10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10‑Q

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2012

OR

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM             TO
Commission file number 1‑8359
NEW JERSEY RESOURCES CORPORATION
(Exact name of registrant as specified in its charter)
New Jersey	22‑2376465
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification Number)
1415 Wyckoff Road, Wall, New Jersey 07719	732‑938‑1480
(Address of principal executive offices)	(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12 (b) of the Act:
Common Stock ‑ $2.50 Par Value	New York Stock Exchange
(Title of each class)	(Name of each exchange on which registered)

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes: x            No: o

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

Yes: x            No: o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b‑2 of the Exchange Act.

Large accelerated filer:x	Accelerated filer:o	Non-accelerated filer: o	Smaller reporting company: o
		(Do not check if a smaller reporting company)

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

Yes: o            No: x

The number of shares outstanding of $2.50 par value Common Stock as of April 30, 2012 was 41,551,934.

New Jersey Resources Corporation

TABLE OF CONTENTS

			Page
Information Concerning Forward-Looking Statements			1
PART I. FINANCIAL INFORMATION
	ITEM 1.	Unaudited Condensed Consolidated Financial Statements	2
		Notes to Unaudited Condensed Consolidated Financial Statements	6
		Note 1. Nature of the Business	6
		Note 2. Summary of Significant Accounting Policies	6
		Note 3. Regulation	7
		Note 4. Derivative Instruments	9
		Note 5. Fair Value	13
		Note 6. Investments in Equity Investees	15
		Note 7. Earnings Per Share	16
		Note 8. Debt	16
		Note 9. Employee Benefit Plans	17
		Note 10. Income Taxes	17
		Note 11. Commitments and Contingent Liabilities	17
		Note 12. Business Segment and Other Operations Data	19
		Note 13. Related Party Transactions	23
	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	23
	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	44
	ITEM 4.	Controls and Procedures	47
PART II. OTHER INFORMATION
	ITEM 1.	Legal Proceedings	48
	ITEM 1A.	Risk Factors	48
	ITEM 2.	Unregistered Sale of Equity Securities and Use of Proceeds	48
	ITEM 6.	Exhibits	49
		Signatures	50

New Jersey Resources Corporation

INFORMATION CONCERNING FORWARD-LOOKING STATEMENTS                                                                           

Certain statements contained in this report, including, without limitation, statements as to management expectations and beliefs presented in Part I, Item 2. “Management's Discussion and Analysis of Financial Condition and Results of Operations,” Part I, Item 3. “Quantitative and Qualitative Disclosures about Market Risk,” Part II, Item I. “Legal Proceedings” and in the notes to the financial statements are forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements can also be identified by the use of forward-looking terminology such as “may,” “intend,” “expect,” “believe,” "will" or “continue” or comparable terminology and are made based upon management's current expectations and beliefs as of this date concerning future developments and their potential effect upon New Jersey Resources Corporation (NJR or the Company). There can be no assurance that future developments will be in accordance with management's expectations or that the effect of future developments on the Company will be those anticipated by management.

The Company cautions readers that the assumptions that form the basis for forward-looking statements regarding customer growth, customer usage, qualifications for federal investment tax credits (ITCs) and Solar Renewable Energy Certificates (SRECs), financial condition, results of operations, cash flows, capital requirements, market risk and other matters for fiscal 2012 and thereafter include many factors that are beyond the Company's ability to control or estimate precisely, such as estimates of future market conditions, the behavior of other market participants and changes in the debt and equity capital markets. The factors that could cause actual results to differ materially from NJR's expectations include, but are not limited to, those discussed in Item 1A. Risk Factors of NJR's 2011 Annual Report on Form 10-K and Part II, Item 1A of this Form 10-Q, as well as the following:

• weather and economic conditions;

• demographic changes in the New Jersey Natural Gas (NJNG) service territory and their effect on NJNG's customer growth;

• volatility of natural gas and other commodity prices and their impact on NJNG customer usage, NJNG's incentive programs, NJR Energy Services' (NJRES) operations and on the Company's risk management efforts;

• changes in rating agency requirements and/or credit ratings and their effect on availability and cost of capital to the Company;

• the impact of volatility in the credit markets;

• the ability to comply with debt covenants;

• the impact to the asset values and resulting higher costs and funding obligations of NJR's pension and postemployment benefit plans as a result of a downturn in the financial markets, a lower discount rate, and impacts associated with the Patient Protection and Affordable Care Act;

• accounting effects and other risks associated with hedging activities and use of derivatives contracts;

• commercial and wholesale credit risks, including the availability of creditworthy customers and counterparties, liquidity in the wholesale energy trading market and the Company's ability to recover all of NJRES' funds in the MF Global liquidation proceedings;

• the ability to obtain governmental approvals and/or financing for the construction, development and operation of certain non-regulated energy investments;

• risks associated with the management of the Company's joint ventures and partnerships;

• risks associated with our investments in solar energy projects, including the availability of regulatory and tax incentives, logistical risks and potential delays related to construction, permitting, regulatory approvals and electric grid interconnection, the availability of viable projects and NJR's eligibility for ITCs, the future market for SRECs and operational risks related to projects in service;

• timing of qualifying for ITCs due to delays or failures to complete planned solar energy projects and the resulting effect on our effective tax rate and earnings;

• the level and rate at which NJNG's costs and expenses are incurred and the extent to which they are allowed to be recovered from customers through the regulatory process;

• access to adequate supplies of natural gas and dependence on third-party storage and transportation facilities for natural gas supply;

• operating risks incidental to handling, storing, transporting and providing customers with natural gas;

• risks related to our employee workforce;

• the regulatory and pricing policies of federal and state regulatory agencies;

• the costs of compliance with the proposed regulatory framework for over-the-counter derivatives;

• the costs of compliance with present and future environmental laws, including potential climate change-related legislation;

• risks related to changes in accounting standards;

• the disallowance of recovery of environmental-related expenditures and other regulatory changes;

• environmental-related and other litigation and other uncertainties; and

• the impact of natural disasters, terrorist activities, and other extreme events.

While the Company periodically reassesses material trends and uncertainties affecting the Company's results of operations and financial condition in connection with its preparation of management's discussion and analysis of results of operations and financial condition contained in its Quarterly and Annual Reports, the Company does not, by including this statement, assume any obligation to review or revise any particular forward-looking statement referenced herein in light of future events.

Page 1

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS                                                                                                                                          

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands, except per share data)	2012		2011		2012		2011
OPERATING REVENUES
Utility	$	226,023	$	433,248	$	417,397	$	723,924
Nonutility	386,898		543,739		837,935		966,215
Total operating revenues	612,921		976,987		1,255,332		1,690,139
OPERATING EXPENSES
Gas purchases:
Utility	78,301		235,001		163,931		395,450
Nonutility	382,055		548,618		788,472		977,865
Operation and maintenance	39,185		37,896		78,130		75,312
Regulatory rider expenses	18,443		24,304		30,986		41,002
Depreciation and amortization	10,439		8,477		20,039		16,931
Energy and other taxes	16,809		29,489		30,867		50,114
Total operating expenses	545,232		883,785		1,112,425		1,556,674
OPERATING INCOME	67,689		93,202		142,907		133,465
Other income	349		805		876		1,250
Interest expense, net of capitalized interest	5,427		5,078		10,432		10,341
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	62,611		88,929		133,351		124,374
Income tax provision	11,094		28,612		27,131		42,465
Equity in earnings of affiliates	3,018		3,610		5,672		6,527
NET INCOME	$	54,535	$	63,927	$	111,892	$	88,436
EARNINGS PER COMMON SHARE
BASIC	$1.31		$1.55		$2.70		$2.14
DILUTED	$1.31		$1.54		$2.68		$2.13
DIVIDENDS PER COMMON SHARE	$0.38		$0.36		$0.76		$0.72
WEIGHTED AVERAGE SHARES OUTSTANDING
BASIC	41,509		41,352		41,472		41,316
DILUTED	41,711		41,553		41,673		41,516

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Three Months Ended					Six Months Ended
	March 31,					March 31,
(Thousands)	2012			2011		2012			2011
Net income	$	54,535		$	63,927	$	111,892		$	88,436
Other comprehensive income, net of tax
Unrealized (loss) gain on available for sale securities, net of tax of $575, $(266), $(25) and $(552), respectively (1)	$	(833	)	$	390	$	36		$	800
Net unrealized (loss) gain on derivatives, net of tax of $18, $(16), $41 and $(55), respectively	(30		)	26		(70		)	95
Adjustment to postemployment benefit obligation, net of tax of $(149), $0, $(299) and $0, respectively	219			—		438			—
Other comprehensive income	$	(644	)	$	416	$	404		$	895
Comprehensive income	$	53,891		$	64,343	$	112,296		$	89,331

(1) Available for sale securities are included in other noncurrent assets in the Unaudited Condensed Consolidated Balance Sheets.

See Notes to Unaudited Condensed Consolidated Financial Statements

Page 2

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                      

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	Six Months Ended
	March 31,
(Thousands)	2012			2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	111,892		$	88,436
Adjustments to reconcile net income to cash flows from operating activities:
Unrealized (gain) loss on derivative instruments	(15,353		)	58,049
Depreciation and amortization	20,039			17,369
Allowance for equity used during construction	(139		)	(499		)
Allowance for bad debt expense	1,586			2,572
Deferred income taxes	20,920			(6,374		)
Manufactured gas plant remediation costs	(4,964		)	(5,727		)
Equity in earnings of affiliates, net of distributions received	3,852			(13		)
Cost of removal - asset retirement obligations	(368		)	(456		)
Contributions to postemployment benefit plans	(22,982		)	(8,068		)
Changes in:
Components of working capital	(31,567		)	9,862
Other noncurrent assets	11,690			16,234
Other noncurrent liabilities	10,018			9,624
Cash flows from operating activities	104,624			181,009
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Expenditures for
Utility plant	(42,380		)	(43,581		)
Solar equipment	(61,786		)	(11,533		)
Real estate properties and other	(459		)	(367		)
Cost of removal	(6,765		)	(3,605		)
Withdrawal from restricted cash construction fund	136			38
Cash flows (used in) investing activities	(111,254		)	(59,048		)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Proceeds from issuance of common stock	7,164			7,297
Tax benefit from stock options exercised	222			347
Proceeds from sale-leaseback transaction	6,522			5,901
Payments of long-term debt	(3,371		)	(23,919		)
Purchases of treasury stock	(4,800		)	(7,222		)
Payments of common stock dividends	(30,695		)	(28,917		)
Net proceeds from short-term debt	31,950			—
Cash flows from (used in) financing activities	6,992			(46,513		)
Change in cash and cash equivalents	362			75,448
Cash and cash equivalents at beginning of period	7,440			943
Cash and cash equivalents at end of period	$	7,802		$	76,391
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	19,773		$	(106,839	)
Inventories	118,920			141,246
Recovery of gas costs	(21,177		)	28,309
Gas purchases payable	(80,941		)	(1,285		)
Prepaid and accrued taxes	47,025			78,809
Accounts payable and other	(4,573		)	(3,414		)
Restricted broker margin accounts	(14,249		)	(48,713		)
Customers' credit balances and deposits	(82,321		)	(77,917		)
Other current assets	(14,024		)	(334		)
Total	$	(31,567	)	$	9,862
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for:
Interest (net of amounts capitalized)	$	8,324		$	9,172
Income taxes	$	814		$	4,047
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING ACTIVITIES
Accrued capital expenditures	$	5,041		$	(3,472	)

