of fiscal 2014. In the second quarter of 2014, NJRCEV acquired the development rights to its second wind project, a $42 million, 20 MW wind farm currently under construction in Carroll County, Iowa, which NJRCEV expects to be operational in the second quarter of fiscal 2015.

EARNINGS_PER_SHARE

EARNINGS PER SHARE	6 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
EARNINGS PER SHARE	'
	EARNINGS PER SHARE
	The following table presents the calculation of the Company's basic and diluted earnings per share for:
		Three Months Ended				Six Months Ended
		March 31,				March 31,
	(Thousands, except per share amounts)	2014		2013		2014		2013
	Net income	$	172,971	$	45,469	$	180,664	$	105,675
	Basic earnings per share
	Weighted average shares of common stock outstanding-basic	42,079		41,789		42,050		41,742
	Basic earnings per common share	$4.11		$1.09		$4.30		$2.53
	Diluted earnings per share
	Weighted average shares of common stock outstanding-basic	42,079		41,789		42,050		41,742
	Incremental shares (1)	378		183		378		183
	Weighted average shares of common stock outstanding-diluted	42,457		41,972		42,428		41,925
	Diluted earnings per common share (2)	$4.07		$1.08		$4.26		$2.52
	-1	Incremental shares consist of stock options, stock awards and performance units.
	-2	There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and six months ended March 31, 2014 and 2013.

COMMON_STOCK_EQUITY

COMMON STOCK EQUITY	6 Months Ended
	Mar. 31, 2014
Equity [Abstract]	'
COMMON STOCK EQUITY	'
	COMMON STOCK EQUITY
	Changes in common stock equity during the six months ended March 31, 2014, are as follows:
	(Thousands)	Number of Shares		Common Stock			Premium on Common Stock			Accumulated Other Comprehensive (Loss) Income					Treasury Stock And Other			Retained Earnings			Total
	Balance as of September 30, 2013	41,962		$	112,563		$	300,196			$	(1,621	)		$	(128,638	)	$	604,884		$	887,384
	Net income																	180,664			180,664
	Other comprehensive (loss)										(159		)								(159		)
	Common stock issued under stock plans	224		143			2,817								6,741						9,701
	Tax benefits from stock plans						94														94
	Cash dividend declared ($.84 per share)																	(35,314		)	(35,314		)
	Treasury stock and other	(111	)												(3,188		)				(3,188		)
	Balance as of March 31, 2014	42,075		$	112,706		$	303,107			$	(1,780	)		$	(125,085	)	$	750,234		$	1,039,182
	Accumulated Other Comprehensive Income
	The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects:
	(Thousands)	Available for Sale Securities				Cash Flow Hedges				Postemployment Benefit Obligation				Total
	Balance as of September 30, 2013	$	5,400			$	12			$	(7,033	)		$	(1,621	)
	Other comprehensive income, net of tax
	Other comprehensive (loss), before reclassifications, net of tax of $203, $169, $-, $372	(295		)		(291		)		—				(586		)
	Amounts reclassified from accumulated other comprehensive income, net of tax of $-, $(60), $(223), $(283)	—				105			(1)	322			(2)	427
	Net current-period other comprehensive (loss) income, net of tax of $203, $109, $(223), $89	(295		)		(186		)		322				(159		)
	Balance as of March 31, 2014	$	5,105			$	(174	)		$	(6,711	)		$	(1,780	)
	Balance as of September 30, 2012	$	4,921			$	51			$	(15,743	)		$	(10,771	)
	Other comprehensive income, net of tax
	Other comprehensive income, before reclassifications, net of tax of $(226), $26, $-, $(200)	327				(45		)		—				282
	Amounts reclassified from accumulated other comprehensive income, net of tax of $-, $(16) $(406), $(422)	—				28			(1)	709			(2)	737
	Net current-period other comprehensive income, net of tax of $(226), $10, $(406), $(622)	327				(17		)		709				1,019
	Balance as of March 31, 2013	$	5,248			$	34			$	(15,034	)		$	(9,752	)
	-1	Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases in the Unaudited Condensed Consolidated Statements of Operations.
	-2	Included in the computation of net periodic pension cost, a component of operations and maintenance expense in the Unaudited Condensed Consolidated Statements of Operations.

DEBT

DEBT	6 Months Ended
	Mar. 31, 2014
Debt Disclosure [Abstract]	'
DEBT	'
	DEBT
	NJR and NJNG finance working capital requirements and capital expenditures through the issuance of various short-term debt and long-term financing arrangements, including a commercial paper program, committed unsecured credit facilities and private placement debt shelf facilities. Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit. Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.
	Credit Facilities
	On January 24, 2014, NJR entered into an agreement for a $50 million unsecured committed credit line. The credit line was put in place primarily to provide additional working capital to NJRES to meet any potential margin calls that may arise in NJRES’ normal course of business. Effective January 31, 2014, NJR utilized the accordion option available under the NJR Credit Facility to increase the amount of credit available from $325 million to $425 million and the additional credit line was thereby terminated on the same date.
	A summary of NJR's credit facility and NJNG's commercial paper program and credit facility are as follows:
	(Thousands)	March 31,			September 30,			Expiration Dates
		2014			2013
	NJR
	Bank revolving credit facility (1)	$	425,000		$	325,000		Aug-17
	Notes outstanding at end of period	$	15,200		$	97,000
	Weighted average interest rate at end of period	1.15		%	1		%
	Amount available at end of period (2)	$	384,459		$	210,110
	Bank term loan (3)	$	100,000		$	100,000		Sep-14
	Loan outstanding at end of period	$	—		$	100,000
	Weighted average interest rate at end of period	—		%	0.74		%
	Amount available at end of period	$	100,000		$	—
	Bank letter of credit facility (3) (4)	$	10,000		$	10,000		Jun-14
	NJNG
	Bank credit facility dedicated to EDA Bonds (1) (4)	$	100,000		$	100,000		Aug-15
	Bank revolving credit facility (1)	$	250,000		$	250,000		Aug-14
	Commercial paper outstanding at end of period	$	48,000		$	168,600
	Weighted average interest rate at end of period	0.12		%	0.13		%
	Amount available at end of period (5)	$	201,269		$	81,400
	-1	Committed credit facilities, which require commitment fees on the unused amounts.
	-2	Letters of credit outstanding total $25.3 million and $17.9 million as of March 31, 2014 and September 30, 2013, respectively, which reduces amount available by the same amount.
	-3	Uncommitted.
	-4	There were no borrowings outstanding as of March 31, 2014 and September 30, 2013, respectively.
	-5	Letters of credit outstanding total $731,000 and $266,000 as of March 31, 2014 and September 30, 2013, respectively, which reduces the amount available by the same amount.
	NJR Long-term Debt
	On May 12, 2011, NJR entered into an unsecured, uncommitted $100 million private placement shelf note agreement allowing NJR to issue senior notes during a two-year issuance period, which expired on May 10, 2013. As of March 31, 2014, NJR had two series of notes outstanding under this agreement, $25 million at 1.94 percent, which will mature on September 15, 2015 and $25 million at 2.51 percent, which will mature on September 15, 2018.
	On June 30, 2011, NJR entered into an unsecured, uncommitted $75 million private placement shelf note agreement allowing NJR to issue senior notes during a three-year issuance period ending June 30, 2014. As of March 31, 2014, NJR had $50 million at 3.25 percent outstanding, which will mature on September 17, 2022, under this agreement.
	On September 26, 2013, NJR entered into an unsecured, uncommitted $100 million private placement shelf note agreement allowing NJR to issue senior notes during a three-year issuance period ending September 26, 2016. As of March 31, 2014, $100 million remains available for borrowing under this facility.
	NJNG Long-term Debt
	On March 13, 2014, NJNG issued $70 million of 3.58 percent senior notes due March 13, 2024, and $55 million of 4.61 percent senior notes due March 13, 2044, secured by FMB in the private placement market pursuant to a note purchase agreement entered into on February 7, 2014. The proceeds were used to pay down short-term debt and redeem its $60 million, 4.77 percent private placement bonds.
	During the second quarter of fiscal 2014, management decided to redeem the $12 million, 5 percent Series HH bonds, which were callable as of December 1, 2013. On April 10, 2014, NJNG provided notice to bond holders that the bonds will be redeemed on May 27, 2014. As of March 31, 2014, the bonds have been reclassified to current maturities of long-term debt on the Unaudited Condensed Consolidated Balance Sheets.
	NJNG received $7.6 million and $7.1 million in December 2013 and 2012, respectively, in connection with the sale-leaseback of its natural gas meters. NJNG records a capital lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease.

EMPLOYEE_BENEFIT_PLANS

EMPLOYEE BENEFIT PLANS	6 Months Ended
	Mar. 31, 2014
Compensation and Retirement Disclosure [Abstract]	'
EMPLOYEE BENEFIT PLANS	'
	EMPLOYEE BENEFIT PLANS
	Pension and Other Postemployment Benefit Plans
	The components of the net periodic cost for pension benefits, including the Company's Pension Equalization Plan, and OPEB costs (principally health care and life insurance) for employees and covered dependents were as follows:
		Pension												OPEB
		Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
		March 31,						March 31,						March 31,						March 31,
	(Thousands)	2014			2013			2014			2013			2014			2013			2014			2013
	Service cost	$	1,536		$	1,718		$	3,072		$	3,436		$	981		$	1,171		$	1,962		$	2,342
	Interest cost	2,517			2,235			5,033			4,470			1,433			1,287			2,866			2,574
	Expected return on plan assets	(3,869		)	(3,706		)	(7,738		)	(7,412		)	(1,043		)	(913		)	(2,087		)	(1,826		)
	Recognized actuarial loss	1,399			1,911			2,798			3,822			625			964			1,250			1,928
	Prior service cost amortization	28			27			56			54			(89		)	7			(178		)	14
	Recognized net initial obligation	—			—			—			—			2			(89		)	5			(178		)
	Net periodic benefit cost	$	1,611		$	2,185		$	3,221		$	4,370		$	1,909		$	2,427		$	3,818		$	4,854
	The Company does not expect to be required to make additional contributions to fund the pension plans over the next three fiscal years based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets, interest rates and changes in the demographics of eligible employees and covered dependents. In addition, as in the past, the Company may elect to make contributions in excess of the minimum required amount to the plans. NJR made a discretionary contribution of $20 million to the pension plans during fiscal 2013. There have been no discretionary contributions made during the six months ended March 31, 2014.

INCOME_TAXES

INCOME TAXES	6 Months Ended
	Mar. 31, 2014
Income Tax Disclosure [Abstract]	'
INCOME TAXES	'
	INCOME TAXES
	NJR evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with unrecognized tax benefits. During the six months ended March 31, 2014 and 2013, based on its analysis, the Company determined that there was no need to recognize any liabilities associated with uncertain tax positions.
	The effective tax rates for the six months ended March 31, 2014 and 2013, are 28.8 percent and 25.4 percent, respectively. The increased tax rate is due primarily to a significant year over year increase in the forecasted pre-tax income. This increase is partially offset by the impact of increased forecasted ITCs, net of deferred taxes, and PTCs of $18.9 million and $13.4 million for the fiscal years ended September 30, 2014 and 2013, respectively.
	To calculate the estimated annual effective tax rate, NJR considers solar and wind projects that are probable of being completed and placed in service during the current fiscal year based on the best information available at each reporting period. The estimate includes an assessment of various factors, such as board of director approval, status of contractual agreements, permitting, regulatory approval and interconnection. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.
	As of March 31, 2014, the Company has state income tax net operating losses of approximately $125.3 million, which generally have a life of 20 years. The Company has recorded a deferred state tax asset of approximately $7.3 million on the Unaudited Condensed Consolidated Balance Sheets, reflecting the tax benefit associated with the loss carryforwards. In addition, as of March 31, 2014, the Company has recorded a valuation allowance of $229,000 because it believes that it is more likely than not that the deferred tax assets related to CR&R and NJR will expire unused. As of September 30, 2013, the Company had a state income tax net operating losses of approximately $104.4 million, a deferred state tax asset of approximately $6.1 million and a valuation allowance of $262,000.
	As of September 30, 2013, the Company had an ITC carryforward of approximately $40 million, which has a life of 20 years. The Company expects to utilize the entire carryforward.