See Notes to Unaudited Condensed Consolidated Financial Statements

Page 3

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                      

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

ASSETS

(Thousands)	March 31, 2012			September 30, 2011
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	1,634,936		$	1,595,278
Real estate properties, solar and other, at cost	179,402			110,886
Total property, plant and equipment	1,814,338			1,706,164
Accumulated depreciation and amortization	(417,563		)	(410,237		)
Property, plant and equipment, net	1,396,775			1,295,927
CURRENT ASSETS
Cash and cash equivalents	7,802			7,440
Customer accounts receivable
Billed	179,006			209,266
Unbilled revenues	16,428			7,333
Allowance for doubtful accounts	(4,806		)	(4,612		)
Regulatory assets	80,920			17,630
Gas in storage, at average cost	175,209			294,475
Materials and supplies, at average cost	7,741			7,395
Prepaid and accrued taxes	23,803			54,311
Derivatives, at fair value	103,506			100,338
Restricted broker margin accounts	66,515			22,595
Deferred taxes	—			1,498
Other	18,552			14,698
Total current assets	674,676			732,367
NONCURRENT ASSETS
Investments in equity investees	157,049			159,063
Regulatory assets	410,901			434,185
Derivatives, at fair value	3,333			6,515
Other	27,005			21,387
Total noncurrent assets	598,288			621,150
Total assets	$	2,669,739		$	2,649,444

See Notes to Unaudited Condensed Consolidated Financial Statements

Page 4

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                      

CAPITALIZATION AND LIABILITIES

(Thousands)	March 31, 2012		September 30, 2011
CAPITALIZATION
Common stock equity	$	862,242	$	776,257
Long-term debt	429,450		426,797
Total capitalization	1,291,692		1,203,054
CURRENT LIABILITIES
Current maturities of long-term debt	8,117		7,575
Short-term debt	191,300		159,350
Gas purchases payable	171,750		252,691
Accounts payable and other	63,268		65,960
Dividends payable	15,780		14,912
Deferred and accrued taxes	17,295		778
Regulatory liabilities	—		4,633
New Jersey clean energy program	13,522		15,011
Derivatives, at fair value	92,028		68,698
Restricted broker margin accounts	29,671		—
Customers' credit balances and deposits	31,455		113,776
Total current liabilities	634,186		703,384
NONCURRENT LIABILITIES
Deferred income taxes	353,237		327,782
Deferred investment tax credits	6,066		6,227
Deferred revenue	5,966		7,633
Derivatives, at fair value	3,751		6,341
Manufactured gas plant remediation	182,900		182,900
Postemployment employee benefit liability	95,176		114,305
Regulatory liabilities	63,391		59,837
New Jersey clean energy program	—		5,133
Asset retirement obligation	27,537		27,026
Other	5,837		5,822
Total noncurrent liabilities	743,861		743,006
Commitments and contingent liabilities (Note 11)
Total capitalization and liabilities	$	2,669,739	$	2,649,444

See Notes to Unaudited Condensed Consolidated Financial Statements

Page 5

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS                                              

1. NATURE OF THE BUSINESS

New Jersey Resources Corporation (NJR or the Company) provides regulated gas distribution services and certain non-regulated businesses primarily through the following subsidiaries:

New Jersey Natural Gas Company (NJNG) provides natural gas utility service to approximately 499,500 retail customers in central and northern New Jersey and is subject to rate regulation by the New Jersey Board of Public Utilities (BPU). NJNG comprises the Natural Gas Distribution segment;

NJR Energy Services Company (NJRES) 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 (NJRCEV) comprises the Clean Energy Ventures segment and reports the results of operations and assets related to the Company's capital investments in renewable energy projects, including commercial and residential solar projects;

NJR Energy Holdings Corporation (NJREH) primarily invests in energy-related ventures through its subsidiaries, NJNR Pipeline Company (Pipeline), which holds the Company's 5.53 percent ownership interest in Iroquois Gas Transmission L.P. (Iroquois), and NJR Steckman Ridge Storage Company, which holds the Company's 50 percent combined interest in Steckman Ridge GP, LLC and Steckman Ridge, LP (collectively, Steckman Ridge). Iroquois and Steckman Ridge comprise the Energy Holdings segment (previously Midstream Assets);

NJR Retail Holdings Corporation (Retail Holdings) has two principal subsidiaries, NJR Home Services Company (NJRHS) and Commercial Realty & Resources Corporation (CR&R). Retail Holdings and NJR Energy Corporation (NJR Energy) are included in Retail and Other operations.

2. 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 (SEC). The September 30, 2011, 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 financial statements and the notes thereto included in NJR's 2011 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, 2012.

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, 2012				September 30, 2011
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJNG		$	67,104	10.7		$	159,328	23.1
NJRES		108,105		41.9		135,147		36.8
Total		$	175,209	52.6		$	294,475	59.9

Page 6

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 $10.4 million and $10.3 million as of March 31, 2012 and September 30, 2011, 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 $7.7 million ($4.6 million, after tax) and $7.7 million ($4.5 million, after tax) as of March 31, 2012 and September 30, 2011, respectively.

Recent Updates to the Accounting Standards Codification (ASC)

Fair Value

In May 2011, the FASB issued an amendment to ASC Topic 820, Fair Value Measurements and Disclosures, clarifying certain guidance to ensure that U.S. generally accepted accounting principles (U.S. GAAP) and International Financial Reporting Standards (IFRS) have the same fair value meaning, measurements and disclosure requirements. The amended guidance became effective for interim and annual periods beginning after December 15, 2011. There was no impact to the Company's financial position, results of operations or cash flows upon adoption.

Presentation of Comprehensive Income

In June 2011, the FASB issued an update to ASC Topic 220, Comprehensive Income, allowing two alternatives for the presentation of comprehensive income, eliminating the option to present the components of comprehensive income (OCI) as a part of the statement of changes in stockholder's equity and requiring that reclassification adjustments from OCI to income be presented on the face of the financial statements. The amended guidance requires that comprehensive income, including the components of net income and OCI, be presented in either one statement or in two separate but consecutive statements. In December 2011, the FASB issued a subsequent amendment indefinitely deferring the provisions requiring reclassification adjustments out of OCI to be presented on the face of the financial statements. The other portions of the original update remain unchanged and became effective for interim and annual periods beginning after December 15, 2011, with early adoption permitted. Effective September 30, 2011, NJR adopted the two-statement approach retrospectively. There was no impact to the Company's financial position, results of operations or cash flows upon adoption.

Balance Sheet Offsetting

In December 2011, the FASB issued an amendment to ASC Topic 210, Balance Sheet, requiring additional disclosures about the nature of an entity's rights of setoff and related master netting arrangements associated with its financial and derivative instruments. The objective of the disclosures is to facilitate comparison between financial statements prepared on the basis of U.S. generally accepted accounting principles (U.S. GAAP) and those prepared on the basis of International Financial Reporting Standards (IFRS). The amended guidance will become effective for interim and annual periods beginning on or after January 1, 2013 and will be applied retrospectively. The Company has determined that the new guidance will not impact its financial position, results of operations or cash flows upon adoption.

3. 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. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing amounts that are probable future expenditures as regulatory liabilities.

Page 7

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets are comprised of the following:

(Thousands)	March 31, 2012		September 30, 2011
Regulatory assets-current
Conservation Incentive Program	$	20,871	$	9,178
Underrecovered gas costs	16,544		—
Derivatives, net	43,505		8,452
Total current	$	80,920	$	17,630
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	61,259	$	75,646
Liability for future expenditures	182,900		182,900
Deferred income taxes	10,879		10,879
Energy Efficiency Program	17,913		11,906
New Jersey Clean Energy Program	13,522		20,144
Postemployment and other benefit costs	120,247		123,827
Other	4,181		8,883
Total noncurrent	$	410,901	$	434,185
Regulatory liability-current
Overrecovered gas costs	$	—	$	4,633
Total current	$	—	$	4,633
Regulatory liabilities-noncurrent
Cost of removal obligation	$	63,133	$	59,752
Other	258		85
Total noncurrent	$	63,391	$	59,837

NJNG's recovery of costs is facilitated through its base rates, Basic Gas Supply Service (BGSS) and other regulatory 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 November 17, 2011, NJNG notified the BPU that it will provide bill credits to NJNG's residential and small commercial customers during December 2011 and January 2012, as a result of the decline in the wholesale prices of natural gas and a change in the methodology used to develop estimates of unaccounted-for gas. On January 25, 2012 and March 9, 2012, NJNG notified the BPU that it would extend bill credits through February 2012 and March 2012, respectively. In total, customers received approximately $90.7 million in credits based on usage during the four-month period.

• On January 18, 2012, the BPU approved an extension of NJNG's Energy Efficiency program (EE) for one year with an additional $18.4 million of investments in customer incentives and financing earning a weighted average cost of capital of 7.1 percent, including a cost of equity of 10.3 percent.

• On January 18, 2012, the BPU issued an Order approving NJNG's 2010 Societal Benefits Clause (SBC) filing, in which NJNG requested approval of its manufactured gas plant remediation expenditures incurred through September 30, 2009, as well as continuation of its existing overall SBC rate. In February 2012, NJNG filed its 2011 SBC filing, which requested approval of its MGP expenditures incurred through September 30, 2011, with no additional rate impact on customers.

• On March 9, 2012, NJNG notified the BPU that it will implement a 3.6 percent decrease to its BGSS rate, effective April 1, 2012, with an annual impact of approximately $19 million.

Page 8

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

• On March 20, 2012, NJNG filed a petition with the BPU seeking to implement a Safety Acceleration and Facility Enhancement (SAFE) program, whereby NJNG would invest up to $204 million over a five-year period to replace portions of NJNG's gas distribution infrastructure. If approved, commencing in 2013, NJNG would file a petition with the BPU annually in June to recover costs over the life of the program, including an overall weighted average cost of capital of 7.76 percent, including a cost of equity of 10.3 percent.

4. DERIVATIVE INSTRUMENTS

The Company and certain of its subsidiaries are subject to commodity price risk due to fluctuations in the market price of natural gas. To manage this risk, the Company and certain of its subsidiaries enter 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. 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 in 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, changes in the fair value of these derivative instruments are recorded as a component of gas purchases or operating revenues, as appropriate for NJRES, in 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. 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 other comprehensive income (OCI). When the foreign exchange contracts are settled, realized gains and (losses) are recognized in gas purchases in 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 potential 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 in 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 in 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.

The Company elects normal purchase/normal sale 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 earnings when the contract settles and the natural gas is delivered.

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Fair Value of Derivatives

The following table reflects the fair value of NJR's derivative assets and liabilities recognized in the Unaudited Condensed Consolidated Balance Sheets as of:

			Fair Value
			March 31, 2012						September 30, 2011
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	127		$	22		$	153		$	8
	Derivatives - noncurrent		93			43			127			6
Fair value of derivatives designated as hedging instruments			$	220		$	65		$	280		$	14
Derivatives not designated as hedging instruments:
NJNG:
Financial commodity contracts	Derivatives - current		$	6,049		$	49,717		$	5,424		$	13,258
	Derivatives - noncurrent		163			—			2			620
NJRES:
Physical forward commodity contracts	Derivatives - current		21,541			11,150			33,240			10,570
	Derivatives - noncurrent		578			604			4,450			781
Financial commodity contracts	Derivatives - current		75,789			31,139			61,521			44,862
	Derivatives - noncurrent		2,499			3,104			1,936			4,934
Fair value of derivatives not designated as hedging instruments			$	106,619		$	95,714		$	106,573		$	75,025
Total fair value of derivatives			$	106,839		$	95,779		$	106,853		$	75,039

At March 31, 2012, the gross notional amount of the foreign currency transactions was approximately $11.5 million, and ineffectiveness in the hedge relationship is immaterial to the financial results of NJR.

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:		2012		2011			2012			2011
NJRES:
Physical commodity contracts	Operating revenues	$	8,745	$	41,306		$	(3,163	)	$	24,837
Physical commodity contracts	Gas purchases	116		(9,448		)	4,391			(5,739		)
Financial commodity contracts	Gas purchases	40,511		496			102,965			(27,775		)
Total unrealized and realized gains (losses)		$	49,372	$	32,354		$	104,193		$	(8,677	)

Not included in the previous table, are (losses) associated with NJNG's financial derivatives that totaled $(15.4) million and $(2.2) million for the three months endedMarch 31, 2012 and 2011, respectively and $(35.3) million and $(4.9) million for the six months endedMarch 31, 2012 and 2011, respectively. These derivatives are part of its risk management activities that relate

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to its natural gas purchasing activities 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 and there is 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 in the Unaudited Condensed Consolidated Statements of Operations. The following table reflect the effect of derivative instruments designated as cash flow hedges on OCI as of:

(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:	2012			2011		2012			2011			2012		2011
Foreign currency contracts	$	(25	)	$	42	$	(23	)	$	(50	)	$	—	$	—

(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:	2012			2011		2012			2011			2012		2011
Foreign currency contracts	$	(75	)	$	161	$	(35	)	$	(59	)	$	—	$	—

(1) The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $105,000 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, 2012		September 30, 2011
NJNG	Futures	14.8		23.7
	Swaps	3.3		(1.8	)
	Options	2.4		1.1
NJRES	Futures	(26.0	)	(13.8	)
	Swaps	(0.7	)	(41.9	)
	Options	—		—
	Physical	24.6		58.3

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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 broker margin accounts for NJNG and NJRES. The balances by company, are as follows:

(Thousands)	Balance Sheet Location	March 31, 2012			September 30, 2011
NJNG	Broker margin - Current assets	$	46,361		$	11,722
NJRES	Broker margin - Current assets	$	20,154		$	10,873
NJRES	Broker margin - Current (liabilities)	$	(29,671	)	$	—

Wholesale Credit Risk

NJNG and NJRES are exposed to credit risk as a result of their wholesale marketing activities. As a result of the inherent volatility in the prices of natural gas commodities and derivatives, 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 the International Swaps and Derivatives Association (ISDA) and the North American Energy Standards Board (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, 2012. Internally-rated exposure applies to counterparties that are not rated by Standard & Poor's (S&P) or Moody's Investors Service, Inc. (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		$	107,085
Noninvestment grade		21,457
Internally rated investment grade		25,580
Internally rated noninvestment grade		7,451
Total		$	161,573

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.

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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, 2012 and September 30, 2011, was $2.6 million and $4.1 million, respectively, for which the Company had not posted any collateral. If all the thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on March 31, 2012 and September 30, 2011, the Company would have been required to post an additional $2.2 million and $1.7 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected in 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.

Liquidation of Clearing Broker

MF Global Inc. (MFGI) and MF Global UK Limited (UKMF), which operated as futures commission merchants and broker/dealer entities of MF Global Holdings Ltd. (collectively with its affiliates, MF Global), were NJRES' clearing brokers through which NJRES held positions in energy futures contracts, options on futures contracts, and swaps cleared on exchanges administered by the Chicago Mercantile Exchange (CME) and the Intercontinental Exchange (ICE). The CME and ICE both require NJRES to maintain adequate margin against NJRES' trading positions, which our former clearing brokers, MFGI and UKMF, were required to hold on our behalf in segregated or secured accounts. MF Global disclosed to the CME that it had a “significant shortfall” in its segregated customer accounts. Shortly thereafter, on October 31, 2011, the Securities Investor Protection Corporation announced that it had initiated the liquidation of MFGI under the Securities Investor Protection Act (SIPA) in the U.S. and the High Court in the U.K. appointed special administrators to conduct the liquidation of UKMF. The SIPA Trustee's latest estimate of the shortfall in commodities customers' segregated account funds is $1.6 billion.

As of the close of business on November 3, 2011, the market value of NJRES' MF Global account was $27.8 million, of which $10.6 million related to CME positions and $17.2 million related to ICE positions. To date, NJRES has received distributions from the SIPA Trustee totaling$7.6 million related to its CME positions. Accordingly, the remaining exposure as of March 31, 2012, is $20.2 million.

NJRES has filed claims in both the MFGI and UKMF liquidation proceedings and intends to vigorously prosecute those claims to recover all of its funds, but it cannot estimate at this time, either how much of those funds will be recovered or when they will be recovered.

5. 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. The estimated fair value of long-term debt, including current maturities is as follows:

(Thousands)	March 31, 2012		September 30, 2011
Carrying value	$	437,567	$	434,372
Fair market value	$	478,010	$	471,022

Effective January 1, 2012, NJR changed its valuation technique from a market approach to an income approach. NJR considers the discounted cash flow method to provide a more consistently reliable fair value. Inputs include U.S. Treasury securities and credit spreads, both of which are observable inputs. Any adjustments to the measurement for duration, as applicable, are not considered to be significant, therefore, NJR classifies its debt within Level 2 of the fair value hierarchy.

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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 contracts, listed equities, and money market funds.

Level 2 Price data, which includes both commodity and basis price data other than Level 1 quotes, 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. These additional adjustments are not considered 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.

NJNG's and NJRES' financial derivatives portfolios consist mainly of futures, options and swaps. NJR primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market, therefore, the primary source for its price inputs is the New York Mercantile (NYMEX) exchange. NJRES also uses Natural Gas Exchange (NGX) for Canadian delivery points and Platts and NYMEX ClearPort for certain over-the-counter physical forward commodity contracts. However, NJRES also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the cost to transport to the final delivery location is not significant to the overall valuation. If required, NJRES' policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or pricing services.

NJR also has available for sale securities and other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When NJR determines fair values, measurements are adjusted, as needed, for credit risk associated with its counterparties, as well as its own credit risk. NJR determines these adjustments by using historical default probabilities that correspond to the applicable Standard and Poor's issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.

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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, 2012:
Assets:
Physical forward commodity contracts		$	—		$	22,119		$	—	$	22,119
Financial derivative contracts - natural gas		47,212			37,288			—		84,500
Financial commodity contracts - foreign exchange		—			220			—		220
Available for sale equity securities - energy industry (1)		10,408			—			—		10,408
Other		3,865			—			—		3,865
Total assets at fair value		$	61,485		$	59,627		$	—	$	121,112
Liabilities:
Physical forward commodity contracts		$	—		$	11,754		$	—	$	11,754
Financial commodity contracts - natural gas		61,351			22,609			—		83,960
Financial commodity contracts - foreign exchange		—			65			—		65
Other		729			—			—		729
Total liabilities at fair value		$	62,080		$	34,428		$	—	$	96,508
As of September 30, 2011:
Assets:
Physical forward commodity contracts		$	—		$	37,690		$	—	$	37,690
Financial derivative contracts - natural gas		25,617			43,266			—		68,883
Financial commodity contracts - foreign exchange		—			280					280
Available for sale equity securities - energy industry(1)		10,348			—			—		10,348
Other		2,820			—			—		2,820
Total assets at fair value		$	38,785		$	81,236		$	—	$	120,021
Liabilities:
Physical forward commodity contracts		$	—		$	11,351		$	—	$	11,351
Financial derivative contracts - natural gas		23,715			39,959			—		63,674
Financial commodity contracts - foreign exchange		—			14			—		14
Other		616			—			—		616
Total liabilities at fair value		$	24,331		$	51,324		$	—	$	75,655

(1) Included in other noncurrent assets in the Unaudited Condensed Consolidated Balance Sheets.

6. INVESTMENTS IN EQUITY INVESTEES

NJR uses the equity method of accounting for its investments in Steckman Ridge and Iroquois. Earnings or losses from equity method investments are included in Equity in earnings of affiliates in the Unaudited Condensed Consolidated Statements of Operations.

NJR's investments in equity investees include the following investments as of:

(Thousands)	March 31, 2012		September 30, 2011
Steckman Ridge	$	134,703	$	135,130
Iroquois	22,346		23,933
Total	$	157,049	$	159,063

As of March 31, 2012, the investment of 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 December 31, 2017.

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NJRES and NJNG have entered into transportation, storage and park and loan agreements with Iroquois and Steckman Ridge. See Note 13. Related Party Transactions for more information on these affiliate transactions.

7. 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)	2012		2011		2012		2011
Net income , as reported	$	54,535	$	63,927	$	111,892	$	88,436
Basic earnings per share
Weighted average shares of common stock outstanding-basic	41,509		41,352		41,472		41,316
Basic earnings per common share	$1.31		$1.55		$2.70		$2.14
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	41,509		41,352		41,472		41,316
Incremental shares (1)	202		201		201		200
Weighted average shares of common stock outstanding-diluted	41,711		41,553		41,673		41,516
Diluted earnings per common share (2)	$1.31		$1.54		$2.68		$2.13

(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 endedMarch 31, 2012 and 2011.

8. DEBT

NJR and NJNG finance working capital requirements and capital expenditures through the issuance of various long-term debt and other financing arrangements, including unsecured credit 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.

A summary of NJR's and NJNG's debt shelf and credit facilities are as follows:

(Thousands)	March 31, 2012			September 30, 2011			Maturity Dates
NJR
Debt shelf facilities (1) (2) (3)	$	175,000		$	175,000		Various (3)
Bank credit facilities(4)	$	325,000		$	325,000		December 2012
Notes payable outstanding at end of period	$	157,300		$	132,850
Weighted average interest rate at end of period	0.53		%	0.54		%
Amount available at end of period	$	155,453		$	157,853
NJNG
Bank credit facility dedicated to EDA Bonds (2) (4)	$	100,000		$	100,000		August 2015
Bank credit facilities (4)	$	200,000		$	200,000		August 2014
Commercial paper outstanding at end of period	$	34,000		$	26,500
Weighted average interest rate at end of period	0.16		%	0.24		%
Amount available at end of period	$	166,000		$	173,500

(1) Uncommitted, long-term debt shelf facilities, which require no commitment fees on the unused amounts.

(2) There were no borrowings outstanding as of March 31, 2012 and September 30, 2011, respectively.

(3) $100 million debt shelf expires May 2013 and $75 million debt shelf expires June 2014.

(4) Committed credit facilities, which require commitment fees on the unused amounts.

Other

NJNG received $6.5 million and $5.9 million in December 2011 and 2010, respectively, in connection with the sale-leaseback of its natural gas meters. This sale-leaseback program is expected to continue on an annual basis.

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9. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans (OPEB)

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)	2012			2011			2012			2011			2012			2011			2012			2011
Service cost	$	1,344		$	1,194		$	2,688		$	2,388		$	896		$	836		$	1,792		$	1,672
Interest cost	2,206			2,095			4,412			4,189			1,283			1,212			2,566			2,423
Expected return on plan assets	(3,171		)	(2,873		)	(6,342		)	(5,745		)	(686		)	(618		)	(1,372		)	(1,236		)
Recognized actuarial loss	1,254			987			2,508			1,973			724			653			1,448			1,306
Prior service cost amortization	11			12			22			24			6			19			12			38
Recognized net initial obligation	—			—			—			—			89			89			178			178
Net periodic benefit cost	$	1,644		$	1,415		$	3,288		$	2,829		$	2,312		$	2,191		$	4,624		$	4,381

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 in December 2011.

10. 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 endedMarch 31, 2012 and 2011, 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 endedMarch 31, 2012 and 2011, are 19.5 percent and 32.4 percent, respectively. The decrease in the rate is due primarily to federal investment tax credits (ITC) of $24.9 million and $6.1 million, generated by NJRCEV's solar investments placed into service in the six months endedMarch 31, 2012 and 2011, respectively, and solar investments forecasted to be completed before the end of the fiscal year.