COMMITMENTS_AND_CONTINGENT_LIA

COMMITMENTS AND CONTINGENT LIABILITIES	6 Months Ended
	Mar. 31, 2014
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENT LIABILITIES	'
	COMMITMENTS AND CONTINGENT LIABILITIES
	Cash Commitments
	NJNG has entered into long-term contracts, expiring at various dates through August 2030, for the supply, storage and delivery of natural gas. These contracts include current annual fixed charges of approximately $95.1 million at current contract rates and volumes, which are recoverable through BGSS.
	For the purpose of securing storage and pipeline capacity, NJRES enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by NJRES to maintain the ability to access such natural gas storage or pipeline capacity, during a fixed time period, which generally ranges from one to ten years. Demand charges are established by storage and pipeline operators and regulated by the FERC. These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and transport natural gas utilizing their respective assets.
	Commitments as of March 31, 2014, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:
	(Thousands)	2014		2015		2016		2017		2018		Thereafter
	NJRES:
	Natural gas purchases	$	320,608	$	99,106	$	15,452	$	—	$	—	$	—
	Storage demand fees	15,571		20,773		9,931		5,425		3,318		4,000
	Pipeline demand fees	35,978		43,174		33,561		18,307		12,548		7,175
	Sub-total NJRES	$	372,157	$	163,053	$	58,944	$	23,732	$	15,866	$	11,175
	NJNG:
	Natural gas purchases	$	55,132	$	107,920	$	6,522	$	113	$	—	$	—
	Storage demand fees	12,995		20,611		13,285		10,883		9,299		13,948
	Pipeline demand fees	32,139		74,142		43,312		34,247		33,978		194,675
	Sub-total NJNG	$	100,266	$	202,673	$	63,119	$	45,243	$	43,277	$	208,623
	Total (1)	$	472,423	$	365,726	$	122,063	$	68,975	$	59,143	$	219,798
	-1	Does not include amounts related to intercompany asset management agreements between NJRES and NJNG.
	Legal Proceedings
	Manufactured Gas Plant Remediation
	NJNG is responsible for the remedial cleanup of five MGP sites, dating back to gas operations in the late 1800s and early 1900s that contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the NJDEP, as well as participating in various studies and investigations by outside consultants, to determine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action, where warranted, under Administrative Consent Orders or Memoranda of Agreement with the NJDEP.
	NJNG may, subject to BPU approval, recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RA approved by the BPU. In July 2013, NJNG requested approval of its MGP expenditures incurred through June 2013 as well as a reduction in the SBC RA factor to recover $18.7 million annually. The petition was provisionally approved by the BPU on November 22, 2013. As of March 31, 2014, $32.7 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets.
	NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the review that total future expenditures to remediate and monitor the five MGP sites for which it is responsible, including potential liabilities for Natural Resource Damages that might be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites, will range from approximately $159.8 million to $261.2 million. NJNG's estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the best estimated amount in the range. If no point within the range is more likely than the other, it is NJNG's policy to accrue the lower end of the range. Accordingly, as of March 31, 2014, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $183.6 million on the Unaudited Condensed Consolidated Balance Sheets, based on the best estimate. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries.
	NJNG will continue to seek recovery of MGP-related costs through the RA. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination. However, because recovery of such costs is subject to BPU approval, there can be no assurance as to the ultimate recovery through the RA or the impact on the Company's results of operations, financial position or cash flows, which could be material.
	General
	The Company is party to various other claims, legal actions and complaints arising in the ordinary course of business. In the Company's opinion, the ultimate disposition of these matters will not have a material effect on its financial condition, results of operations or cash flows.

BUSINESS_SEGMENT_AND_OTHER_OPE

BUSINESS SEGMENT AND OTHER OPERATIONS DATA	6 Months Ended
	Mar. 31, 2014
Segment Reporting [Abstract]	'
BUSINESS SEGMENT AND OTHER OPERATIONS DATA	'
	BUSINESS SEGMENT AND OTHER OPERATIONS DATA
	NJR organizes its businesses based on its products and services as well as regulatory environment. As a result, the Company manages the businesses through the following reportable segments and other operations: the Natural Gas Distribution segment consists of regulated energy and off-system, capacity and storage management operations; the Energy Services segment consists of unregulated wholesale energy operations; the Clean Energy Ventures segment consists of capital investments in distributed power projects; the Midstream segment consists of NJR's investments in natural gas transportation and storage facilities; the Retail and Other operations consist of heating, cooling and water appliance installation and services, commercial real estate development, other investments and general corporate activities.
	Information related to the Company's various business segments and other operations is detailed below:
		Three Months Ended						Six Months Ended
		March 31,						March 31,
	(Thousands)	2014			2013			2014			2013
	Operating revenues
	Natural Gas Distribution
	External customers	$	394,528		$	351,750		$	627,997		$	570,599
	Energy Services
	External customers (1)	1,173,835			599,362			1,807,526			1,102,997
	Intercompany	67,749			4,444			71,767			4,551
	Clean Energy Ventures
	External customers	2,679			1,440			4,852			4,619
	Subtotal	1,638,791			956,996			2,512,142			1,682,766
	Retail and Other
	External customers	8,527			8,334			17,599			18,689
	Intercompany	297			186			499			449
	Eliminations	(68,046		)	(4,631		)	(72,266		)	(5,000		)
	Total	$	1,579,569		$	960,885		$	2,457,974		$	1,696,904
	Depreciation and amortization
	Natural Gas Distribution	$	9,972		$	9,399		$	19,807		$	18,676
	Energy Services	13			11			25			22
	Clean Energy Ventures	2,635			2,104			5,146			3,935
	Midstream	2			1			3			3
	Subtotal	12,622			11,515			24,981			22,636
	Retail and Other	208			199			415			390
	Eliminations	(2		)	7			(2		)	(2		)
	Total	$	12,828		$	11,721		$	25,394		$	23,024
	Interest income (2)
	Natural Gas Distribution	$	181		$	146		$	442		$	313
	Midstream	270			263			538			534
	Subtotal	451			409			980			847
	Retail and Other	—			1			—			2
	Eliminations	(235		)	(218		)	(468		)	(450		)
	Total	$	216		$	192		$	512		$	399
	-1	Includes sales to Canada, which accounted for 4 percent and 6.9 percent of total operating revenues during the six months ended March 31, 2014 and 2013, respectively.
	-2	Included in other income on the Unaudited Condensed Consolidated Statements of Operations.
		Three Months Ended						Six Months Ended
		March 31,						March 31,
	(Thousands)	2014			2013			2014			2013
	Interest expense, net of capitalized interest
	Natural Gas Distribution	$	3,888		$	3,549		$	7,872		$	7,133
	Energy Services	661			640			1,277			1,208
	Clean Energy Ventures	1,249			822			2,435			1,605
	Midstream	377			476			775			1,067
	Subtotal	6,175			5,487			12,359			11,013
	Retail and Other	131			259			242			558
	Total	$	6,306		$	5,746		$	12,601		$	11,571
	Income tax provision (benefit)
	Natural Gas Distribution	$	23,725		$	22,794		$	37,908		$	37,301
	Energy Services	64,345			(5,203		)	53,072			10,961
	Clean Energy Ventures	(17,388		)	(6,457		)	(19,432		)	(14,226		)
	Midstream	1,573			1,619			2,569			2,862
	Subtotal	72,255			12,753			74,117			36,898
	Retail and Other	(1,129		)	(906		)	(1,320		)	(1,029		)
	Eliminations	554			218			388			176
	Total	$	71,680		$	12,065		$	73,185		$	36,045
	Equity in earnings of affiliates
	Midstream	$	4,141		$	4,469		$	7,083		$	7,960
	Eliminations	(908		)	(939		)	(1,708		)	(1,875		)
	Total	$	3,233		$	3,530		$	5,375		$	6,085
	Net financial earnings (loss)
Natural Gas Distribution	$	47,043		$	45,917		$	74,682		$	71,409
Energy Services	91,407			16,368			98,781			19,382
Clean Energy Ventures	12,807			5,154			16,421			10,459
Midstream	2,254			2,274			3,688			4,059
Subtotal	153,511			69,713			193,572			105,309
Retail and Other	(1,576		)	(1,037		)	(1,777		)	(1,131		)
Eliminations	(15		)	(12		)	(15		)	(21		)
Total	$	151,920		$	68,664		$	191,780		$	104,157
Capital expenditures
Natural Gas Distribution	$	35,484		$	31,554		$	70,885		$	65,699
Clean Energy Ventures	20,486			9,545			45,403			24,865
Subtotal	55,970			41,099			116,288			90,564
Retail and Other	272			144			477			298
Total	$	56,242		$	41,243		$	116,765		$	90,862
The chief operating decision maker of the Company is the Chief Executive Officer who uses NFE as a measure of profit or loss in measuring the results of the Company's segments and operations. A reconciliation of consolidated NFE to consolidated net income is as follows:
	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2014			2013			2014			2013
Consolidated net financial earnings	$	151,920		$	68,664		$	191,780		$	104,157
Less:
Unrealized (gain) loss from derivative instruments and related transactions (1)	(13,256		)	38,800			52,395			20,466
Effects of economic hedging related to natural gas inventory	(18,668		)	(2,117		)	(41,548		)	(22,865		)
Tax adjustments	10,873			(13,488		)	269			881
Consolidated net income	$	172,971		$	45,469		$	180,664		$	105,675
-1	Excludes unrealized losses related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $(957,000) and $(377,000) for the three months ended and $(672,000) and $(310,000) for the six months ended March 31, 2014 and 2013, respectively.
The Company uses derivative instruments as economic hedges of purchases and sales of physical gas inventory. For GAAP purposes, these derivatives are recorded at fair value and related changes in fair value are included in reported earnings. Revenues and cost of gas related to physical gas flow is recognized as the gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical gas flows. Timing differences occur in two ways:
•	Unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical gas inventory flows; and
•	Unrealized gains and losses of prior periods are reclassified as realized gains and losses when derivatives are settled in the same period as physical gas inventory movements occur.
NFE is a measure of the earnings based on eliminating these timing differences, to effectively match the earnings effects of the economic hedges with the physical sale of gas. Consequently, to reconcile between GAAP and NFE, current period unrealized gains and losses on the derivatives are excluded from NFE as a reconciling item. Additionally, realized derivative gains and losses are also included in current period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical gas flows. NJR also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.
The Company's assets for the various business segments and business operations are detailed below:
(Thousands)	March 31,			September 30,
	2014			2013
Assets at end of period:
Natural Gas Distribution	$	2,157,317		$	2,094,940
Energy Services	546,010			468,096
Clean Energy Ventures	312,258			253,663
Midstream	153,050			153,536
Subtotal	3,168,635			2,970,235
Retail and Other	89,810			85,293
Intercompany assets (1)	(97,235		)	(50,745		)
Total	$	3,161,210		$	3,004,783
-1	Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	6 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	RELATED PARTY TRANSACTIONS
	NJRES may periodically enter into storage or park and loan agreements with its affiliated FERC-regulated natural gas storage facility, Steckman Ridge, or transportation agreements with its affiliated FERC-regulated interstate pipeline, Iroquois. As of March 31, 2014, NJRES has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which expire in March 2015. Additionally, NJRES has transportation capacity with Iroquois that expires in March 2019. Demand fees, net of eliminations, associated with both Steckman Ridge and Iroquois were $1.5 million and $3.2 million during the six months ended March 31, 2014 and 2013, respectively. As of March 31, 2014, NJRES had demand fees payable of $166,000 and $403,000 to Steckman Ridge and Iroquois, respectively, which are included in gas purchases payable. As of September 30, 2013, fees payable to Steckman Ridge and Iroquois, were $159,000 and $390,000, respectively.
	In January 2010, NJNG entered into a 10-year agreement effective April 1, 2010, for 3 Bcf of firm storage capacity with Steckman Ridge. Under the terms of the agreement, NJNG incurs demand fees, at market rates, of approximately $9.3 million annually, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG's BGSS mechanism and are included in regulatory assets. Additionally, NJNG has transportation capacity with Iroquois that expires by January 2019. Demand fees, net of eliminations, associated with both Steckman Ridge and Iroquois were $4.8 million and $2.7 million during the six months ended March 31, 2014 and 2013, respectively. NJNG had demand fees payable to Steckman Ridge in the amount of $776,000 as of March 31, 2014 and $775,000 as of September 30, 2013. NJNG had fees payable to Iroquois of $62,000 and $61,000 as of March 31, 2014 and September 30, 2013, respectively.
	In December 2009, NJNG and NJRES entered into an asset management agreement that began in January 2010 and ends in March 2015. Under the terms of this agreement, NJNG released certain transportation and storage contracts to NJRES for the entire term of the agreement. NJNG also sold approximately 1 Bcf of natural gas in storage at cost to NJRES. In return, NJNG has the option to purchase index priced gas from NJRES at NJNG's city gate and other delivery locations to maintain operational reliability. In September 2010, NJNG and NJRES entered into an asset management agreement that began in November 2010 and ends October 2014, whereby NJNG released additional transportation contracts to NJRES for the entire term of the agreement and has the option to purchase index priced gas from NJRES at NJNG's city gate. In March 2014, NJNG and NJRES entered into an another asset management agreement that began in April 2014 and ends March 2016, whereby NJNG released additional transportation contracts to NJRES for the entire term of the agreement and has the option to purchase index priced gas from NJRES at NJNG's city gate.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Available for Sale Securities	'
	Available for Sale Securities
	Included in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets are certain investments in equity securities of a publicly traded energy company that have a fair value of $11.2 million and $11.7 million as of March 31, 2014 and September 30, 2013, respectively. Total unrealized gains associated with these equity securities, which are included as a part of accumulated other comprehensive income, a component of common stock equity, were $8.6 million ($5.1 million, after tax) and $9.1 million ($5.4 million, after tax) as of March 31, 2014 and September 30, 2013, respectively. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.
Loan Receivable	'
	Loan Receivable
	NJNG provides interest-free loans, with terms ranging from two to ten years, to customers that elect to purchase and install certain energy efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at net present value on the Unaudited Condensed Consolidated Balance Sheets. The Company has recorded $3 million and $1.9 million in other current assets and $21.9 million and $14.3 million in other noncurrent assets as of March 31, 2014 and September 30, 2013, respectively, on the Unaudited Condensed Consolidated Balance Sheets.
	NJR's policy is to establish an allowance for doubtful accounts when loan balances are outstanding for more than 60 days. As of March 31, 2014 and September 30, 2013, there was no allowance for doubtful accounts established.
Derivatives	'
	The Company is subject to commodity price risk due to fluctuations in the market price of natural gas, SREC, and electricity prices. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs, and electricity. In addition, the Company may utilize foreign currency derivatives as cash flow hedges of Canadian dollar denominated gas purchases. These contracts, with a few exceptions as described below, are accounted for as derivatives. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company's fair value measurement policies and level disclosures associated with the NJR's derivative instruments, see Note 5. Fair Value.
	Since the Company chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS as appropriate, changes in the fair value of these derivative instruments are recorded as a component of gas purchases or operating revenues, as appropriate for NJRES, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or (losses). For NJRES at settlement, realized gains and (losses) on all financial derivative instruments are recognized as a component of gas purchases and realized gains and (losses) on all physical derivatives follow the presentation of the related unrealized gains and (losses) as a component of either gas purchases or operating revenues.
	NJRES also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the US dollar. NJRES utilizes foreign currency derivatives to lock in the currency translation rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are being used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company has designated these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in OCI. When the foreign exchange contracts are settled and the related purchases are recognized in income, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.
	As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that may ultimately be repaid, based on changes in forward natural gas prices during the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings.
	Changes in fair value of NJNG's financial derivative instruments are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets, as NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff for gas service.
	The Company elects NPNS accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, gains or (losses) are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered.
	NJRCEV hedges certain of its expected production of SRECs through forward sale contracts. The Company intends to physically deliver the SRECs upon settlement and therefore applies NPNS accounting treatment to the contracts. NJRCEV recognizes revenue for SRECs upon transfer of the certificate.
Fair Value Hierarchy	'
	Fair Value Hierarchy
	NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following:
	Level 1	Unadjusted quoted prices for identical assets or liabilities in active markets. NJR's Level 1 assets and liabilities include exchange traded futures and options contracts, listed equities, and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX/CME and ICE that NJR refers internally to as basis swaps, fixed swaps, futures and options that are cleared through a FCM.
	Level 2	Other significant observable inputs such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input was considered to be a “model”, it would still be considered to be a Level 2 input as:
	1)     The data is widely accepted and public
	2)    The data is non-proprietary and sourced from an independent third party
	3)    The data is observable and published
	These additional adjustments are generally not considered to be significant to the ultimate recognized values.
	Level 3	Inputs derived from a significant amount of unobservable market data; these include NJR's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	6 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Schedule of Utility Inventory	'
	The following table summarizes gas in storage, at average cost by company as of:
		March 31,					September 30,
		2014					2013
	($ in thousands)	Gas in Storage				Bcf	Gas in Storage				Bcf
	NJNG		$	12,582		2.1		$	104,979		20.4
	NJRES		126,439			23.2		209,498			62.3
	Total		$	139,021		25.3		$	314,477		82.7
Accounts Receivable by Subsidiary	'
	Customer accounts receivable include outstanding billings from the following subsidiaries as of:
	(Thousands)	March 31,					September 30,
		2014					2013
	NJRES	$	328,544		67	%	$	194,263		81	%
	NJNG (1)	156,272			32		43,045			18
	NJRCEV	565			—		293			—
	NJRHS and other	2,560			1		2,680			1
	Total	$	487,941		100	%	$	240,281		100	%
	-1	Does not include unbilled revenues of $53.7 million and $7.4 million as of March 31, 2014 and September 30, 2013, respectively.