To calculate the estimated annual effective tax rate, NJR considers projects that are probable of being completed and available for use 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 and interconnection. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

11. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through November 2024, for the supply, storage and delivery of natural gas. These contracts include current annual fixed charges of approximately $96 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 five years. Demand charges are based on established rates as 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.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Commitments as of March 31, 2012, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2012		2013		2014		2015		2016		Thereafter
NJRES:
Natural gas purchases	$	264,023	$	181,858	$	6,555	$	—	$	—	$	—
Storage demand fees	21,136		31,625		18,838		12,286		7,236		12,353
Pipeline demand fees	32,704		41,830		22,169		10,891		9,077		17,427
Sub-total NJRES	$	317,863	$	255,313	$	47,562	$	23,177	$	16,313	$	29,780
NJNG:
Natural gas purchases	$	19,877	$	1,096	$	—	$	—	$	—	$	—
Storage demand fees	15,666		30,070		25,123		15,888		11,088		33,245
Pipeline demand fees	27,164		76,776		73,150		35,213		31,578		201,838
Sub-total NJNG	$	62,707	$	107,942	$	98,273	$	51,101	$	42,666	$	235,083
Total (1)	$	380,570	$	363,255	$	145,835	$	74,278	$	58,979	$	264,863

(1) Does not include amounts related to intercompany asset management agreements between NJRES and NJNG.

NJNG's capital expenditures are estimated at $121.2 million and $70 million in fiscal 2012 and 2013, respectively, and consist primarily of its construction program to support customer growth, maintenance of its distribution system and replacement needed under pipeline safety regulations. Approximately $49.1 million has been committed or spent on capital expenditures, including accruals, during the six months endedMarch 31, 2012. The expected expenditures in fiscal 2012 include an estimate of $49.9 million related to AIP II. NJNG has committed or spent $14.9 million related to AIP II programs during the six months endedMarch 31, 2012.

The Company has entered into various agreements to install solar equipment involving both residential and commercial projects. Total solar-related capital expenditures during the six months endedMarch 31, 2012 were $61.8 million. The Company currently estimates solar-related capital expenditures of $82.6 million during fiscal 2012, of which $79.8 million has been committed or spent. Solar-related capital expenditures in fiscal 2013 are estimated to be $90 million. These investments are subject to a variety of factors, such as the identification of appropriate projects, the timing of construction schedules, the permitting and regulatory process and delays related to electric grid interconnection, which may affect our ability to commence operations at these projects on a timely basis or, at all.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of five manufactured gas plant (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 New Jersey Department of Environmental Protection (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. On January 18, 2012, the BPU approved the recovery of the remediation expenditures incurred through September 30, 2009, which maintained the expected annual recovery at approximately $20 million. As of March 31, 2012, $61.3 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.

In September 2011, NJNG updated 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 $161.5 million to $278.5 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. However, NJNG expects actual costs to differ from these estimates. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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, NJNG has recorded an MGP remediation liability and a corresponding regulatory asset of $182.9 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.

12. 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 consist of capital investments in renewable energy projects; the Energy Holdings segment (previously Midstream Assets) consists of NJR's investments in natural gas transportation and storage facilities; the Retail and Other operations consist of appliance and installation services, commercial real estate development, renewable energy and other investments and general corporate activities.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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)	2012			2011			2012			2011
Operating revenues
Natural Gas Distribution
External customers	$	226,023		$	433,248		$	417,397		$	723,924
Intercompany	—			—			—			—
Energy Services
External customers	378,356			535,987			820,162			950,418
Intercompany	2,654			37,088			2,848			53,431
Clean Energy Ventures
External customers	527			—			907			—
Segment subtotal	607,560			1,006,323			1,241,314			1,727,773
Retail and Other
External customers	8,014			7,751			16,866			15,796
Intercompany	263			75			442			156
Eliminations	(2,916		)	(37,162		)	(3,290		)	(53,586		)
Total	$	612,921		$	976,987		$	1,255,332		$	1,690,139
Depreciation and amortization
Natural Gas Distribution	$	8,749		$	8,235		$	17,381		$	16,458
Energy Services	16			15			32			31
Clean Energy Ventures	1,511			28			2,321			28
Energy Holdings	2			2			3			3
Segment subtotal	10,278			8,280			19,737			16,520
Retail and Other	161			197			302			411
Total	$	10,439		$	8,477		$	20,039		$	16,931
Interest income (1)
Natural Gas Distribution	$	214		$	280		$	460		$	540
Energy Services	(5		)	3			26			8
Energy Holdings	285			224			533			452
Segment subtotal	494			507			1,019			1,000
Retail and Other	1			1			1			1
Eliminations	(268		)	(217		)	(503		)	(438		)
Total	$	227		$	291		$	517		$	563

(1) Included in other income in the Unaudited Condensed Consolidated Statements of Operations.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2012			2011			2012			2011
Interest expense, net of capitalized interest
Natural Gas Distribution	$	3,713		$	3,808		$	7,450		$	7,824
Energy Services	245			323			515			599
Clean Energy Ventures	198			3			340			7
Energy Holdings	683			817			1,397			1,625
Segment subtotal	4,839			4,951			9,702			10,055
Retail and Other	588			127			730			286
Total	$	5,427		$	5,078		$	10,432		$	10,341
Income tax provision (benefit)
Natural Gas Distribution	$	27,016		$	26,278		$	42,612		$	40,879
Energy Services	(2,105		)	7,525			9,403			6,683
Clean Energy Ventures	(14,826		)	(6,071		)	(26,997		)	(6,710		)
Energy Holdings	1,393			1,487			2,624			2,670
Segment subtotal	11,478			29,219			27,642			43,522
Retail and Other	(312		)	(588		)	(371		)	(1,044		)
Eliminations	(72		)	(19		)	(140		)	(13		)
Total	$	11,094		$	28,612		$	27,131		$	42,465
Equity in earnings of affiliates
Energy Holdings	$	3,967		$	4,360		$	7,582		$	7,980
Segment subtotal	3,967			4,360			7,582			7,980
Eliminations	(949		)	(750		)	(1,910		)	(1,453		)
Total	$	3,018		$	3,610		$	5,672		$	6,527
Net financial earnings (loss)
Natural Gas Distribution	$	44,936		$	44,040		$	70,910		$	68,396
Energy Services	15,871			16,001			23,486			19,168
Clean Energy Ventures	11,862			5,171			21,959			5,225
Energy Holdings	2,021			2,145			3,804			3,858
Segment subtotal	74,690			67,357			120,159			96,647
Retail and Other	(543		)	(328		)	(689		)	(488		)
Eliminations	(21		)	—			(36		)	—
Total	$	74,126		$	67,029		$	119,434		$	96,159
Capital expenditures
Natural Gas Distribution	$	27,427		$	18,988		$	49,145		$	47,186
Clean Energy Ventures	14,175			9,038			61,786			9,937
Segment subtotal	41,602			28,026			110,931			57,123
Retail and Other	370			1,717			459			1,963
Total	$	41,972		$	29,743		$	111,390		$	59,086

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The chief operating decision maker of the Company is the Chief Executive Officer (CEO). The CEO uses net financial earnings as a measure of profit or loss in measuring the results of the Company's segments and operations. A reconciliation of consolidated net financial earnings to consolidated net income is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2012		2011		2012			2011
Consolidated net financial earnings	$	74,126	$	67,029	$	119,434		$	96,159
Less:
Unrealized loss (gain) from derivative instruments and related transactions, net of taxes (1)	7,664		2,306		(9,708		)	36,710
Effects of economic hedging related to natural gas inventory, net of taxes	11,927		796		17,250			(28,987		)
Consolidated net income	$	54,535	$	63,927	$	111,892		$	88,436

(1) Excludes unrealized losses related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $79,000 and $30,000, for the three months ended March 31, 2012 and March 31, 2011, respectively, and $197,000, and $32,000 for the six months endedMarch 31, 2012 and 2011, 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.

Net financial earnings 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 net financial earnings, current period unrealized gains and losses on the derivatives are excluded from net financial earnings as a reconciling item. Additionally, realized derivative gains and losses are also included in current period net income. However, net financial earnings include 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.

The Company's assets for the various business segments and business operations are detailed below:

(Thousands)	March 31, 2012			September 30, 2011
Assets at end of period:
Natural Gas Distribution	$	1,951,497		$	1,942,691
Energy Services	346,995			400,882
Clean Energy Ventures	166,478			80,234
Energy Holdings	157,987			159,940
Segment subtotal	2,622,957			2,583,747
Retail and Other	66,742			87,066
Intercompany assets (1)	(19,960		)	(21,369		)
Total	$	2,669,739		$	2,649,444

(1) Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.

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13. 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 Gas Transmission. As of March 31, 2012, NJRES has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which expire by October 2012. Additionally, NJRES has transportation capacity with Iroquois Gas Transmission that expires by March 2019. Demand fees associated with both Steckman Ridge and Iroquois Gas Transmission were $2.1 million and $4.1 million during the three and six months endedMarch 31, 2012, respectively. As of March 31, 2012, NJRES had fees payable of $238,000 and $392,000 to Steckman Ridge and Iroquois Gas Transmission, respectively.

In January 2010, NJNG entered into a ten-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. These fees are recoverable through NJNG's BGSS mechanism. Additionally, NJNG has transportation capacity with Iroquois Gas Transmission that expires by January 2019. Demand fees associated with both Steckman Ridge and Iroquois Gas Transmission were $1.9 million and $4 million during the three and six months endedMarch 31, 2012, respectively. As of March 31, 2012, NJNG had fees payable (receivable) to Steckman Ridge and Iroquois Gas Transmission in the amount of $775,000 and $(146,000), respectively.

In December 2009, NJNG and NJRES entered into an asset management agreement that began in January 2010 and ends in March 2013. 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 another asset management agreement that began in September 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.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS                                                                                                                                                                                   

Management's Overview

New Jersey Resources Corporation (NJR or the Company) is an energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in states from the Gulf Coast and Mid-Continent regions to the Appalachian and Northeast regions, the West Coast and Canada through two of its subsidiaries, New Jersey Natural Gas (NJNG) and NJR Energy Services (NJRES).

Comprising the Natural Gas Distribution segment, NJNG is a natural gas utility that provides regulated retail natural gas service in central and northern New Jersey and also participates in the off-system sales and capacity release markets. NJNG is regulated by the New Jersey Board of Public Utilities (BPU).

NJRES comprises the Energy Services segment. NJRES maintains and transacts around a portfolio of physical assets consisting of natural gas storage and transportation contracts. In addition, NJRES provides wholesale energy services to non-affiliated utility and energy companies.

NJR Clean Energy Ventures (NJRCEV) invests in renewable energy projects consisting primarily of residential and commercial rooftop and ground mount solar systems. NJRCEV comprises the Clean Energy Ventures segment.

The Energy Holdings segment (previously Midstream Assets) includes NJR Energy Holdings Corporation (NJREH), which primarily invests in energy-related ventures through its subsidiaries, NJNR Pipeline Company (Pipeline), which holds the Company's 5.53 percent ownership interest in Iroquois Gas Transmission L.P. (Iroquois) and NJR Steckman Ridge Storage Company, which holds the Company's 50 percent combined interest in Steckman Ridge GP, LLC and Steckman Ridge, LP (collectively, Steckman Ridge), a natural gas storage facility in Pennsylvania.

The retail and other business operations (Retail and Other) includes: NJR Home Services (NJRHS), which provides service, sales and installation of appliances, as well as solar installation projects; NJR Energy Corporation (NJR Energy), a company that invests in energy-related ventures; NJR Plumbing Services (NJRPS), which provides plumbing repair and installation services; Commercial Realty and Resources (CR&R), which holds and develops commercial real estate; and NJR Service Corporation (NJR Service), which provides support services to the various NJR businesses.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Assets by business segment and operations are as follows:

($ in thousands)	March 31, 2012					September 30, 2011
Assets
Natural Gas Distribution	$	1,951,497		74	%	$	1,942,691		74	%
Energy Services	346,995			13		400,882			15
Clean Energy Ventures	166,478			6		80,234			3
Energy Holdings	157,987			6		159,940			6
Retail and Other	66,742			2		87,066			3
Eliminations (1)	(19,960		)	(1	)	(21,369		)	(1	)
Total	$	2,669,739		100	%	$	2,649,444		100	%

(1) Consists of transactions between subsidiaries that are eliminated in consolidation.

An increase in capital expenditures associated with solar investments at Clean Energy Ventures was the primary contributor to the increase in assets, partially offset by a decrease at Energy Services in both accounts receivable and gas in storage during the six months endedMarch 31, 2012.

Net income (loss) by business segment and operations are as follows:

	Three Months Ended										Six Months Ended
	March 31,										March 31,
($ in Thousands)	2012					2011					2012					2011
Net Income (Loss)
Natural Gas Distribution	$	44,936		82	%	$	44,040		69	%	$	70,910		63	%	$	68,396		77	%
Energy Services	(3,642		)	(7	)	12,929			20		16,141			14		11,477			13
Clean Energy Ventures	11,862			22		5,171			8		21,959			20		5,225			6
Energy Holdings	2,021			4		2,145			3		3,804			3		3,858			4
Retail and Other	(543		)	(1	)	(328		)	—		(689		)	—		(488		)	—
Eliminations (1)	(99		)	—		(30		)	—		(233		)	—		(32		)	—
Total	$	54,535		100	%	$	63,927		100	%	$	111,892		100	%	$	88,436		100	%

(1) Consists of transactions between subsidiaries that are eliminated in consolidation.

Included in net income are unrealized (losses) in the Energy Services segment of $(7.6) million and $(2.3) million, after taxes, for the three months endedMarch 31, 2012 and 2011, respectively and realized (losses) of $(11.9) million and $(796,000), after taxes, for the three months endedMarch 31, 2012 and 2011, respectively. Also included in net income are unrealized gains (losses) in the Energy Services segment of $9.9 million and $(36.7) million, after taxes, for the six months endedMarch 31, 2012 and 2011, respectively and realized (losses) gains of $(17.3) million and $29 million, after taxes, for the six months endedMarch 31, 2012 and 2011, respectively, which are related to financial derivative instruments that have settled and are designed to economically hedge natural gas still in inventory.

NJRES accounts for its physical commodity contracts and its financial derivative instruments used to economically hedge the forecasted purchase, sale and transportation of natural gas at fair value on the Unaudited Condensed Consolidated Balance Sheets. Changes in the fair value of these contracts are included in earnings as a component of operating revenue and gas purchases, as appropriate, in the Unaudited Condensed Consolidated Statements of Operations. All physical commodity contracts at NJNG are accounted for under accrual accounting. Accordingly, gains and losses are recognized in earnings when the contract settles and the natural gas is delivered.

Unrealized gains and losses at NJRES are the result of changes in the fair value of derivative instruments. The change in fair value of these derivative instruments at NJRES over periods of time can result in substantial volatility in reported net income. When a financial instrument settles, the result is the realization of these gains or losses. NJRES utilizes certain financial instruments to economically hedge natural gas inventory placed into storage that will be sold at a later date, all of which were contemplated as part of an entire forecasted transaction. Volatility in earnings also occurs as a result of timing differences between the settlement of the financial derivative and the sale of the corresponding natural gas that was hedged with the financial instrument. When the financial instrument settles and the natural gas is placed in inventory, the realized gains and losses associated with the financial instrument are recognized in earnings. However, the gains and losses associated with the economically hedged natural gas are not recognized in earnings until the natural gas inventory is sold.

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New Jersey Resources Corporation

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Management of the Company uses a non-Generally Accepted Accounting Principles (GAAP) measure (non-GAAP financial measure), noted as “net financial earnings,” when evaluating the operating results of NJRES. Net financial earnings is a measure of the earnings based on eliminating timing differences surrounding the recognition of certain gains or losses as described above, to effectively match the earnings effects of the economic hedges with the physical sale of gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments.

Net financial earnings by business segment and operations are as follows:

	Three Months Ended										Six Months Ended
	March 31,										March 31,
($ in Thousands)	2012					2011					2012					2011
Net Financial Earnings (Loss)
Natural Gas Distribution	$	44,936		61	%	$	44,040		66	%	$	70,910		59	%	$	68,396		71	%
Energy Services	15,871			21		16,001			24		23,486			20		19,168			20
Clean Energy Ventures	11,862			16		5,171			8		21,959			18		5,225			5
Energy Holdings	2,021			3		2,145			3		3,804			3		3,858			4
Retail and Other	(543		)	(1	)	(328		)	(1	)	(689		)	—		(488		)	—
Eliminations (1)	(21		)	—		—			—		(36		)	—		—			—
Total	$	74,126		100	%	$	67,029		100	%	$	119,434		100	%	$	96,159		100	%

(1) Consists of transactions between subsidiaries that are eliminated in consolidation.

Natural Gas Distribution Segment

Our natural gas distribution segment has approximately 499,500 residential and commercial customers in its service territory and participates in the off-system sales and capacity release markets. NJNG's operations are managed with the goal of providing safe and reliable service, growing profitably and promoting clean energy programs. The business is subject to various risks, such as those associated with adverse economic conditions that can negatively impact customer growth, operating and financing costs, fluctuations in commodity prices, which can impact customer usage, customer conservation efforts, certain regulatory actions, and environmental remediation. It is often difficult to predict the impact of trends associated with these risks. NJNG employs certain strategies, which are described further below, to manage the challenges it faces, including pursuing customer conversions from other fuel sources and monitoring new construction markets through contact with developers, utilizing incentive programs through BPU-approved mechanisms to reduce gas costs, pursuing rate and other regulatory strategies designed to stabilize and decouple margin, and working actively with consultants and the New Jersey Department of Environmental Protection (NJDEP) to manage expectations related to its obligations associated with NJNG's manufactured gas plant (MGP) sites.

Conservation Incentive Program (CIP)

The CIP allows NJNG to recover utility gross margin variations related to both weather and customer usage subject to certain conditions. Effective October 1, 2010, the BPU approved recovery of $12.1 million annually for accrued and estimated CIP amounts through September 30, 2010. In June 2011, NJNG filed for a change in the CIP rates, effective October 1, 2011. The proposed CIP rates result in a decrease to residential heat customers and a minor increase to all other customers. See the Results of Operations section of Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations for more information on the impact to utility gross margin.

As of March 31, 2012, NJNG has $20.9 million in regulatory assets in the Unaudited Condensed Consolidated Balance Sheets related to accrued CIP to be recovered in future periods from customers.

Customer growth

In conducting NJNG's business, management focuses on factors it believes may have significant influence on its future financial results. NJNG's policy is to work with all stakeholders, including customers, regulators and policymakers, to achieve favorable results. These factors include the rate of NJNG's customer growth in its service territory, which can be influenced by political and regulatory policies, the delivered cost of natural gas compared with competing fuels, interest rates and general economic conditions.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

During the six months endedMarch 31, 2012, NJNG added 3,492 new customers, or an increase of 13.7 percent compared with the six months endedMarch 31, 2011, and converted 261 existing customers to natural gas heat and other services. This customer growth is expected by NJNG to increase annual utility gross margin by approximately $1.9 million. NJNG currently expects to add approximately 12,000 to 14,000 new customers during the two-year period of fiscal 2012 and 2013. We believe that this growth rate would increase utility gross margin under NJNG's base rates by approximately $3.5 million annually, as calculated under NJNG's CIP tariff. See the Natural Gas Distribution Results of Operations section of Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations for a definition of utility gross margin.

Commodity prices

Our natural gas distribution segment is affected by the price of natural gas, which can have a significant impact on our cash flows, short-term financing costs, gas costs recovered from customers, NJNG's ability to collect accounts receivable, which impacts our bad debt expense, and our ability to maintain a competitive advantage over other fuel sources. Natural gas commodity prices may experience high volatility as indicated by New York Mercantile Exchange (NYMEX) settlement prices, which ranged from $2.45 per MMBtu (Million Metric British thermal unit) to $3.76 per MMBtu and from $3.29 per MMBtu to $4.32 per MMBtu during the six months endedMarch 31, 2012 and 2011, respectively. As of March 31, 2012, forward natural gas prices for the next twelve months on the NYMEX, which serve as a market indicator, averaged $2.80 per MMBtu, 10.8 percent lower than the average settlement price of $3.14 per MMBtu during the six months endedMarch 31, 2012.

NJNG occasionally adjusts its periodic Basic Gas Supply Service (BGSS) rates for its residential and small commercial customers to reflect changes in the cost of natural gas and can extend credits or refunds to its customers when the commodity cost is trending lower than the current BGSS rate. Accordingly, during the three and six-month periods ended March 31, 2012, NJNG issued credits of $66.4 million and $90.7 million, respectively, to residential and small commercial customers. In addition, on March 9, 2012, NJNG notified the BPU that it will implement a 3.6 percent decrease to its periodic BGSS rate, effective April 1, 2012. BGSS rates for its large commercial customers are changed monthly based on NYMEX prices.

A more detailed discussion of the impacts of the price of natural gas to operating revenues, gas purchases and cash flows can be found in the Results of Operations and Cash Flow sections of Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Incentive programs

NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of utility gross margin-sharing programs that include Off-System Sales, Capacity Release, Storage Incentive and Financial Risk Management (FRM) programs. Effective August 18, 2011, the BPU approved an extension of NJNG's BGSS incentive programs for four years through October 31, 2015, maintaining the existing margin-sharing percentages. This agreement also permits the Company to annually propose a process to evaluate and discuss alternative incentive programs, should performance of the existing incentives or market conditions warrant re-evaluation.

Utility gross margin from incentive programs was $3.2 million and $3.4 million during the three months endedMarch 31, 2012 and 2011, respectively, and $6.1 million and $6.2 million during the six months endedMarch 31, 2012 and 2011, respectively. A more detailed discussion of the impacts to margin can be found in the Results of Operations sectionof Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Environmental remediation

NJNG reviews the costs associated with its MGP annually, at the end of each fiscal year, and adjusts its liability and corresponding regulatory asset as necessary to reflect its expected obligation. As of March 31, 2012, NJNG has recognized a regulatory asset and an obligation of $182.9 million, a decrease of $18.7 million, or 9.3 percent, compared with the prior year. The decrease was due primarily to fiscal 2011 remediation expenditures that reduced the obligation along with the annual reassessment of the MGP remediation and related costs, which resulted in a decrease in three out of the five MGP sites.

NJNG is currently authorized to recover remediation costs of approximately $20 million annually. If there are changes in the regulatory position on the recovery of these costs as determined by the BPU, such costs would be charged to income in the period of such determination.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Infrastructure projects

NJNG has significant annual capital expenditures associated with the management of its natural gas distribution and transmission system and its associated pipeline integrity.

During fiscal 2011, the BPU approved an extension to NJNG's Accelerated Infrastructure Program (AIP), allowing for additional capital investments of $60.2 million (AIP II) to be made through October 31, 2012, bringing the total approved investment, since the program commenced in fiscal 2009, to $131 million. NJNG defers the costs associated with the AIP projects, including NJNG's weighted cost of capital, and upon regulatory approval recovers these investments through its base rates.

In June 2011, NJNG filed for AIP base rate cost recovery, requesting an increase of $4.7 million to $8.9 million annually, related to AIP infrastructure investments installed in NJNG's distribution and transmission systems. The base rate change was provisionally approved, effective on October 1, 2011. The rate changes included a weighted average cost of capital of 7.12 percent, including a cost of equity of 10.3 percent, for AIP II. The existing weighted average cost of capital of 7.76 percent, including a cost of equity of 10.3 percent, for the initial AIP projects remained the same. An additional filing will be submitted in October 2012, requesting rate changes to be effective in January 1, 2013.