REGULATION_Tables

REGULATION (Tables)	6 Months Ended
	Mar. 31, 2014
Regulated Operations [Abstract]	'
Schedule of Regulatory Assets and Liabilities	'
	Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets are comprised of the following:
	(Thousands)	March 31,		September 30,
		2014		2013
	Regulatory assets-current
	Conservation Incentive Program	$	—	$	18,887
	Underrecovered gas costs	12,991		953
	New Jersey Clean Energy Program	5,979		14,532
	Total current	$	18,970	$	34,372
	Regulatory assets-noncurrent
	Environmental remediation costs
	Expended, net of recoveries	$	32,661	$	46,968
	Liability for future expenditures	183,600		183,600
	Deferred income taxes	10,718		10,718
	Derivatives at fair value, net	—		19
	SAVEGREEN	23,988		30,004
	Postemployment and other benefit costs	98,029		101,415
	Deferred Superstorm Sandy costs	15,207		14,822
	Other	4,116		14,656
	Total noncurrent	$	368,319	$	402,202
	Regulatory liability-current
	Conservation Incentive Program	$	5,964	$	—
	Derivatives at fair value, net	14,396		1,456
	Total current	$	20,360	$	1,456
	Regulatory liabilities-noncurrent
	Cost of removal obligation	$	75,327	$	79,315
	Other	1,530		332
	Total noncurrent	$	76,857	$	79,647

DERIVATIVE_INSTRUMENTS_Tables

DERIVATIVE INSTRUMENTS (Tables)	6 Months Ended
	Mar. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	The following table reflects the fair value of NJR's derivative assets and liabilities recognized on the Unaudited Condensed Consolidated Balance Sheets as of:
				Fair Value
				March 31, 2014								September 30, 2013
	(Thousands)	Balance Sheet Location	Asset				Liability				Asset				Liability
			Derivatives				Derivatives				Derivatives				Derivatives
	Derivatives designated as hedging instruments:
	NJRES:
	Foreign currency contracts	Derivatives - current		$	—			$	277			$	16			$	3
		Derivatives - noncurrent		—				7				—				2
	Fair value of derivatives designated as hedging instruments			$	—			$	284			$	16			$	5
	Derivatives not designated as hedging instruments:
	NJNG:
	Financial derivative contracts	Derivatives - current		$	15,387			$	998			$	3,502			$	2,045
		Derivatives - noncurrent		—				—				121				140
	NJRES:
	Physical forward commodity contracts	Derivatives - current		5,634				35,568				11,282				14,573
		Derivatives - noncurrent		197				111				541				22
	Financial derivative contracts	Derivatives - current		24,161				34,380				38,527				23,769
		Derivatives - noncurrent		2,073				5,074				2,099				2,294
	Fair value of derivatives not designated as hedging instruments			$	47,452			$	76,131			$	56,072			$	42,843
	Total fair value of derivatives			$	47,452			$	76,415			$	56,088			$	42,848
Offsetting Assets and Liabilities	'
	The tables below summarize the reported gross amounts, the amounts that NJR has the right to offset but elects not to, financial collateral, as well as the net amounts NJR could present in the Unaudited Condensed Consolidated Balance Sheets but elects not to.
	(Thousands)	Amounts Presented in Balance Sheets (1)				Offsetting Derivative Instruments (2)				Financial Collateral Received/Pledged (3)				Net Amounts (4)
	As of March 31, 2014:
	Derivative assets:
	NJRES
	Physical forward commodity contracts		$	5,831			$	(2,190	)		$	—			$	3,641
	Financial commodity contracts		26,234				(26,234		)		—				—
	Foreign currency contracts		—				—				—				—
	Total NJRES		$	32,065			$	(28,424	)		$	—			$	3,641
	NJNG
	Financial commodity contracts		$	15,387			$	(998	)		$	(10,772	)		$	3,617
	Derivative liabilities:
	NJRES
	Physical forward commodity contracts		$	35,679			$	(2,371	)		$	(500	)		$	32,808
	Financial commodity contracts		39,454				(26,233		)		(13,221		)		—
	Foreign currency contracts		284				—				—				284
	Total NJRES		$	75,417			$	(28,604	)		$	(13,721	)		$	33,092
	NJNG
	Financial commodity contracts		$	998			$	(998	)		$	—			$	—
	As of September 30, 2013:
	Derivative assets:
	NJRES
	Physical forward commodity contracts		$	11,823			$	(3,549	)		$	(100	)		$	8,174
	Financial commodity contracts		40,626				(26,063		)		6,870				21,433
	Foreign currency contracts		16				(5		)		—				11
	Total NJRES		$	52,465			$	(29,617	)		$	6,770			$	29,618
	NJNG
	Financial commodity contracts		$	3,623			$	(2,185	)		$	214			$	1,652
	Derivative liabilities:
	NJRES
	Physical forward commodity contracts		$	14,595			$	(3,549	)		$	(500	)		$	10,546
	Financial commodity contracts		26,063				(26,063		)		—				—
	Foreign currency contracts		5				(5		)		—				—
	Total NJRES		$	40,663			$	(29,617	)		$	(500	)		$	10,546
	NJNG
	Financial commodity contracts		$	2,185			$	(2,185	)		$	—			$	—
	-1	Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.
	-2	Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.
	-3	Financial collateral includes cash balances at FCM's as well as cash received from or pledged to other counterparties.
	-4	Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.
Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location	'
	The following table reflects the effect of derivative instruments on the Unaudited Condensed Consolidated Statements of Operations as of:
	(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized
			in income on derivatives
			Three Months Ended							Six Months Ended
			March 31,							March 31,
	Derivatives not designated as hedging instruments:		2014				2013			2014				2013
	NJRES:
	Physical commodity contracts	Operating revenues	$	(57,916	)		$	(2,224	)	$	(57,998	)		$	(7,859	)
	Physical commodity contracts	Gas purchases	(54,481		)		2,762			(79,474		)		2,556
	Financial derivative contracts	Gas purchases	(101,629		)		(30,669		)	(141,699		)		(1,467		)
	Total unrealized and realized (losses)		$	(214,026	)		$	(30,131	)	$	(279,171	)		$	(6,770	)
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	'
	The following tables reflect the effect of derivative instruments designated as cash flow hedges on OCI as of March 31:
	(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)						Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
		Three Months Ended						Three Months Ended						Three Months Ended
		March 31,						March 31,						March 31,
	Derivatives in cash flow hedging relationships:	2014			2013			2014			2013			2014			2013
	Foreign currency contracts	$	(309	)	$	24		$	68		$	(35	)	$	—		$	—
	(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion) (1)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)						Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
		Six Months Ended						Six Months Ended						Six Months Ended
		March 31,						March 31,						March 31,
	Derivatives in cash flow hedging relationships:	2014			2013			2014			2013			2014			2013
	Foreign currency contracts	$	(460	)	$	(71	)	$	165		$	44		$	—		$	—
	-1	The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $277,000 from OCI into earnings. The maximum tenor is April 2015
Schedule of Derivative Instruments	'
	NJNG and NJRES had the following outstanding long (short) derivatives as of:
				Volume (Bcf)
				March 31,		September 30,
				2014		2013
	NJNG	Futures		27.5		22.6
	NJRES	Futures		(20.9	)	(64.2	)
		Options		—		1.5
		Physical		31		7.3
Schedule of Due to (from) Broker-Dealers and Clearing Organizations	'
	The balances by company, are as follows:
	(Thousands)	Balance Sheet Location	March 31,			September 30,
			2014			2013
	NJNG	Broker margin - Current assets	$	—		$	213
	NJNG	Broker margin - Current (liabilities)	$	(10,573	)	$	—
	NJRES	Broker margin - Current assets	$	38,490		$	6,368
Schedules of Concentration of Risk, by Risk Factor	'
	The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of March 31, 2014. Internally-rated exposure applies to counterparties that are not rated by S&P or Moody's. In these cases, the Company's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by S&P and/or Moody's are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received. The amounts presented below have not been reduced by any collateral received or netting and exclude accounts receivable for NJNG retail natural gas sales and services.
	(Thousands)	Gross Credit Exposure
	Investment grade		$	299,185
	Noninvestment grade		6,104
	Internally rated investment grade		43,953
	Internally rated noninvestment grade		27,356
	Total		$	376,598

FAIR_VALUE_Tables

FAIR VALUE (Tables)	6 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
Fair Value, by Balance Sheet Grouping	'
	The estimated fair value of long-term debt, including current maturities and excluding capital leases, is as follows:
	(Thousands)	March 31,			September 30,
		2014			2013
	Carrying value	$	594,845		$	529,845
	Fair market value	$	622,213		$	556,518
Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis	'
	Assets and liabilities measured at fair value on a recurring basis are summarized as follows:
		Quoted Prices in Active Markets for Identical Assets					Significant Other Observable Inputs			Significant
										Unobservable
										Inputs
	(Thousands)	(Level 1)					(Level 2)			(Level 3)			Total
	As of March 31, 2014:
	Assets:
	Physical forward commodity contracts		$	—				$	5,832		$	—	$	5,832
	Financial derivative contracts - natural gas		41,620					—			—		41,620
	Financial derivative contracts - foreign exchange		—					—			—		—
	Available for sale equity securities - energy industry (1)		11,218					—			—		11,218
	Other (2)		1,263					—			—		1,263
	Total assets at fair value		$	54,101				$	5,832		$	—	$	59,933
	Liabilities:
	Physical forward commodity contracts		$	—				$	35,680		$	—	$	35,680
	Financial derivative contracts - natural gas		40,451					—			—		40,451
	Financial derivative contracts - foreign exchange		—					284			—		284
	Total liabilities at fair value		$	40,451				$	35,964		$	—	$	76,415
	As of September 30, 2013:
	Assets:
	Physical forward commodity contracts		$	—				$	11,823		$	—	$	11,823
	Financial derivative contracts - natural gas		44,249					—			—		44,249
	Financial derivative contracts - foreign exchange		—					16			—		16
	Available for sale equity securities - energy industry (1)		11,716					—			—		11,716
	Other (2)		1,129					—			—		1,129
	Total assets at fair value		$	57,094				$	11,839		$	—	$	68,933
	Liabilities:
	Physical forward commodity contracts		$	—				$	14,595		$	—	$	14,595
	Financial derivative contracts - natural gas		28,248					—			—		28,248
	Financial derivative contracts - foreign exchange		—					5			—		5
	Total liabilities at fair value		$	28,248				$	14,600		$	—	$	42,848
	-1	Included in Other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets.
	-2	Includes various money market funds.

INVESTMENTS_IN_EQUITY_INVESTEE1

INVESTMENTS IN EQUITY INVESTEES (Tables)	6 Months Ended
	Mar. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]	'
Schedule of Equity Method Investments	'
	Equity Method Investments
	(Thousands)	March 31,		September 30,
		2014		2013
	Steckman Ridge	$	129,171	$	129,707
	Iroquois	23,166		23,084
	Total	$	152,337	$	152,791

EARNINGS_PER_SHARE_Tables

EARNINGS PER SHARE (Tables)	6 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
Schedule of Earnings Per Share Basic and Diluted	'
	The following table presents the calculation of the Company's basic and diluted earnings per share for:
		Three Months Ended				Six Months Ended
		March 31,				March 31,
	(Thousands, except per share amounts)	2014		2013		2014		2013
	Net income	$	172,971	$	45,469	$	180,664	$	105,675
	Basic earnings per share
	Weighted average shares of common stock outstanding-basic	42,079		41,789		42,050		41,742
	Basic earnings per common share	$4.11		$1.09		$4.30		$2.53
	Diluted earnings per share
	Weighted average shares of common stock outstanding-basic	42,079		41,789		42,050		41,742
	Incremental shares (1)	378		183		378		183
	Weighted average shares of common stock outstanding-diluted	42,457		41,972		42,428		41,925
	Diluted earnings per common share (2)	$4.07		$1.08		$4.26		$2.52
	-1	Incremental shares consist of stock options, stock awards and performance units.
	-2	There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and six months ended March 31, 2014 and 2013.

COMMON_STOCK_EQUITY_Tables

COMMON STOCK EQUITY (Tables)	6 Months Ended
	Mar. 31, 2014
Equity [Abstract]	'
Changes in Common Stock Equity	'
	Changes in common stock equity during the six months ended March 31, 2014, are as follows:
	(Thousands)	Number of Shares		Common Stock			Premium on Common Stock			Accumulated Other Comprehensive (Loss) Income					Treasury Stock And Other			Retained Earnings			Total
	Balance as of September 30, 2013	41,962		$	112,563		$	300,196			$	(1,621	)		$	(128,638	)	$	604,884		$	887,384
	Net income																	180,664			180,664
	Other comprehensive (loss)										(159		)								(159		)
	Common stock issued under stock plans	224		143			2,817								6,741						9,701
	Tax benefits from stock plans						94														94
	Cash dividend declared ($.84 per share)																	(35,314		)	(35,314		)
	Treasury stock and other	(111	)												(3,188		)				(3,188		)
	Balance as of March 31, 2014	42,075		$	112,706		$	303,107			$	(1,780	)		$	(125,085	)	$	750,234		$	1,039,182
Components of Accumulated Other Comprehensive Income, Net of Tax	'
	The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects:
	(Thousands)	Available for Sale Securities				Cash Flow Hedges				Postemployment Benefit Obligation				Total
	Balance as of September 30, 2013	$	5,400			$	12			$	(7,033	)		$	(1,621	)
	Other comprehensive income, net of tax
	Other comprehensive (loss), before reclassifications, net of tax of $203, $169, $-, $372	(295		)		(291		)		—				(586		)
	Amounts reclassified from accumulated other comprehensive income, net of tax of $-, $(60), $(223), $(283)	—				105			(1)	322			(2)	427
	Net current-period other comprehensive (loss) income, net of tax of $203, $109, $(223), $89	(295		)		(186		)		322				(159		)
	Balance as of March 31, 2014	$	5,105			$	(174	)		$	(6,711	)		$	(1,780	)
	Balance as of September 30, 2012	$	4,921			$	51			$	(15,743	)		$	(10,771	)
	Other comprehensive income, net of tax
	Other comprehensive income, before reclassifications, net of tax of $(226), $26, $-, $(200)	327				(45		)		—				282
	Amounts reclassified from accumulated other comprehensive income, net of tax of $-, $(16) $(406), $(422)	—				28			(1)	709			(2)	737
	Net current-period other comprehensive income, net of tax of $(226), $10, $(406), $(622)	327				(17		)		709				1,019
	Balance as of March 31, 2013	$	5,248			$	34			$	(15,034	)		$	(9,752	)
	-1	Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases in the Unaudited Condensed Consolidated Statements of Operations.
	-2	Included in the computation of net periodic pension cost, a component of operations and maintenance expense in the Unaudited Condensed Consolidated Statements of Operations.

DEBT_Tables

DEBT (Tables)	6 Months Ended
	Mar. 31, 2014
Debt Disclosure [Abstract]	'
Schedule of Line of Credit Facilities	'
	A summary of NJR's credit facility and NJNG's commercial paper program and credit facility are as follows:
	(Thousands)	March 31,			September 30,			Expiration Dates
		2014			2013
	NJR
	Bank revolving credit facility (1)	$	425,000		$	325,000		Aug-17
	Notes outstanding at end of period	$	15,200		$	97,000
	Weighted average interest rate at end of period	1.15		%	1		%
	Amount available at end of period (2)	$	384,459		$	210,110
	Bank term loan (3)	$	100,000		$	100,000		Sep-14
	Loan outstanding at end of period	$	—		$	100,000
	Weighted average interest rate at end of period	—		%	0.74		%
	Amount available at end of period	$	100,000		$	—
	Bank letter of credit facility (3) (4)	$	10,000		$	10,000		Jun-14
	NJNG
	Bank credit facility dedicated to EDA Bonds (1) (4)	$	100,000		$	100,000		Aug-15
	Bank revolving credit facility (1)	$	250,000		$	250,000		Aug-14
	Commercial paper outstanding at end of period	$	48,000		$	168,600
	Weighted average interest rate at end of period	0.12		%	0.13		%
	Amount available at end of period (5)	$	201,269		$	81,400
	-1	Committed credit facilities, which require commitment fees on the unused amounts.
	-2	Letters of credit outstanding total $25.3 million and $17.9 million as of March 31, 2014 and September 30, 2013, respectively, which reduces amount available by the same amount.
	-3	Uncommitted.
	-4	There were no borrowings outstanding as of March 31, 2014 and September 30, 2013, respectively.
	-5	Letters of credit outstanding total $731,000 and $266,000 as of March 31, 2014 and September 30, 2013, respectively, which reduces the amount available by the same amount.

EMPLOYEE_BENEFIT_PLANS_Tables

EMPLOYEE BENEFIT PLANS (Tables)	6 Months Ended
	Mar. 31, 2014
Compensation and Retirement Disclosure [Abstract]	'
Schedule of Net Benefit Costs	'
	The components of the net periodic cost for pension benefits, including the Company's Pension Equalization Plan, and OPEB costs (principally health care and life insurance) for employees and covered dependents were as follows:
		Pension												OPEB
		Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
		March 31,						March 31,						March 31,						March 31,
	(Thousands)	2014			2013			2014			2013			2014			2013			2014			2013
	Service cost	$	1,536		$	1,718		$	3,072		$	3,436		$	981		$	1,171		$	1,962		$	2,342
	Interest cost	2,517			2,235			5,033			4,470			1,433			1,287			2,866			2,574
	Expected return on plan assets	(3,869		)	(3,706		)	(7,738		)	(7,412		)	(1,043		)	(913		)	(2,087		)	(1,826		)
	Recognized actuarial loss	1,399			1,911			2,798			3,822			625			964			1,250			1,928
	Prior service cost amortization	28			27			56			54			(89		)	7			(178		)	14
	Recognized net initial obligation	—			—			—			—			2			(89		)	5			(178		)
	Net periodic benefit cost	$	1,611		$	2,185		$	3,221		$	4,370		$	1,909		$	2,427		$	3,818		$	4,854

COMMITMENTS_AND_CONTINGENT_LIA1

COMMITMENTS AND CONTINGENT LIABILITIES (Tables)	6 Months Ended
	Mar. 31, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Long-term Purchase Commitment	'
	Commitments as of March 31, 2014, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:
	(Thousands)	2014		2015		2016		2017		2018		Thereafter
	NJRES:
	Natural gas purchases	$	320,608	$	99,106	$	15,452	$	—	$	—	$	—
	Storage demand fees	15,571		20,773		9,931		5,425		3,318		4,000
	Pipeline demand fees	35,978		43,174		33,561		18,307		12,548		7,175
	Sub-total NJRES	$	372,157	$	163,053	$	58,944	$	23,732	$	15,866	$	11,175
	NJNG:
	Natural gas purchases	$	55,132	$	107,920	$	6,522	$	113	$	—	$	—
	Storage demand fees	12,995		20,611		13,285		10,883		9,299		13,948
	Pipeline demand fees	32,139		74,142		43,312		34,247		33,978		194,675
	Sub-total NJNG	$	100,266	$	202,673	$	63,119	$	45,243	$	43,277	$	208,623
	Total (1)	$	472,423	$	365,726	$	122,063	$	68,975	$	59,143	$	219,798
	-1	Does not include amounts related to intercompany asset management agreements between NJRES and NJNG.