NJNG has estimated capital expenditures for fiscal 2012 of $121.2 million, of which $49.9 million is related to AIP II. During the six months endedMarch 31, 2012, NJNG has committed or spent $49.1 million, of which $14.9 million is related to AIP II.

On March 20, 2012, NJNG filed a petition with the BPU seeking to implement a Safety Acceleration and Facility Enhancement (SAFE) program, whereby NJNG would invest up to $204 million over a five-year period to replace portions of NJNG's gas distribution infrastructure. If approved, commencing in 2013, NJNG would file a petition with the BPU annually in June to recover costs over the life of the program, including an overall weighted average cost of capital of 7.76 percent, including a cost of equity of 10.3 percent.

Other

NJNG administers BPU approved EE programs, which facilitate home energy audits and provide financing alternatives including rebates and other incentives designed to encourage the installation of high efficiency heating and cooling equipment. Depending on the specific initiative, NJNG recovers costs associated with the programs over a four to ten-year period. On January 18, 2012, the BPU approved the extension of the program through December 31, 2012, with an additional $18.4 million of investments in customer incentives and financing earning a weighted average return of 7.1 percent, including a cost of equity of 10.3 percent. As of March 31, 2012, the BPU has approved total EE expenditures of $44.3 million, of which NJNG has spent $24.7 million.

On June 16, 2011, NJNG submitted a filing with the BPU seeking authority to invest up to $15 million to build compressed natural gas vehicle refueling stations in Monmouth, Ocean and Morris counties. NJNG would submit a cost recovery filing to the BPU in October 2012, requesting a base rate change to be effective in early 2013, including an overall weighted average cost of capital of 7.76 percent, including a cost of equity of 10.3 percent. Proceeds from the delivery of the associated natural gas, along with any available federal and state incentives, are proposed to be credited back to customers to help offset the cost of this investment.

Due to the capital-intensive nature of NJNG's operations and the seasonal nature of its working capital requirements, significant changes in interest rates can also impact NJNG's results. A more detailed discussion can be found in the Liquidity and Capital Resources and Cash Flow sections of Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Page 27

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Energy Services Segment

NJRES provides unregulated wholesale energy services and engages in the business of optimizing natural gas storage and transportation assets. The rights to these assets are contractually acquired in anticipation of delivering natural gas or performing asset management activities for customers or in conjunction with identifying arbitrage opportunities that exist in the marketplace. These arbitrage opportunities occur as a result of price differences between market locations and/or time horizons. These activities are conducted in the areas in which we have expertise and include states from the Gulf Coast and Mid-Continent regions to the Appalachian and Northeast regions, the West Coast and Canada. NJRES' optimization activities are impacted by changes in pricing between geographic locations and/or time periods. Margins are affected by volatility in natural gas markets and as a result NJRES' financial performance can significantly differ during periods of low or high volatility.

More specifically, NJRES activities consist of the following elements, which provide for growth, while focusing on maintaining a low-risk operating and counterparty credit profile:

• Identifying and benefiting from variations in pricing of natural gas transportation and storage assets due to location or timing differences of natural gas prices to generate gross margin;

• Providing natural gas portfolio management services to nonaffiliated utilities, natural gas producers and electric generation facilities;

• Leveraging transactions for the delivery of natural gas to customers by aggregating the natural gas commodity costs and transportation costs in order to minimize the total cost required to provide and deliver natural gas to NJRES' customers by identifying the lowest cost alternative with the natural gas supply, transportation availability and markets to which NJRES is able to access through its business footprint and contractual asset portfolio; and

• Managing economic hedging programs that are designed to mitigate adverse market price fluctuations in natural gas transportation and storage commitments.

NJRES focuses on creating value from natural gas assets, which are typically amassed through contractual rights to natural gas transportation and storage capacity. NJRES has developed a portfolio of natural gas storage and transportation capacity in states in the Northeast, Gulf Coast, Mid-Continent, Appalachian, and West Coast regions of the United States and Canada. These assets become more valuable when prices change between these areas and across time periods. On a forward basis, NJRES may lock in these price differentials through the use of financial instruments. In addition, NJRES seeks to optimize these assets on a daily basis as market conditions change by evaluating all the natural gas supplies and transportation to which it has access. When market conditions allow, NJRES is able to capture geographic pricing differences across these various regions as delivered natural gas prices change. NJRES focuses on earning a margin on a single original transaction and then utilizing that transaction, and the changes in prices across the regions or across time periods, as the basis to further improve the initial result. This strategy is in large part dependent on volatility in natural gas markets, and is more challenging to execute in a period of economic downturn and resulting lower industrial gas consumption.

NJRES transacts with a variety of counterparties including local distribution companies, industrial companies, electric generators, retail aggregators, natural gas producers and other wholesale marketing companies. The physical sales commitments to these counterparties allows NJRES to leverage its transportation and storage capacity. These physical sale commitments are managed in an aggregate fashion, and allows NJRES the ability to extract more value from its portfolio of natural gas storage and pipeline transportation capacity. NJRES' portfolio management customers include nonaffiliated utilities and electric generation plants. Services provided by NJRES include optimization of underutilized natural gas assets and basic gas supply functions.

Beginning in fiscal 2010, there has been a significant expansion of natural gas resources in the Northeast region as a result of drilling in the Marcellus Shale, which caused a general decrease in volatility in natural gas pricing in the Northeast. This has generally reduced the value of transportation and storage capacity in the northeast, a core market for NJRES. This downturn in volatility and capacity values could have a lasting effect on the earnings of NJRES. NJRES has since looked into opportunities to provide asset management services to exploration and production companies working on the development of these natural gas resources.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

In conducting its business, NJRES mitigates risk by following formal risk management guidelines, including transaction limits, approval processes, segregation of duties, and formal contract and credit review and approval procedures. NJRES continuously monitors and seeks to reduce the risk associated with its credit exposures with its various counterparties. The Risk Management Committee (RMC) of NJR oversees compliance with these established guidelines.

Clean Energy Ventures Segment

NJRCEV actively pursues opportunities in the solar renewable energy markets and has entered into various agreements to install solar equipment involving both residential and commercial projects. Projects that are completed and placed in service qualify for a 30 percent federal investment tax credit (ITC) and once the projects commence operations, for each Megawatt hour (Mwh) of electricity produced, a Solar Renewable Energy Certificate (SREC) is created. NJRCEV currently estimates capital expenditures of approximately $82.6 million in fiscal 2012, of which $61.8 million was associated with projects placed in service during the six months endedMarch 31, 2012. These investments are subject to a variety of factors, including logistics associated with timing of construction schedules, the permitting and regulatory process, and any delays related to electric grid interconnection, which may affect our ability to commence operations at these projects on a timely basis or, at all. Projects not placed in service prior to a period end, would result in a failure to qualify for ITCs and SRECs and could have a material adverse impact on earnings and cash flow. In addition, since the primary contributors toward the value of qualifying renewable energy projects are the ITC and SRECs, changes in the federal statutes related to the ITC or in the markets surrounding SRECs, which can be traded or sold to load serving entities that need to comply with state renewable energy standards, could also significantly affect earnings and cash flow.

Energy Holdings Segment

NJR's subsidiary, NJR Energy Holdings Corporation, invests in natural gas “midstream” assets, such as natural gas transportation and storage facilities. NJR believes that acquiring, owning and developing these midstream assets, which operate under a tariff structure that has either regulated or market-based rates, can provide a growth opportunity for the Company. To that end, NJR has ownership interests in Iroquois, a natural gas pipeline operating with regulated rates, and Steckman Ridge, a storage facility that operates under market-based rates, and is considering other potential opportunities that meet its investment and development criteria.

As of March 31, 2012, NJR's investments in Steckman Ridge and Iroquois, including capitalized costs and equity in earnings, net of cash distributions received, were $134.7 million and $22.3 million, respectively.

Retail and Other Operations

The financial results of Retail and Other have consisted primarily of the operating results of NJRHS, CR&R, and NJR Energy. NJRHS provides service, sales and installation of appliances to approximately 131,800 customers and has been focused on growing its installation business and expanding its service contract customer base. CR&R seeks additional opportunities to enhance the value of its undeveloped land and building. NJR Energy invests in other energy-related ventures through its operating subsidiaries. Retail and Other operations also include organizational expenses incurred at NJR.

Critical Accounting Policies

A summary of NJR's critical accounting policies is included in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations of its Annual Report on Form 10-K for the period ended September 30, 2011. NJR's critical accounting policies have not changed from those reported in the 2011 Annual Report on Form 10-K.

Recently Issued Accounting Standards

Refer to Note 2. Summary of Significant Accounting Policies for discussion of recently issued accounting standards.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Results of Operations

Consolidated

A summary of the company's consolidated results is as follows:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
($ in Thousands)	2012		2011		% change		2012		2011		% change
Operating revenues	$	612,921	$	976,987	(37.3	)%	$	1,255,332	$	1,690,139	(25.7	)%
Gas purchases	$	460,356	$	783,619	(41.3	)%	$	952,403	$	1,373,315	(30.6	)%
Net income	$	54,535	$	63,927	(14.7	)%	$	111,892	$	88,436	26.5	%

The primary drivers of the changes noted above, which are described in more detail in the individual segment discussions, are as follows:

Operating revenues and gas purchases decreased during the three and six months endedMarch 31, 2012, compared with the three and six months endedMarch 31, 2011, due primarily to:

• Bill credits issued to NJNG customers during the three and six months endedMarch 31, 2012, that did not occur during the comparable periods in fiscal 2011, as well as decreases in firm sales due to lower therm usage and off-system sales; partially offset by

• lower average commodity prices at NJRES, which correlate to the lower price levels on the NYMEX.

Net income decreased 14.7 percent during the three months endedMarch 31, 2012, to $54.5 million from $63.9 million for the three months endedMarch 31, 2011. Earnings for the three months endedMarch 31, 2012, were $1.31 per basic share and $1.31 per diluted share, compared with $1.55 per basic share and $1.54 per diluted share for the three months endedMarch 31, 2011. Changes in net income were primarily driven by an increase in unrealized and realized losses at NJRES.

Net income increased 26.5 percent during the six months endedMarch 31, 2012, to $111.9 million, compared with $88.4 million for the six months endedMarch 31, 2011. Earnings for the six months endedMarch 31, 2012, were $2.70 per basic share and $2.68 per diluted share, compared with $2.14 per basic share and $2.13 per diluted share for the six months endedMarch 31, 2011. Changes in net income were primarily driven by:

• an increase at Clean Energy Ventures associated with solar projects that were completed and placed into service during the three and six months endedMarch 31, 2012; and

• an increase at NJRES due primarily to higher revenue from fee based services and transportation arbitrage opportunities as compared to the prior year; and

• improved earnings at NJNG during the current fiscal period due primarily to customer growth.

Natural Gas Distribution Segment

NJNG's business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG receives most of its gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the year.

Page 30

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Operating Results

NJNG's financial results are as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2012		2011		2012		2011
Utility gross margin
Operating revenues	$	226,023	$	433,248	$	417,397	$	723,924
Less:
Gas purchases	81,667		272,948		168,154		450,599
Energy and other taxes	14,353		27,296		26,236		45,778
Regulatory rider expense	18,443		24,304		30,986		41,002
Total utility gross margin	111,560		108,700		192,021		186,545
Operation and maintenance expense	26,246		26,069		52,186		51,943
Depreciation and amortization	8,749		8,235		17,381		16,458
Other taxes not reflected in utility gross margin	1,235		1,064		2,141		2,143
Operating income	75,330		73,332		120,313		116,001
Other income	335		794		659		1,098
Interest expense, net of capitalized interest	3,713		3,808		7,450		7,824
Income tax provision	27,016		26,278		42,612		40,879
Net income	$	44,936	$	44,040	$	70,910	$	68,396

Utility Gross Margin

NJNG's utility gross margin is a non-GAAP financial measure defined as natural gas revenues less natural gas purchases, sales tax, a Transitional Energy Facilities Assessment (TEFA) and regulatory rider expenses, and may not be comparable to the definition of gross margin used by others in the natural gas distribution business and other industries.