BUSINESS_SEGMENT_AND_OTHER_OPE1

BUSINESS SEGMENT AND OTHER OPERATIONS DATA (Tables)	6 Months Ended
	Mar. 31, 2014
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment	'
	Information related to the Company's various business segments and other operations is detailed below:
		Three Months Ended						Six Months Ended
		March 31,						March 31,
	(Thousands)	2014			2013			2014			2013
	Operating revenues
	Natural Gas Distribution
	External customers	$	394,528		$	351,750		$	627,997		$	570,599
	Energy Services
	External customers (1)	1,173,835			599,362			1,807,526			1,102,997
	Intercompany	67,749			4,444			71,767			4,551
	Clean Energy Ventures
	External customers	2,679			1,440			4,852			4,619
	Subtotal	1,638,791			956,996			2,512,142			1,682,766
	Retail and Other
	External customers	8,527			8,334			17,599			18,689
	Intercompany	297			186			499			449
	Eliminations	(68,046		)	(4,631		)	(72,266		)	(5,000		)
	Total	$	1,579,569		$	960,885		$	2,457,974		$	1,696,904
	Depreciation and amortization
	Natural Gas Distribution	$	9,972		$	9,399		$	19,807		$	18,676
	Energy Services	13			11			25			22
	Clean Energy Ventures	2,635			2,104			5,146			3,935
	Midstream	2			1			3			3
	Subtotal	12,622			11,515			24,981			22,636
	Retail and Other	208			199			415			390
	Eliminations	(2		)	7			(2		)	(2		)
	Total	$	12,828		$	11,721		$	25,394		$	23,024
	Interest income (2)
	Natural Gas Distribution	$	181		$	146		$	442		$	313
	Midstream	270			263			538			534
	Subtotal	451			409			980			847
	Retail and Other	—			1			—			2
	Eliminations	(235		)	(218		)	(468		)	(450		)
	Total	$	216		$	192		$	512		$	399
	-1	Includes sales to Canada, which accounted for 4 percent and 6.9 percent of total operating revenues during the six months ended March 31, 2014 and 2013, respectively.
	-2	Included in other income on the Unaudited Condensed Consolidated Statements of Operations.
		Three Months Ended						Six Months Ended
		March 31,						March 31,
	(Thousands)	2014			2013			2014			2013
	Interest expense, net of capitalized interest
	Natural Gas Distribution	$	3,888		$	3,549		$	7,872		$	7,133
	Energy Services	661			640			1,277			1,208
	Clean Energy Ventures	1,249			822			2,435			1,605
	Midstream	377			476			775			1,067
	Subtotal	6,175			5,487			12,359			11,013
	Retail and Other	131			259			242			558
	Total	$	6,306		$	5,746		$	12,601		$	11,571
	Income tax provision (benefit)
	Natural Gas Distribution	$	23,725		$	22,794		$	37,908		$	37,301
	Energy Services	64,345			(5,203		)	53,072			10,961
	Clean Energy Ventures	(17,388		)	(6,457		)	(19,432		)	(14,226		)
	Midstream	1,573			1,619			2,569			2,862
	Subtotal	72,255			12,753			74,117			36,898
	Retail and Other	(1,129		)	(906		)	(1,320		)	(1,029		)
	Eliminations	554			218			388			176
	Total	$	71,680		$	12,065		$	73,185		$	36,045
	Equity in earnings of affiliates
	Midstream	$	4,141		$	4,469		$	7,083		$	7,960
	Eliminations	(908		)	(939		)	(1,708		)	(1,875		)
	Total	$	3,233		$	3,530		$	5,375		$	6,085
	Net financial earnings (loss)
	Natural Gas Distribution	$	47,043		$	45,917		$	74,682		$	71,409
	Energy Services	91,407			16,368			98,781			19,382
Clean Energy Ventures	12,807			5,154			16,421			10,459
Midstream	2,254			2,274			3,688			4,059
Subtotal	153,511			69,713			193,572			105,309
Retail and Other	(1,576		)	(1,037		)	(1,777		)	(1,131		)
Eliminations	(15		)	(12		)	(15		)	(21		)
Total	$	151,920		$	68,664		$	191,780		$	104,157
Capital expenditures
Natural Gas Distribution	$	35,484		$	31,554		$	70,885		$	65,699
Clean Energy Ventures	20,486			9,545			45,403			24,865
Subtotal	55,970			41,099			116,288			90,564
Retail and Other	272			144			477			298
Total	$	56,242		$	41,243		$	116,765		$	90,862
Reconciliation of Consolidated Net Financial Earnings to Consolidated Net Income	'
	A reconciliation of consolidated NFE to consolidated net income is as follows:
		Three Months Ended						Six Months Ended
		March 31,						March 31,
	(Thousands)	2014			2013			2014			2013
	Consolidated net financial earnings	$	151,920		$	68,664		$	191,780		$	104,157
	Less:
	Unrealized (gain) loss from derivative instruments and related transactions (1)	(13,256		)	38,800			52,395			20,466
	Effects of economic hedging related to natural gas inventory	(18,668		)	(2,117		)	(41,548		)	(22,865		)
	Tax adjustments	10,873			(13,488		)	269			881
	Consolidated net income	$	172,971		$	45,469		$	180,664		$	105,675
	-1	Excludes unrealized losses related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $(957,000) and $(377,000) for the three months ended and $(672,000) and $(310,000) for the six months ended March 31, 2014 and 2013, respectively.
Reconciliation of Assets from Segment to Consolidated	'
	The Company's assets for the various business segments and business operations are detailed below:
	(Thousands)	March 31,			September 30,
		2014			2013
	Assets at end of period:
	Natural Gas Distribution	$	2,157,317		$	2,094,940
	Energy Services	546,010			468,096
	Clean Energy Ventures	312,258			253,663
	Midstream	153,050			153,536
	Subtotal	3,168,635			2,970,235
	Retail and Other	89,810			85,293
	Intercompany assets (1)	(97,235		)	(50,745		)
	Total	$	3,161,210		$	3,004,783
	-1	Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.

NATURE_OF_THE_BUSINESS_Details

NATURE OF THE BUSINESS (Details)	6 Months Ended
	Mar. 31, 2014
	Customers
Steckman Ridge [Member]	'
Equity method investment, ownership percentage	50.00%
Iroquois [Member]	'
Equity method investment, ownership percentage	5.53%
NJNG [Member]	'
Total retail customers	503,700

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - GAS IN STORAGE (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013
In Thousands, unless otherwise specified	MMcf	MMcf
Inventory [Line Items]	'	'
Gas in Storage	$139,021	$314,477
Gas in Storage (Bcf)	25,300	82,700
NJNG [Member]	'	'
Inventory [Line Items]	'	'
Gas in Storage	12,582	104,979
Gas in Storage (Bcf)	2,100	20,400
NJRES [Member]	'	'
Inventory [Line Items]	'	'
Gas in Storage	$126,439	$209,498
Gas in Storage (Bcf)	23,200	62,300

SUMMARY_OF_SIGNIFICANT_ACCOUNT4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - AVAILABLE FOR SALE SECURITIES (Details) (USD $)	6 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Sep. 30, 2013
Accounting Policies [Abstract]	'		'
Available-for-sale securities, fair value disclosure	$11.20	[1]	$11.70
Available-for-sale securities, gross unrealized gain (loss)	8.6		9.1
Accumulated other comprehensive income, available-for-sale securities adjustment, net of tax	$5.10		$5.40
[1]	Included in Other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets

SUMMARY_OF_SIGNIFICANT_ACCOUNT5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SALE OF ASSET (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Oct. 22, 2013	Sep. 30, 2013
			acre
Accounting Policies [Abstract]	'	'	'	'
Number of acres of undeveloped land	'	'	25.4	'
Asset held for sale	$0	'	$5,400	$5,428
Proceeds from sale of assets	6,000	0	'	'
Pre-tax gain after closing costs	$313	'	'	'

SUMMARY_OF_SIGNIFICANT_ACCOUNT6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ACCOUNTS RECEIVABLE BY SUBSIDIARY (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013
In Thousands, unless otherwise specified
accounts receivable by subsidiary [Line Items]	'	'
Billed	$487,941	$240,281
Receivable by Subsidiary, percentage	100.00%	100.00%
Unbilled revenues	53,664	7,429
NJRES [Member]	'	'
accounts receivable by subsidiary [Line Items]	'	'
Billed	328,544	194,263
Receivable by Subsidiary, percentage	67.00%	81.00%
NJNG [Member]	'	'
accounts receivable by subsidiary [Line Items]	'	'
Billed	156,272	43,045
Receivable by Subsidiary, percentage	32.00%	18.00%
NJRCEV [Member]	'	'
accounts receivable by subsidiary [Line Items]	'	'
Billed	565	293
Receivable by Subsidiary, percentage	0.00%	0.00%
NJRHS and Other [Member]	'	'
accounts receivable by subsidiary [Line Items]	'	'
Billed	$2,560	$2,680
Receivable by Subsidiary, percentage	1.00%	1.00%

SUMMARY_OF_SIGNIFICANT_ACCOUNT7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - LOAN RECEIVABLE (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2014
In Millions, unless otherwise specified			Minimum [Member]	Maximum [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'	'	'
Loan term	'	'	'2 years	'10 years
Loans receivable in other current assets	$3	$1.90	'	'
Loans receivable in other noncurrent assets	$21.90	$14.30	'	'

REGULATION_REGULATORY_ASSETS_A

REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013
In Thousands, unless otherwise specified
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-current	$18,970	$34,372
Regulatory assets-noncurrent	368,319	402,202
Regulatory liability-current	20,360	1,456
Regulatory liabilities-noncurrent	76,857	79,647
Deferred Derivative Gain (Loss) [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory liability-current	14,396	1,456
Conservation Incentive Program [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory liability-current	5,964	0
Cost of Removal Obligation [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory liabilities-noncurrent	75,327	79,315
Other [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory liabilities-noncurrent	1,530	332
Conservation Incentive Program [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-current	0	18,887
Underrecovered Gas Costs [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-current	12,991	953
New Jersey Clean Energy Program [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-current	5,979	14,532
Environmental Remediation Costs Expended, Net of Recoveries [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	32,661	46,968
Environmental Remediation Costs Liability for Future Expenditures [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	183,600	183,600
Deferred Income Taxes [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	10,718	10,718
Derivatives at Fair Value, Net [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	0	19
SAVEGREEN [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	23,988	30,004
Postemployment and Other Benefit Costs [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	98,029	101,415
Deferred Superstorm Sandy Costs [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	15,207	14,822
Other [Member]	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets-noncurrent	$4,116	$14,656

REGULATION_REGULATORY_FILINGS_

REGULATION - REGULATORY FILINGS (Details) (USD $)	1 Months Ended			6 Months Ended
	Apr. 23, 2014	Apr. 23, 2014	Apr. 23, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	CIP [Member]	BGSS [Member]	SBC [Member]	NJCEP [Member]	June 2013 USF Filing [Member]	July 2013 SBC Filing [Member]
		Revolving Credit Facility [Member]	Medium-term Notes [Member]					USF [Member]	SBC [Member]
Schedule of Regulatory [Line Items]	'	'	'	'	'	'	'	'	'
Percent of increase (decrease) for the average residential heating customer	'	'	'	-1.00%	-6.00%	-0.20%	1.90%	-0.50%	'
Annual recovery amount approved by the Board of Public Utilities	'	'	'	'	'	'	'	'	$18,700,000
Debt term	'3 years	'	'	'	'	'	'	'	'
Maximum issuance amount	'	'	$300,000,000	'	'	'	'	'	'
Maturity period	'	'	'30 years	'	'	'	'	'	'
Renewal period	'	'5 years	'	'	'	'	'	'	'

DERIVATIVE_INSTRUMENTS_BALANCE

DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013
Derivatives, Fair Value [Line Items]	'	'
Derivative assets, current	$45,182,000	$53,327,000
Derivative liabilities, current	71,223,000	40,390,000
Derivative assets, noncurrent	2,270,000	2,761,000
Derivative liabilities, noncurrent	5,192,000	2,458,000
Derivative assets	47,452,000	56,088,000
Derivative liabilities	76,415,000	42,848,000
Notional amount of foreign currency derivatives	6,900,000	'
Designated as Hedging Instrument [Member] | NJRES [Member] | Foreign Currency Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative assets, current	0	16,000
Derivative liabilities, current	277,000	3,000
Derivative assets, noncurrent	0	0
Derivative liabilities, noncurrent	7,000	2,000
Derivative assets	0	16,000
Derivative liabilities	284,000	5,000
Not Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative assets	47,452,000	56,072,000
Derivative liabilities	76,131,000	42,843,000
Not Designated as Hedging Instrument [Member] | NJRES [Member] | Financial Commodity Contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative assets, current	24,161,000	38,527,000
Derivative liabilities, current	34,380,000	23,769,000
Derivative assets, noncurrent	2,073,000	2,099,000
Derivative liabilities, noncurrent	5,074,000	2,294,000
Not Designated as Hedging Instrument [Member] | NJRES [Member] | Physical Forward Commodity Contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative assets, current	5,634,000	11,282,000
Derivative liabilities, current	35,568,000	14,573,000
Derivative assets, noncurrent	197,000	541,000
Derivative liabilities, noncurrent	111,000	22,000
Not Designated as Hedging Instrument [Member] | NJNG [Member] | Financial Commodity Contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative assets, current	15,387,000	3,502,000
Derivative liabilities, current	998,000	2,045,000
Derivative assets, noncurrent	0	121,000
Derivative liabilities, noncurrent	$0	$140,000

DERIVATIVE_INSTRUMENTS_OFFSETT

DERIVATIVE INSTRUMENTS - OFFSETTING OF ASSETS AND LIABILITIES (Details) (USD $)	Mar. 31, 2014		Sep. 30, 2013
In Thousands, unless otherwise specified
NJRES [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Amounts Presented in Balance Sheets, Derivative assets	$32,065	[1]	$52,465	[1]
Offsetting Derivative Instruments, Derivative assets	-28,424	[2]	-29,617	[2]
Financial Collateral Received/Pledged, Derivative assets	0	[3]	6,770	[3]
Net Amounts, Derivative assets	3,641	[4]	29,618	[4]
Amounts Presented in Balance Sheets, Derivative liabilities	75,417	[1]	40,663	[1]
Offsetting Derivative Instruments, Derivative liabilities	-28,604	[2]	-29,617	[2]
Financial Collateral Received/Pledged, Derivative liabilities	-13,721	[3]	-500	[3]
Net Amounts, Derivative liabilities	33,092	[4]	10,546	[4]
NJRES [Member] | Physical Forward Commodity Contracts [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Amounts Presented in Balance Sheets, Derivative assets	5,831	[1]	11,823	[1]
Offsetting Derivative Instruments, Derivative assets	-2,190	[2]	-3,549	[2]
Financial Collateral Received/Pledged, Derivative assets	0	[3]	-100	[3]
Net Amounts, Derivative assets	3,641	[4]	8,174	[4]
Amounts Presented in Balance Sheets, Derivative liabilities	35,679	[1]	14,595	[1]
Offsetting Derivative Instruments, Derivative liabilities	-2,371	[2]	-3,549	[2]
Financial Collateral Received/Pledged, Derivative liabilities	-500	[3]	-500	[3]
Net Amounts, Derivative liabilities	32,808	[4]	10,546	[4]
NJRES [Member] | Financial Commodity Contracts [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Amounts Presented in Balance Sheets, Derivative assets	26,234	[1]	40,626	[1]
Offsetting Derivative Instruments, Derivative assets	-26,234	[2]	-26,063	[2]
Financial Collateral Received/Pledged, Derivative assets	0	[3]	6,870	[3]
Net Amounts, Derivative assets	0	[4]	21,433	[4]
Amounts Presented in Balance Sheets, Derivative liabilities	39,454	[1]	26,063	[1]
Offsetting Derivative Instruments, Derivative liabilities	-26,233	[2]	-26,063	[2]
Financial Collateral Received/Pledged, Derivative liabilities	-13,221	[3]	0	[3]
Net Amounts, Derivative liabilities	0	[4]	0	[4]
NJRES [Member] | Foreign Currency Contract [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Amounts Presented in Balance Sheets, Derivative assets	0	[1]	16	[1]
Offsetting Derivative Instruments, Derivative assets	0	[2]	-5	[2]
Financial Collateral Received/Pledged, Derivative assets	0	[3]	0	[3]
Net Amounts, Derivative assets	0	[4]	11	[4]
Amounts Presented in Balance Sheets, Derivative liabilities	284	[1]	5	[1]
Offsetting Derivative Instruments, Derivative liabilities	0	[2]	-5	[2]
Financial Collateral Received/Pledged, Derivative liabilities	0	[3]	0	[3]
Net Amounts, Derivative liabilities	284	[4]	0	[4]
NJNG [Member] | Financial Commodity Contracts [Member]	'		'
Offsetting Assets and Liabilities [Line Items]	'		'
Amounts Presented in Balance Sheets, Derivative assets	15,387	[1]	3,623	[1]
Offsetting Derivative Instruments, Derivative assets	-998	[2]	-2,185	[2]
Financial Collateral Received/Pledged, Derivative assets	-10,772	[3]	214	[3]
Net Amounts, Derivative assets	3,617	[4]	1,652	[4]
Amounts Presented in Balance Sheets, Derivative liabilities	998	[1]	2,185	[1]
Offsetting Derivative Instruments, Derivative liabilities	-998	[2]	-2,185	[2]
Financial Collateral Received/Pledged, Derivative liabilities	0	[3]	0	[3]
Net Amounts, Derivative liabilities	$0	[4]	$0	[4]
[1]	Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.
[2]	Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.
[3]	Financial collateral includes cash balances at FCM's as well as cash received from or pledged to other counterparties.
[4]	Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.

DERIVATIVE_INSTRUMENTS_INCOME_

DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) (USD $)	3 Months Ended				6 Months Ended
	Mar. 31, 2014		Mar. 31, 2013		Mar. 31, 2014		Mar. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Expected reclassification from OCI into earnings	$277,000		'		$277,000		'
Maximum tenor	'		'		'1 year 0 months 1 day		'
NJNG [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Derivative instruments, gain (loss) recognized in regulatory assets and liabilities net	6,200,000		12,400,000		12,800,000		6,200,000
Not Designated as Hedging Instrument [Member] | NJRES [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of gain (loss) recognized in income on derivatives	-214,026,000		-30,131,000		-279,171,000		-6,770,000
Not Designated as Hedging Instrument [Member] | Physical Commodity Contracts [Member] | Operating Revenues [Member] | NJRES [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of gain (loss) recognized in income on derivatives	-57,916,000		-2,224,000		-57,998,000		-7,859,000
Not Designated as Hedging Instrument [Member] | Physical Commodity Contracts [Member] | Gas Purchases [Member] | NJRES [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of gain (loss) recognized in income on derivatives	-54,481,000		2,762,000		-79,474,000		2,556,000
Not Designated as Hedging Instrument [Member] | Financial Commodity Contracts [Member] | Gas Purchases [Member] | NJRES [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of gain (loss) recognized in income on derivatives	-101,629,000		-30,669,000		-141,699,000		-1,467,000
Cash Flow Hedging [Member] | Foreign Currency Contract [Member] | Gas Purchases [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)	-309,000	[1]	24,000	[1]	-460,000	[1]	-71,000	[1]
Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)	68,000		-35,000		165,000		44,000
Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	$0		$0		$0		$0
[1]	The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $277,000 from OCI into earnings. The maximum tenor is April 2015

DERIVATIVE_INSTRUMENTS_VOLUME_

DERIVATIVE INSTRUMENTS - VOLUME (Details)	Mar. 31, 2014	Sep. 30, 2013
	MMcf	MMcf
NJNG [Member] | Futures [Member] | Long Position [Member]	'	'
Derivative [Line Items]	'	'
Derivative, nonmonetary notional amount	27,500	22,600
NJRES [Member] | Futures [Member] | Short Position [Member]	'	'
Derivative [Line Items]	'	'
Derivative, nonmonetary notional amount	-20,900	-64,200
NJRES [Member] | Options [Member] | Long Position [Member]	'	'
Derivative [Line Items]	'	'
Derivative, nonmonetary notional amount	0	1,500
NJRES [Member] | Physical [Member] | Long Position [Member]	'	'
Derivative [Line Items]	'	'
Derivative, nonmonetary notional amount	31,000	7,300

DERIVATIVE_INSTRUMENTS_BROKER_

DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013
In Thousands, unless otherwise specified
Broker margin - Current assets	$38,490	$6,581
Broker margin - Current (liabilities)	-10,573	0
NJNG [Member]	'	'
Broker margin - Current assets	0	213
Broker margin - Current (liabilities)	-10,573	0
NJRES [Member]	'	'
Broker margin - Current assets	$38,490	$6,368

DERIVATIVE_INSTRUMENTS_CREDIT_

DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) (USD $)	6 Months Ended
	Mar. 31, 2014	Sep. 30, 2013
Credit Risk Exposure [Line Items]	'	'
Gross Credit Exposure	$376,598,000	'
Derivative, net liability position, aggregate fair value	200,000	2,000,000
Additional collateral, aggregate fair value	200,000	1,100,000
Investment Grade [Member]	'	'
Credit Risk Exposure [Line Items]	'	'
Gross Credit Exposure	299,185,000	'
Noninvestment Grade [Member]	'	'
Credit Risk Exposure [Line Items]	'	'
Gross Credit Exposure	6,104,000	'
Internally Rated Investment Grade [Member]	'	'
Credit Risk Exposure [Line Items]	'	'
Gross Credit Exposure	43,953,000	'
Internally Rated Noninvestment Grade [Member]	'	'
Credit Risk Exposure [Line Items]	'	'
Gross Credit Exposure	$27,356,000	'

FAIR_VALUE_DEBT_Details

FAIR VALUE - DEBT (Details) (Level 2 [Member], USD $)	Mar. 31, 2014	Sep. 30, 2013
In Thousands, unless otherwise specified
Carrying Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term debt, fair value	$594,845	$529,845
Fair Market Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term debt, fair value	$622,213	$556,518

FAIR_VALUE_HIERARCHY_Details

FAIR VALUE - HIERARCHY (Details) (USD $)	Mar. 31, 2014		Sep. 30, 2013
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	$47,452		$56,088
Available for sale equity securities - energy industry	11,200	[1]	11,700
Liabilities	76,415		42,848
Fair Value, Measurements, Recurring [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Available for sale equity securities - energy industry	11,218	[1]	11,716	[1]
Other	1,263	[2]	1,129	[2]
Total assets at fair value	59,933		68,933
Total liabilities at fair value	76,415		42,848
Fair Value, Measurements, Recurring [Member] | Physical Forward Commodity Contracts [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	5,832		11,823
Liabilities	35,680		14,595
Fair Value, Measurements, Recurring [Member] | Financial Derivative Contracts - Natural Gas [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	41,620		44,249
Liabilities	40,451		28,248
Fair Value, Measurements, Recurring [Member] | Financial Derivative Contracts - Foreign Exchange [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		16
Liabilities	284		5
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Available for sale equity securities - energy industry	11,218	[1]	11,716	[1]
Other	1,263	[2]	1,129	[2]
Total assets at fair value	54,101		57,094
Total liabilities at fair value	40,451		28,248
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Physical Forward Commodity Contracts [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Financial Derivative Contracts - Natural Gas [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	41,620		44,249
Liabilities	40,451		28,248
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Financial Derivative Contracts - Foreign Exchange [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Available for sale equity securities - energy industry	0	[1]	0	[1]
Other	0	[2]	0	[2]
Total assets at fair value	5,832		11,839
Total liabilities at fair value	35,964		14,600
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Physical Forward Commodity Contracts [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	5,832		11,823
Liabilities	35,680		14,595
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Financial Derivative Contracts - Natural Gas [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Financial Derivative Contracts - Foreign Exchange [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		16
Liabilities	284		5
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Available for sale equity securities - energy industry	0	[1]	0	[1]
Other	0	[2]	0	[2]
Total assets at fair value	0		0
Total liabilities at fair value	0		0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Physical Forward Commodity Contracts [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Financial Derivative Contracts - Natural Gas [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Financial Derivative Contracts - Foreign Exchange [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Assets	0		0
Liabilities	$0		$0
[1]	Included in Other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets
[2]	Includes various money market funds.

INVESTMENTS_IN_EQUITY_INVESTEE2

INVESTMENTS IN EQUITY INVESTEES - SCHEDULE OF EQUITY METHOD INVESTMENTS (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013
Schedule of Equity Method Investments [Line Items]	'	'
Investments in equity investees	$152,337,000	$152,791,000
Steckman Ridge [Member]	'	'
Schedule of Equity Method Investments [Line Items]	'	'
Investments in equity investees	129,171,000	129,707,000
Steckman Ridge [Member] | Equity Method Investee [Member]	'	'
Schedule of Equity Method Investments [Line Items]	'	'
Outstanding principal balance	70,400,000	'
Iroquois [Member]	'	'
Schedule of Equity Method Investments [Line Items]	'	'
Investments in equity investees	$23,166,000	$23,084,000

INVESTMENTS_IN_EQUITY_INVESTEE3

INVESTMENTS IN EQUITY INVESTEES - SCHEDULE OF COST METHOD INVESTMENTS (Details) (USD $)	Mar. 31, 2014	Mar. 31, 2014	Sep. 30, 2012
In Millions, unless otherwise specified	Two Dot Wind Project in Montana [Member]	Carroll Wind Project in Iowa [Member]	OwnEnergy [Member]
	MW	MW
Schedule of Cost-method Investments [Line Items]	'	'	'
Cost method investments	$22	$42	$8.80
Cost method investment, ownership percentage	'	'	18.70%
Number of megawatts	9.7	20	'

EARNINGS_PER_SHARE_Details

EARNINGS PER SHARE (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013		Mar. 31, 2014		Mar. 31, 2013
Earnings Per Share [Abstract]	'		'		'		'
Net income	$172,971		$45,469		$180,664		$105,675
Basic earnings per share	'		'		'		'
Weighted average shares of common stock outstanding-basic (in shares)	42,079,000		41,789,000		42,050,000		41,742,000
Basic earnings per common share (usd per share)	$4.11		$1.09		$4.30		$2.53
Diluted earnings per share	'		'		'		'
Incremental shares	378,000	[1]	183,000	[1]	378,000	[1]	183,000	[1]
Weighted average shares of common stock outstanding-diluted (in shares)	42,457,000		41,972,000		42,428,000		41,925,000
Diluted earnings (loss) per common share (usd per share)	$4.07	[2]	$1.08	[2]	$4.26	[2]	$2.52	[2]
Anti-dilutive shares excluded from the calculation of diluted earnings per share (in shares)	0		0		0		0
[1]	Incremental shares consist of stock options, stock awards and performance units.
[2]	There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and six months ended MarchB 31, 2014 and 2013.