Management believes that utility gross margin provides a more meaningful basis than revenue for evaluating utility operations since natural gas costs, sales tax, TEFA and regulatory rider expenses are included in operating revenue and passed through to customers and, therefore, have no effect on utility gross margin.

Natural gas costs are charged to operating expenses on the basis of therm sales at the prices in NJNG's BGSS tariff approved by the BPU. The BGSS tariff rate includes projected natural gas costs, which include fees paid to pipelines and storage facilities, and the impact of hedging activities and incentive programs. Any underrecoveries or overrecoveries from the projected amounts are deferred and reflected in the BGSS tariff rate in subsequent years.

NJNG's operating revenues and gas purchases decreased by $207.2 million, or 47.8 percent, and by $191.3 million, or 70.1 percent, respectively, during the three months endedMarch 31, 2012, compared with the three months endedMarch 31, 2011, as a result of:

• a decrease in operating revenues and gas purchases related to firm sales in the amount of $79.6 million and $48.6 million, respectively, as a result of lower therm usage due primarily to weather being 22 percent warmer than the prior year, partially offset by an increase in operating revenue of $20.7 million, as a result of higher CIP accruals;

• a decrease in operating revenues and gas purchases in the amount of $66.4 million and $62.1 million, respectively, due to bill credits, inclusive of sales tax refunds of $4.3 million, during the three months endedMarch 31, 2012, that did not occur during the three months endedMarch 31, 2011;

• a decrease in operating revenues and gas purchases related to off-system sales in the amount of $60 million and $58.1 million, respectively, due primarily to a 41.4 percent reduction in volumes of natural gas sold as a result of an increase in the utilization of NJNG's transport capacity for capacity release activity, coupled with a 47 percent decrease in average cost;

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

• a decrease in operating revenues and gas purchases related to firm sales in the amount of $22.3 million and $20.9 million, respectively, as a result of a decrease in the average BGSS rate per therm; partially offset by

• an increase in operating revenue of $1 million due primarily to the increase in base rates related to AIP.

NJNG's operating revenues and gas purchases decreased by $306.5 million, or 42.3 percent, and by $282.4 million, or 62.7 percent, respectively, during the six months endedMarch 31, 2012, compared with the six months endedMarch 31, 2011, as a result of:

• a decrease in operating revenues and gas purchases related to firm sales in the amount of $131.6 million and $79.9 million, respectively, as a result of lower therm usage due primarily to weather being 23.1 percent warmer than the prior year, partially offset by an increase in operating revenue of $34.6 million, as a result of higher CIP accruals;

• a decrease in operating revenues and gas purchases in the amount of $90.7 million and $84.8 million, respectively, due to bill credits, inclusive of sales tax refunds of $5.9 million, during the six months endedMarch 31, 2012, that did not occur during the six months endedMarch 31, 2011;

• a decrease in operating revenues and gas purchases related to off-system sales in the amount of $84 million and $81.6 million, respectively, due primarily to a 35.2 percent reduction in volumes of natural gas sold as a result of an increase in the utilization of NJNG's transport capacity for capacity release activity, coupled with a 32.5 percent decrease in average cost;

• a decrease in operating revenues and gas purchases related to firm sales in the amount of $36.1 million and $33.7 million, respectively, as a result of a decrease in the average BGSS rate per therm; partially offset by

• an increase in operating revenue of $2.1 million due primarily to the increase in base rates related to AIP.

Sales tax and TEFA, which are presented as both components of operating revenues and energy and other taxes in the Unaudited Condensed Consolidated Statements of Operations, totaled $14.4 million and $27.3 million during the three months endedMarch 31, 2012 and 2011, respectively and $26.2 million and $45.8 million during the six months endedMarch 31, 2012, and 2011, respectively. The fluctuation in sales tax correlates directly to the changes in operating revenue from firm sales. The decrease of $8.2 million during the three months endedMarch 31, 2012 was due primarily to a decrease of $195.2 million in operating revenue subject to sales tax, compared with the three months endedMarch 31, 2011. The decrease of $14.3 million during the six months endedMarch 31, 2012, was due primarily to a decrease of $286.3 million in operating revenue subject to sales tax, compared with the six months endedMarch 31, 2011. TEFA, which is calculated on a per-therm basis, decreased $703,000 and $1.4 million during the three and six months endedMarch 31, 2012, primarily due to lower usage compared with the three and six months endedMarch 31, 2011. TEFA will be phased out over a three-year period commencing January 1, 2012.

Regulatory rider expenses, which are calculated on a per-therm basis, consist of recovery of state-mandated programs, the RA and energy efficiency costs. During the three and six months endedMarch 31, 2012, the decrease in expense, which is offset by a corresponding decrease in operating revenue, was due primarily to a 2.6 percent and 2.3 percent decrease in rates and a 22.2 percent and 22.6 percent decrease in usage compared with the three and six months endedMarch 31, 2011, respectively.

NJNG's utility gross margin is comprised of the following components:

• Utility firm gross margin, which is derived from residential and commercial customers who receive natural gas service from NJNG through either sales or transportation tariffs; Utility firm gross margin is earned from residential and commercial customers who receive natural gas service from NJNG through either sales tariffs, which include a commodity and delivery component, or transportation tariffs, which include a delivery component only.

• Incentive programs, where gross margins generated or savings achieved from BPU-approved off-system sales, capacity release, financial risk management or storage incentive programs are shared between customers and NJNG; and

• Utility gross margin from interruptible customers who have the ability to switch to alternative fuels.

Page 32

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

The following table summarizes Utility Gross Margin and Throughput in billion cubic feet (Bcf) of natural gas by type:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2012			2011			2012			2011
($ in thousands)	Margin		Bcf	Margin		Bcf	Margin		Bcf	Margin		Bcf
Utility gross margin/throughput
Residential	$	73,496	15.6	$	72,711	20.9	$	124,726	25.8	$	123,557	34.6
Commercial, industrial and other	17,401		3.0	16,903		4.0	30,511		5.0	29,893		6.7
Firm transportation	17,351		4.7	15,571		5.3	30,531		8.1	26,766		9.3
Total utility firm gross margin/throughput	108,248		23.3	105,185		30.2	185,768		38.9	180,216		50.6
Incentive programs	3,220		23.2	3,431		28.4	6,059		48.8	6,155		55.7
Interruptible	92		1.0	84		1.2	194		3.1	174		2.6
Total utility gross margin/throughput	$	111,560	47.5	$	108,700	59.8	$	192,021	90.8	$	186,545	108.9

Utility Firm Gross Margin

Utility firm gross margin is earned from residential and commercial customers who receive natural gas service from NJNG through either sales tariffs, which include a commodity and delivery component, or transportation tariffs, which include a delivery component only.

Total utility firm gross margin increased $3.1 million and $5.6 million due primarily to customer growth during the three and six months endedMarch 31, 2012, compared with the three and six months endedMarch 31, 2011, respectively.

Utility firm gross margin from transportation service increased $1.8 million to $17.4 million during the three months endedMarch 31, 2012, from $15.6 million during the three months endedMarch 31, 2011, and increased $3.8 million to $30.5 million during the six months endedMarch 31, 2012, from $26.8 million during the six months endedMarch 31, 2011. The improvement was due primarily to an increase in customers that transferred from residential and commercial sales to transportation due to marketing activity by third party natural gas providers in NJNG's distribution territory. NJNG had 34,549 and 28,360 residential customers and 9,086 and 8,743 commercial customers using its transportation service at March 31, 2012 and 2011, respectively.

NJNG added 3,492 and 3,070 new customers and converted 261 and 305 existing customers to natural gas heat and other services during the six months endedMarch 31, 2012, and 2011 , respectively. The customer growth represents an estimated annual increase of approximately 0.4 Bcf in sales to firm customers, which would contribute approximately $1.9 million annually to utility gross margin assuming normal weather and usage.

NJNG's total utility firm gross margin includes the following adjustments related to the CIP mechanism:

	Three Months Ended					Six Months Ended
	March 31,					March 31,
(Thousands)	2012		2011			2012		2011
Weather (1)	$	17,013	$	(36	)	$	25,973	$	(2,850	)
Usage	5,374		1,678			10,240		4,499
Total	$	22,387	$	1,642		$	36,213	$	1,649

(1) Compared with the twenty-year average, weather was 22.5 percent and 21.4 percent warmer-than-normal during the three and six months endedMarch 31, 2012, respectively and 0.6 percent and 3.5 percent colder-than-normal during the three and six months endedMarch 31, 2011, respectively.

Incentive Programs

Utility gross margin generated by NJNG's incentive programs decreased slightly during the three and six months endedMarch 31, 2012, compared with the three and six months endedMarch 31, 2011, due primarily to a decrease in off system sales, offset by an increase in FRM, storage incentive and capacity release margins.

Page 33

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Operating Expenses

Operations and maintenance and other taxes remained relatively consistent during the three and six months endedMarch 31, 2012, compared with the three and six months endedMarch 31, 2011. Depreciation expense during the three and six months endedMarch 31, 2012, increased $514,000 and $923,000 compared with the three and six months endedMarch 31, 2011, as a result of additional utility plant being placed into service.

Operating Income

Operating income increased $2 million, or 2.7 percent, during the three months endedMarch 31, 2012, compared with the three months endedMarch 31, 2011, due primarily to an increase in total utility gross margin of $2.9 million, partially offset by an increase in depreciation expense, as previously discussed. Operating income increased $4.3 million, or 3.7 percent, during the six months endedMarch 31, 2012, compared with the six months endedMarch 31, 2011, due primarily to an increase in total utility gross margin of $5.5 million, partially offset by an increase in depreciation expense, as previously discussed.

Interest Expense

Interest expense decreased slightly during the three and six months endedMarch 31, 2012, compared with the three and six months endedMarch 31, 2011, due primarily to lower interest and commitment fees as a result of the refinancing of NJNG's variable rate long-term debt and credit facility, respectively.

Net Income

Net income increased $896,000, or 2 percent, to $44.9 million during the three months endedMarch 31, 2012 compared with the three months endedMarch 31, 2011, due primarily to the factors discussed above, partially offset by an increase in income tax expense of $738,000 correlating to the higher operating income.

Net income increased $2.5 million, or 3.7 percent, to $70.9 million during the six months endedMarch 31, 2012 compared with the six months endedMarch 31, 2011, due primarily to the factors discussed above, partially offset by an increase in income tax expense of $1.7 million correlating to the higher operating income.

Energy Services Segment

Operating Results

NJRES' financial results are summarized as follows:

	Three Months Ended					Six Months Ended
	March 31,					March 31,
(Thousands)	2012			2011		2012		2011
Operating revenues	$	381,010		$	573,075	$	823,010	$	1,003,849
Gas purchases (including demand charges) (1)	382,432			548,677		789,195		977,992
Gross margin	(1,422		)	24,398		33,815		25,857
Operation and maintenance expense	3,755			3,309		7,096		6,480
Depreciation and amortization	16			15		32		31
Other taxes	304			301		654		595
Operating (loss) income	(5,497		)	20,773		26,033		18,751
Other income	(5		)	4		26		8
Interest expense, net	245			323		515		599
Income tax (benefit) provision	(2,105		)	7,525		9,403		6,683
Net (loss) income	$	(3,642	)	$	12,929	$	16,141	$	11,477

(1) NJRES recognizes its demand charges, which represent the right to use natural gas pipeline and storage capacity assets of a third-party, over the term of the related natural gas pipeline or storage contract. The term of these contracts vary from less than one year to ten years.