COMMON_STOCK_EQUITY_Details

COMMON STOCK EQUITY (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Balance as of beginning of period (shares)	'	'	41,961,534	'
Balance as of beginning of period	'	'	$887,384	'
Net income	172,971	45,469	180,664	105,675
Other comprehensive (loss)	24	936	-159	1,019
Common stock issued under stock plans	'	'	9,701	'
Tax benefits from stock plans	'	'	94	'
Cash dividend declared ($.84 per share)	'	'	-35,314	'
Treasury stock and other	'	'	-3,188	'
Balance as of end of period (shares)	42,074,766	'	42,074,766	'
Balance as of end of period	1,039,182	'	1,039,182	'
Cash dividend declared per share (usd per share)	$0.42	$0.40	$0.84	$0.80
Common Stock [Member]	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Balance as of beginning of period (shares)	'	'	41,962,000	'
Balance as of beginning of period	'	'	112,563	'
Common stock issued under stock plans (shares)	'	'	224,000	'
Common stock issued under stock plans	'	'	143	'
Treasury stock and other (shares)	'	'	-111,000	'
Balance as of end of period (shares)	42,075,000	'	42,075,000	'
Balance as of end of period	112,706	'	112,706	'
Premium on Common Stock [Member]	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Balance as of beginning of period	'	'	300,196	'
Common stock issued under stock plans	'	'	2,817	'
Tax benefits from stock plans	'	'	94	'
Balance as of end of period	303,107	'	303,107	'
Accumulated Other Comprehensive (Loss) Income [Member]	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Balance as of beginning of period	'	'	-1,621	'
Other comprehensive (loss)	'	'	-159	'
Balance as of end of period	-1,780	'	-1,780	'
Treasury Stock And Other [Member]	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Balance as of beginning of period	'	'	-128,638	'
Common stock issued under stock plans	'	'	6,741	'
Treasury stock and other	'	'	-3,188	'
Balance as of end of period	-125,085	'	-125,085	'
Retained Earnings [Member]	'	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Balance as of beginning of period	'	'	604,884	'
Net income	'	'	180,664	'
Cash dividend declared ($.84 per share)	'	'	-35,314	'
Balance as of end of period	$750,234	'	$750,234	'

COMMON_STOCK_EQUITY_ACCUMULATE

COMMON STOCK EQUITY - ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014		Mar. 31, 2013
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'	'	'		'
Balance as of beginning of period	'	'	($1,621)		($10,771)
Other comprehensive (loss), before reclassifications, net of tax	'	'	-586		282
Amounts reclassified from accumulated other comprehensive income, net of tax	'	'	427		737
Other comprehensive income (loss)	24	936	-159		1,019
Balance as of end of period	-1,780	-9,752	-1,780		-9,752
Tax on other comprehensive income before reclassifications	'	'	372		-200
Tax on amounts reclassified from accumulated other comprehensive income	'	'	-283		-422
Tax on net current-period other comprehensive income	'	'	89		-622
Available for Sale Securities [Member]	'	'	'		'
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'	'	'		'
Balance as of beginning of period	'	'	5,400		4,921
Other comprehensive (loss), before reclassifications, net of tax	'	'	-295		327
Amounts reclassified from accumulated other comprehensive income, net of tax	'	'	0		0
Other comprehensive income (loss)	'	'	-295		327
Balance as of end of period	5,105	5,248	5,105		5,248
Tax on other comprehensive income before reclassifications	'	'	203		-226
Tax on amounts reclassified from accumulated other comprehensive income	'	'	0		0
Tax on net current-period other comprehensive income	'	'	203		-226
Cash Flow Hedges [Member]	'	'	'		'
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'	'	'		'
Balance as of beginning of period	'	'	12		51
Other comprehensive (loss), before reclassifications, net of tax	'	'	-291		-45
Amounts reclassified from accumulated other comprehensive income, net of tax	'	'	105	[1]	28	[1]
Other comprehensive income (loss)	'	'	-186		-17
Balance as of end of period	-174	34	-174		34
Tax on other comprehensive income before reclassifications	'	'	169		26
Tax on amounts reclassified from accumulated other comprehensive income	'	'	-60		-16
Tax on net current-period other comprehensive income	'	'	109		10
Postemployment Benefit Obligation [Member]	'	'	'		'
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]	'	'	'		'
Balance as of beginning of period	'	'	-7,033		-15,743
Other comprehensive (loss), before reclassifications, net of tax	'	'	0		0
Amounts reclassified from accumulated other comprehensive income, net of tax	'	'	322	[2]	709	[2]
Other comprehensive income (loss)	'	'	322		709
Balance as of end of period	-6,711	-15,034	-6,711		-15,034
Tax on other comprehensive income before reclassifications	'	'	0		0
Tax on amounts reclassified from accumulated other comprehensive income	'	'	-223		-406
Tax on net current-period other comprehensive income	'	'	($223)		($406)
[1]	Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases in the Unaudited Condensed Consolidated Statements of Operations.
[2]	Included in the computation of net periodic pension cost, a component of operations and maintenance expense in the Unaudited Condensed Consolidated Statements of Operations.

DEBT_CREDIT_FACILITIES_Details

DEBT - CREDIT FACILITIES (Details) (USD $)	Mar. 31, 2014		Jan. 30, 2014		Jan. 24, 2014	Sep. 30, 2013
Line of Credit Facility [Line Items]	'		'		'	'
Bank term loan	$63,200,000		'		'	$365,600,000
NJR [Member] | Letter of Credit [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Letters of credit outstanding, amount	25,300,000		'		'	17,900,000
NJR [Member] | Bank Revolving Credit Facility [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Bank credit facilities	425,000,000	[1]	325,000,000	[1]	'	325,000,000	[1]
Amount available at end of period	384,459,000	[2]	'		'	210,110,000	[2]
Line of credit facility, additional borrowing capacity	'		'		50,000,000	'
NJR [Member] | Bank Revolving Credit Facility [Member] | Notes Payable to Banks [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Amount outstanding at end of period	15,200,000		'		'	97,000,000
Weighted average interest rate at end of period	1.15%		'		'	1.00%
NJR [Member] | Bank Term Loan [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Amount outstanding at end of period	0		'		'	100,000,000
Weighted average interest rate at end of period	0.00%		'		'	0.74%
Amount available at end of period	100,000,000		'		'	0
Bank term loan	100,000,000	[3]	'		'	100,000,000	[3]
NJR [Member] | Bank Letter of Credit Facility [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Bank credit facilities	10,000,000	[3],[4]	'		'	10,000,000	[3],[4]
NJNG [Member] | Letter of Credit [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Letters of credit outstanding, amount	731,000		'		'	266,000
NJNG [Member] | Bank Revolving Credit Facility [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Bank credit facilities	250,000,000	[1]	'		'	250,000,000	[1]
Amount available at end of period	201,269,000	[5]	'		'	81,400,000	[5]
NJNG [Member] | Bank Revolving Credit Facility [Member] | Commercial Paper [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Amount outstanding at end of period	48,000,000		'		'	168,600,000
Weighted average interest rate at end of period	0.12%		'		'	0.13%
NJNG [Member] | Bank Credit Facility Dedicated to EDA Bonds [Member]	'		'		'	'
Line of Credit Facility [Line Items]	'		'		'	'
Bank credit facilities	$100,000,000	[1],[4]	'		'	$100,000,000	[1],[4]
[1]	Committed credit facilities, which require commitment fees on the unused amounts.
[2]	Letters of credit outstanding total $25.3 million and $17.9 million as of MarchB 31, 2014 and SeptemberB 30, 2013, respectively, which reduces amount available by the same amount.
[3]	Uncommitted.
[4]	There were no borrowings outstanding as of MarchB 31, 2014 and SeptemberB 30, 2013, respectively.
[5]	Letters of credit outstanding total $731,000 and $266,000 as of MarchB 31, 2014 and SeptemberB 30, 2013, respectively, which reduces the amount available by the same amount.

DEBT_SCHEDULE_OF_LONG_TERM_DEB

DEBT - SCHEDULE OF LONG TERM DEBT (Details) (USD $)

6 Months Ended

24 Months Ended

6 Months Ended

6 Months Ended

3 Months Ended

1 Months Ended

1 Months Ended

6 Months Ended

0 Months Ended

Mar. 31, 2014

Mar. 31, 2013

10-May-13

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 14, 2014

Apr. 10, 2014

NJR [Member]

NJR [Member]

NJR [Member]

NJR [Member]

NJR [Member]

NJR [Member]

NJR [Member]

NJNG [Member]

NJNG [Member]

NJNG [Member]

NJNG [Member]

NJNG [Member]

NJNG [Member]

NJNG [Member]

Long-term Debt [Member]

Debt Shelf Facility Metlife [Member]

Debt Shelf Facility Metlife [Member]

Debt Shelf Facility Metlife [Member]

Debt Shelf Facility Metlife [Member]

Debt Shelf Facility Prudential [Member]

Debt Shelf Facility Prudential [Member]

Debt Shelf Facility Metlife 2 [Member]

First Mortgage [Member]

First Mortgage [Member]

First Mortgage [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

NJNG [Member]

Unsecured Senior Note 1.94% [Member]

Unsecured Senior Note 2.51% [Member]

Unsecured Senior Note 3.25% [Member]

Series QQ [Member]

Series HH [Member]

Series RR [Member]

First Mortgage [Member]

Series HH [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility, maximum borrowing capacity

'

'

'

$100,000,000

'

'

$75,000,000

'

$100,000,000

'

'

'

'

'

'

'

'

Line of credit facility, issuance period

'

'

'2 years

'

'

'

'3 years

'

'3 years

'

'

'

'

'

'

'

'

Amount issued and outstanding

'

'

'

'

25,000,000

25,000,000

'

50,000,000

'

'

'

'

'

'

'

'

'

Interest rate, stated percentage

'

'

'

'

1.94%

2.51%

'

3.25%

'

'

'

3.58%

5.00%

4.61%

'

4.77%

'

Repayments of First Mortgage Bond

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,000,000

Repayments of Long-term Debt

65,017,000

3,833,000

'

'

'

'

'

'

'

'

'

'

'

'

60,000,000

'

'

Line of credit facility, remaining borrowing capacity

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

Proceeds from issuance of long-term debt

'

'

'

'

'

'

'

'

'

'

'

70,000,000

'

55,000,000

'

'

'

Sale leaseback transaction, gross proceeds

'

'

'

'

'

'

'

'

'

$7,600,000

$7,100,000

'

'

'

'

'

'

EMPLOYEE_BENEFIT_PLANS_DEFINED

EMPLOYEE BENEFIT PLANS - DEFINED BENEFIT PLANS (Details) (USD $)	3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended			12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Sep. 30, 2013
	Pension [Member]	Pension [Member]	Pension [Member]	Pension [Member]	OPEB [Member]	OPEB [Member]	OPEB [Member]	OPEB [Member]	Pension Plans Excluding Pension Equalization Plan, Defined Benefit [Member]	Pension Plans Excluding Pension Equalization Plan, Defined Benefit [Member]
Components of net periodic cost	'	'	'	'	'	'	'	'	'	'
Service cost	$1,536,000	$1,718,000	$3,072,000	$3,436,000	$981,000	$1,171,000	$1,962,000	$2,342,000	'	'
Interest cost	2,517,000	2,235,000	5,033,000	4,470,000	1,433,000	1,287,000	2,866,000	2,574,000	'	'
Expected return on plan assets	-3,869,000	-3,706,000	-7,738,000	-7,412,000	-1,043,000	-913,000	-2,087,000	-1,826,000	'	'
Recognized actuarial loss	1,399,000	1,911,000	2,798,000	3,822,000	625,000	964,000	1,250,000	1,928,000	'	'
Prior service cost amortization	28,000	27,000	56,000	54,000	-89,000	7,000	-178,000	14,000	'	'
Recognized net initial obligation	0	0	0	0	2,000	-89,000	5,000	-178,000	'	'
Net periodic cost	1,611,000	2,185,000	3,221,000	4,370,000	1,909,000	2,427,000	3,818,000	4,854,000	'	'
Defined benefit plan, contributions by employer	'	'	'	'	'	'	'	'	$0	$20,000,000

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	6 Months Ended		12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'	'	'
Effective income tax rate	28.80%	25.40%	'
Forecasted annual ITC and PTC for effective tax rate calculation	$18,900,000	'	$13,400,000
Operating Loss Carryforwards [Line Items]	'	'	'
ITC carryforward, expiration period	'	'	'20 years
State and Local Jurisdiction [Member]	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Net operating loss carryforwards	125,300,000	'	104,400,000
Net operating loss carryforwards, expiration term	'20 years	'	'
Deferred tax assets, operating loss carryforwards	7,300,000	'	6,100,000
Valuation allowance	229,000	'	262,000
Internal Revenue Service (IRS) [Member]	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
ITC carryforward	'	'	$40,000,000

COMMITMENTS_AND_CONTINGENT_LIA2

COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) (USD $)	6 Months Ended
	Mar. 31, 2014
Long-term Purchase Commitment [Line Items]	'
Current charges recoverable through BGSS	$95,100,000
Natural Gas Purchases [Member] | NJRES [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	320,608,000
2015	99,106,000
2016	15,452,000
2017	0
2018	0
Thereafter	0
Natural Gas Purchases [Member] | NJNG [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	55,132,000
2015	107,920,000
2016	6,522,000
2017	113,000
2018	0
Thereafter	0
Storage Demand Fees [Member] | NJRES [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	15,571,000
2015	20,773,000
2016	9,931,000
2017	5,425,000
2018	3,318,000
Thereafter	4,000,000
Storage Demand Fees [Member] | NJNG [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	12,995,000
2015	20,611,000
2016	13,285,000
2017	10,883,000
2018	9,299,000
Thereafter	13,948,000
Pipeline Demand Fees [Member] | NJRES [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	35,978,000
2015	43,174,000
2016	33,561,000
2017	18,307,000
2018	12,548,000
Thereafter	7,175,000
Pipeline Demand Fees [Member] | NJNG [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	32,139,000
2015	74,142,000
2016	43,312,000
2017	34,247,000
2018	33,978,000
Thereafter	194,675,000
Natural Gas Purchases and Future Demand Fees [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	472,423,000	[1]
2015	365,726,000	[1]
2016	122,063,000	[1]
2017	68,975,000	[1]
2018	59,143,000	[1]
Thereafter	219,798,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	372,157,000
2015	163,053,000
2016	58,944,000
2017	23,732,000
2018	15,866,000
Thereafter	11,175,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member]	'
Long-term Purchase Commitment [Line Items]	'
2014	100,266,000
2015	202,673,000
2016	63,119,000
2017	45,243,000
2018	43,277,000
Thereafter	$208,623,000
[1]	Does not include amounts related to intercompany asset management agreements between NJRES and NJNG.

COMMITMENTS_AND_CONTINGENT_LIA3

COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details) (USD $)	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2014
			Minimum [Member]	Maximum [Member]	Environmental Remediation Costs Expended, Net of Recoveries [Member]	Environmental Remediation Costs Expended, Net of Recoveries [Member]	Environmental Remediation Costs Liability for Future Expenditures [Member]	Environmental Remediation Costs Liability for Future Expenditures [Member]	SBC [Member]
									July 2013 SBC Filing [Member]
Site Contingency [Line Items]	'	'	'	'	'	'	'	'	'
Annual recovery amount approved by the Board of Public Utilities	'	'	'	'	'	'	'	'	$18,700,000
Regulatory assets	368,319,000	402,202,000	'	'	32,661,000	46,968,000	183,600,000	183,600,000	'
Litigation settlement, gross	'	'	$159,800,000	$261,200,000	'	'	'	'	'

BUSINESS_SEGMENT_AND_OTHER_OPE2

BUSINESS SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013		Mar. 31, 2014		Mar. 31, 2013
Segment Reporting Information [Line Items]	'		'		'		'
Utility	$394,528		$351,750		$627,997		$570,599
Nonutility	1,185,041		609,135		1,829,977		1,126,305
Total operating revenues	1,579,569		960,885		2,457,974		1,696,904
Depreciation and amortization	12,828		11,721		25,394		23,024
Interest income	216	[1]	192	[1]	512	[1]	399	[1]
Interest expense, net of capitalized interest	6,306		5,746		12,601		11,571
Income tax provision (benefit)	71,680		12,065		73,185		36,045
Equity in earnings of affiliates	3,233		3,530		5,375		6,085
Net financial earnings (loss)	151,920		68,664		191,780		104,157
Capital expenditures	56,242		41,243		116,765		90,862
Canada	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Percentage to total operating revenues	'		'		4.00%		6.90%
Intercompany [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Nonutility	297		186		499		449
Energy Services [Member] | Intercompany [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Nonutility	67,749		4,444		71,767		4,551
Operating Segments [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Total operating revenues	1,638,791		956,996		2,512,142		1,682,766
Depreciation and amortization	12,622		11,515		24,981		22,636
Interest income	451	[1]	409	[1]	980	[1]	847	[1]
Interest expense, net of capitalized interest	6,175		5,487		12,359		11,013
Income tax provision (benefit)	72,255		12,753		74,117		36,898
Equity in earnings of affiliates	3,233		3,530		5,375		6,085
Net financial earnings (loss)	153,511		69,713		193,572		105,309
Capital expenditures	55,970		41,099		116,288		90,564
Operating Segments [Member] | Natural Gas Distribution [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Depreciation and amortization	9,972		9,399		19,807		18,676
Interest income	181	[1]	146	[1]	442	[1]	313	[1]
Interest expense, net of capitalized interest	3,888		3,549		7,872		7,133
Income tax provision (benefit)	23,725		22,794		37,908		37,301
Net financial earnings (loss)	47,043		45,917		74,682		71,409
Capital expenditures	35,484		31,554		70,885		65,699
Operating Segments [Member] | Natural Gas Distribution [Member] | External Customers [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Utility	394,528		351,750		627,997		570,599
Operating Segments [Member] | Energy Services [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Depreciation and amortization	13		11		25		22
Interest expense, net of capitalized interest	661		640		1,277		1,208
Income tax provision (benefit)	64,345		-5,203		53,072		10,961
Net financial earnings (loss)	91,407		16,368		98,781		19,382
Operating Segments [Member] | Energy Services [Member] | External Customers [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Nonutility	1,173,835	[2]	599,362	[2]	1,807,526	[2]	1,102,997	[2]
Operating Segments [Member] | Clean Energy Ventures [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Depreciation and amortization	2,635		2,104		5,146		3,935
Interest expense, net of capitalized interest	1,249		822		2,435		1,605
Income tax provision (benefit)	-17,388		-6,457		-19,432		-14,226
Net financial earnings (loss)	12,807		5,154		16,421		10,459
Capital expenditures	20,486		9,545		45,403		24,865
Operating Segments [Member] | Clean Energy Ventures [Member] | External Customers [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Nonutility	2,679		1,440		4,852		4,619
Operating Segments [Member] | Midstream Investments [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Depreciation and amortization	2		1		3		3
Interest income	270	[1]	263	[1]	538	[1]	534	[1]
Interest expense, net of capitalized interest	377		476		775		1,067
Income tax provision (benefit)	1,573		1,619		2,569		2,862
Equity in earnings of affiliates	4,141		4,469		7,083		7,960
Net financial earnings (loss)	2,254		2,274		3,688		4,059
Corporate, Non-Segment [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Depreciation and amortization	208		199		415		390
Interest income	0	[1]	1	[1]	0	[1]	2	[1]
Interest expense, net of capitalized interest	131		259		242		558
Income tax provision (benefit)	-1,129		-906		-1,320		-1,029
Net financial earnings (loss)	-1,576		-1,037		-1,777		-1,131
Capital expenditures	272		144		477		298
Corporate, Non-Segment [Member] | External Customers [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Nonutility	8,527		8,334		17,599		18,689
Consolidation, Eliminations [Member]	'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'
Nonutility	-68,046		-4,631		-72,266		-5,000
Depreciation and amortization	-2		7		-2		-2
Interest income	-235	[1]	-218	[1]	-468	[1]	-450	[1]
Income tax provision (benefit)	554		218		388		176
Equity in earnings of affiliates	-908		-939		-1,708		-1,875
Net financial earnings (loss)	($15)		($12)		($15)		($21)
[1]	Included in other income on the Unaudited Condensed Consolidated Statements of Operations.
[2]	Includes sales to Canada, which accounted for 4 percent and 6.9 percent of total operating revenues during the six months ended MarchB 31, 2014 and 2013, respectively.

BUSINESS_SEGMENT_AND_OTHER_OPE3

BUSINESS SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS LOSS RECONCILIATION (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013		Mar. 31, 2014		Mar. 31, 2013
Net financial earnings (loss)	$151,920		$68,664		$191,780		$104,157
Unrealized (gain) loss from derivative instruments and related transactions	-13,256	[1]	38,800	[1]	52,395	[1]	20,466	[1]
Effects of economic hedging related to natural gas inventory	-18,668		-2,117		-41,548		-22,865
Tax adjustments	10,873		-13,488		269		881
NET INCOME	172,971		45,469		180,664		105,675
Transactions Between NJNG and NJRES [Member]	'		'		'		'
Unrealized losses related to intercompany transactions	($957)		($377)		($672)		($310)
[1]	Excludes unrealized losses related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $(957,000) and $(377,000) for the three months ended and $(672,000) and $(310,000) for the six months ended MarchB 31, 2014 and 2013, respectively.

BUSINESS_SEGMENT_AND_OTHER_OPE4

BUSINESS SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) (USD $)	Mar. 31, 2014		Sep. 30, 2013
In Thousands, unless otherwise specified
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	$3,161,210		$3,004,783
Corporate, Non-Segment [Member]	'		'
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	89,810		85,293
Operating Segments [Member] | Natural Gas Distribution [Member]	'		'
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	2,157,317		2,094,940
Operating Segments [Member] | Energy Services [Member]	'		'
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	546,010		468,096
Operating Segments [Member] | Clean Energy Ventures [Member]	'		'
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	312,258		253,663
Operating Segments [Member] | Midstream [Member]	'		'
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	153,050		153,536
Operating Segments [Member] | Subtotal [Member]	'		'
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	3,168,635		2,970,235
Intercompany/Eliminations [Member]	'		'
Segment Reporting, Asset Reconciling Item [Line Items]	'		'
Assets	($97,235)	[1]	($50,745)	[1]
[1]	Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Sep. 30, 2013

Mar. 31, 2014

Sep. 30, 2013

Mar. 31, 2014

Sep. 30, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Sep. 30, 2013

Mar. 31, 2014

NJRES to Steckman RIdge and Iroquios Affliates [Member]

NJRES to Steckman RIdge and Iroquios Affliates [Member]

NJRES to Steckman Ridge Affiliate

NJRES to Steckman Ridge Affiliate

NJRES to Iroquois Affiliate [Member]

NJRES to Iroquois Affiliate [Member]

NJNG to Steckman RIdge Affiliate

NJNG to Steckman RIdge Affiliate

NJNG to Steckman RIdge and Iroquios Affiliates [Member]

NJNG to Steckman RIdge and Iroquios Affiliates [Member]

NJNG to Iroquois Affiliate [Member]

NJNG to Iroquois Affiliate [Member]

NJNG to NJRES Affiliate [Member]

MMcf

MMcf

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Demand fees expense recognized pertaining to related party agreement

$1,500,000

$3,200,000

'

'

'

'

'

'

$4,800,000

$2,700,000

'

'

'

Due to related parties

'

'

166,000

159,000

403,000

390,000

776,000

775,000

'

'

62,000

61,000

'

Related party agreement term

'

'

'

'

'

'

'10 years

'

'

'

'

'

'

Agreement for natural gas storage capacity between NJNG and affiliate (MMcf)

'

'

'

'

'

'

3,000

'

'

'

'

'

'

Approximate annual demand fees under agreement from April 1 2010 to March 31 2020

'

'

'

'

'

'

$9,300,000

'

'

'

'

'

'

Natural gas sold at cost under asset management agreement (MMcf)

'

'

'

'

'

'

'

'

'

'

'

'

1,000