Page 34

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

As of March 31, 2012, NJRES' portfolio of financial derivative instruments was comprised of:

• 34.9Bcf of net short futures contracts and fixed swap positions, and;

• 8.2Bcf of net long basis swap positions.

As of March 31, 2011, NJRES' portfolio of financial derivative instruments was comprised of:

• 32.9Bcf of net short futures contracts and fixed swap positions, and;

• 5.0Bcf of net long basis swap positions.

Operating revenues and gas purchases

Natural gas commodity prices are the primary factor for changes in operating revenues and gas purchases at NJRES. During the three and six months ended March 31, 2012, operating revenue decreased $192.1 million and $180.8 million, respectively and gas purchases decreased $166.2 million and $188.8 million, respectively, due primarily to lower average prices, which correlate to the lower price levels on the NYMEX. NYMEX prices averaged $2.74 per MMBtu during the three months endedMarch 31, 2012 compared with $4.11per MMBtu during the three months endedMarch 31, 2011 and averaged $3.14 per MMBtu during the six months endedMarch 31, 2012 compared with $3.95per MMBtu during the six months endedMarch 31, 2011.

Gross margin

NJRES' gross margin is a non-GAAP financial measure defined as natural gas revenues less natural gas purchases (including demand charges), and may not be comparable to the definition of gross margin used by others in the natural gas distribution, energy marketing and other industries. Gross margin during the three months endedMarch 31, 2012, was lower by approximately $25.8 million compared with the three months endedMarch 31, 2011, due primarily to higher unrealized and realized losses during fiscal 2012 compared with fiscal 2011. During the six months endedMarch 31, 2012, gross margin was higher by approximately $8 million compared with the six months endedMarch 31, 2011, due primarily to higher revenue from fee based elements of transactions executed with producers in the Marcellus shale region, and an improvement in the results of transportation arbitrage opportunities as compared with the prior year. Exploration and production of shale gas in the Northeastern region continued to contribute to a compression in natural gas prices and a general decrease in opportunities to generate margin from the optimization of transportation and storage assets in NJRES' market area.

NJRES had unrealized (losses) of $(12) million and $(3.6) million during the three months endedMarch 31, 2012 and 2011, respectively, unrealized gains (losses) of $15.7 million and $(58) million during the six months endedMarch 31, 2012 and 2011, respectively, relating to physical commodity and financial derivative contracts that have not yet settled. These unrealized amounts represent the change in price of natural gas from the original hedge price compared with the market price of natural gas at each reporting date. When transactions are settled any previously recognized unrealized amounts related to these transactions are realized.

NJRES also had realized (losses) of $(18.9) million and $(1.3) million during the three months endedMarch 31, 2012 and 2011, respectively and realized (losses) gains of $(27.3) million and $45.8 million during the six months endedMarch 31, 2012 and 2011, respectively, relating to the effects of economic hedging related to natural gas inventory. The realized (losses) gains pertain to the settlement of certain purchased futures and fixed swap contracts, which economically hedge planned natural gas purchases. The changes resulted from less favorable settlement prices compared with the prior year.

As these financial contracts settle, the physical gas is purchased and injected into storage. These physical gas injections and the associated financial hedges are part of the NJRES' business strategy to subsequently sell the natural gas from storage in the future. The realized amounts are a component of the anticipated financial margin associated with the overall strategy, and as a result of certain accounting requirements, are recognized in current earnings and result in a timing difference until the related gas is sold at which time, NJRES will realize the entire margin on the transaction.

In addition, there was an increase in realized margin associated with physical sale of natural gas during the three and six months endedMarch 31, 2012, as described further in the discussion of financial margin in the Non-GAAP measures section below.

Page 35

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Non-GAAP measures

Management of the Company uses non-GAAP measures, noted as “financial margin” and “net financial earnings,” when evaluating the operating results of NJRES. Since NJRES economically hedges its natural gas purchases and sales with derivative instruments, management uses these measures to compare NJRES' results against established benchmarks and earnings targets as it eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. Volatility can occur as a result of timing differences surrounding the recognition of certain gains and losses. These timing differences can impact GAAP earnings in two ways:

• Unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to sales of physical gas inventory flows; and

• Settlement of economic hedges that result in realized gains and losses prior to when the related physical gas inventory movements occur.

Net financial earnings and net financial margin are measures of the earnings and margin 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 from GAAP to both financial margin and net financial earnings, current period unrealized gains and losses on the derivatives are excluded as a reconciling item. Additionally, the effects of economic hedging on the value of our natural gas in storage is also included in current period net loss. However, financial margin and net financial earnings include 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.

Management views financial margin and net financial earnings as more representative of the overall expected economic result. To the extent that there are unanticipated changes in the markets or to the effectiveness of the economic hedges, NJRES' non-GAAP results can differ from what was originally planned at the beginning of the transaction.

The following table is a computation of NJRES' financial margin:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2012		2011		2012			2011
Operating revenues	$	381,010	$	573,075	$	823,010		$	1,003,849
Less: Gas purchases	382,432		548,677		789,195			977,992
Add:
Unrealized loss (gain) on derivative instruments and related instruments	11,996		3,598		(15,665		)	58,005
Effects of economic hedging related to natural gas inventory	18,862		1,258		27,280			(45,843		)
Financial margin	$	29,436	$	29,254	$	45,430		$	38,019

Page 36

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

A reconciliation of operating income, the closest GAAP financial measurement, to NJRES' financial margin is as follows:

	Three Months Ended					Six Months Ended
	March 31,					March 31,
(Thousands)	2012			2011		2012			2011
Operating (loss) income	$	(5,497	)	$	20,773	$	26,033		$	18,751
Add:
Operation and maintenance expense	3,755			3,309		7,096			6,480
Depreciation and amortization	16			15		32			31
Other taxes	304			301		654			595
Subtotal - Gross margin	(1,422		)	24,398		33,815			25,857
Add:
Unrealized loss (gain) on derivative instruments and related instruments	11,996			3,598		(15,665		)	58,005
Effects of economic hedging related to natural gas inventory	18,862			1,258		27,280			(45,843		)
Financial margin	$	29,436		$	29,254	$	45,430		$	38,019

A reconciliation of NJRES' net income (loss) to net financial earnings is as follows:

	Three Months Ended					Six Months Ended
	March 31,					March 31,
(Thousands)	2012			2011		2012			2011
Net (loss) income	$	(3,642	)	$	12,929	$	16,141		$	11,477
Add:
Unrealized loss (gain) on derivative instruments and related instruments, net of taxes	7,586			2,276		(9,905		)	36,678
Effects of economic hedging related to natural gas inventory, net of taxes	11,927			796		17,250			(28,987		)
Net financial earnings	$	15,871		$	16,001	$	23,486		$	19,168

Financial margin remained relatively flat during the three months endedMarch 31, 2012, compared with the three months endedMarch 31, 2011. Financial margin increased $7.4 million to $45.4 million during the six months endedMarch 31, 2012. The increase was due primarily to higher revenue from fee based elements of transactions executed with producers in the Marcellus shale region, and an improvement in the results of transportation arbitrage opportunities as compared with the prior year. Exploration and production of shale gas in the Northeastern region continued to contribute to a compression in natural gas prices and a general decrease in opportunities to generate margin from the optimization of transportation and storage assets in NJRES' market area.

Despite the favorable results in the first and second quarters, the fundamental change in the supply of shale gas and related market volatility is expected to continue to challenge NJRES' financial margin and net financial earnings.

Operating Expenses

Operation and maintenance expense increased $446,000, or 13.5 percent, during the three months endedMarch 31, 2012, and increased $616,000, or 9.5 percent, during the six months endedMarch 31, 2012, compared with the three and six months endedMarch 31, 2011, respectively, due primarily to an increase in salaries and shared corporate services costs.

Net Financial Earnings

Net financial earnings remained relatively flat during the three months endedMarch 31, 2012, compared with the three months endedMarch 31, 2011. Net financial earnings increased $4.3 million during the six months endedMarch 31, 2012, compared with the six months endedMarch 31, 2011, due primarily to higher financial margin, as previously described, partially offset by applicable income taxes.

Page 37

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Future results are subject to NJRES' ability to maintain and expand its wholesale marketing activities and are contingent upon many other factors, including an adequate number of appropriate counterparties, volatility in the natural gas market, availability of storage arbitrage opportunities, sufficient liquidity in the energy trading market, supply and demand for natural gas and continued access to the capital markets.

Clean Energy Ventures Segment

Operating Results

The financial results of NJRCEV are summarized as follows:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2012			2011			2012			2011
Operating revenues	$	527		$	—		$	907		$	—
Operation and maintenance expense	$	1,691		$	833		$	3,142		$	1,401
Income tax (benefit)	$	(14,826	)	$	(6,071	)	$	(26,997	)	$	(6,710	)
Net income	$	11,862		$	5,171		$	21,959		$	5,225

NJRCEV enters into agreements to invest, own and operate commercial solar installations in the State of New Jersey. There were no commercial projects placed into service during the three months endedMarch 31, 2012. There were two commercial roof-top projects totaling 2 MWs placed into service during the three months endedMarch 31, 2011. During the six months endedMarch 31, 2012, NJRCEV constructed and placed into service four roof-top and ground mounted commercial projects totaling approximately 20.2 MW of solar capacity. In addition, NJRCEV placed into service the remaining 25 percent of the 4.7 MW system in Vineland, New Jersey.

In addition, during the three months endedMarch 31, 2012, NJRCEV's residential solar leasing program installed approximately 1 MW of capacity on 132 homes and installed approximately 2 MW of capacity on 272 homes during the six months endedMarch 31, 2012. This compares with installations of approximately 0.16 MW of capacity on 23 homes during the three months endedMarch 31, 2011, and 0.25 MW of capacity on 35 homes during the six months endedMarch 31, 2011, which were recorded at NJRHS as part of the Retail and Other operations. The residential solar leasing program and related assets were transferred to NJRCEV during the third quarter of fiscal 2011.

Operating revenues generated during the three and six months endedMarch 31, 2012, consisted primarily of the sale of SRECs.

Operation and maintenance expense increased by $858,000 and $1.7 million during the three and six months endedMarch 31, 2012, as compared with the three and six months endedMarch 31, 2011, due primarily to increased costs, as a result of compensation, shared corporate services costs, consulting costs and other administrative expenses.

Income tax benefit during the three months endedMarch 31, 2012 and 2011, includes $13.6 million and $5.7 million, respectively, related to ITCs and $24.9 million and $6.1 million during the six months endedMarch 31, 2012 and 2011, respectively. GAAP requires that for interim reporting, companies forecast their earnings and income taxes, including ITC's, for the year and apply that estimated effective tax rate to the period-to-date pretax income. Total ITC-eligible capital expenditures in fiscal 2012 are forecasted to be $111.7 million, including $100.5 million associated with solar projects placed into service during the six months endedMarch 31, 2012.

Net income in the three and six months endedMarch 31, 2012, increased $6.7 million and $16.7 million, compared with the three and six months endedMarch 31, 2011, due primarily to increased ITCs, partially offset by operation and maintenance expense, as discussed above.

Page 38

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Energy Holdings Segment

Operating Results

The financial results of Energy Holdings are summarized as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2012		2011		2012		2011
Equity in earnings of affiliates	$	3,967	$	4,360	$	7,582	$	7,980
Operation and maintenance expense	$	155	$	133	$	273	$	275
Interest expense, net	$	398	$	593	$	864	$	1,173
Net income	$	2,021	$	2,145	$	3,804	$	3,858

Equity in earnings, which is driven primarily by transportation revenues generated by Iroquois and storage revenues generated by Steckman Ridge is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2012		2011		2012		2011
Iroquois	$	1,592	$	1,449	$	2,837	$	2,627
Steckman Ridge	2,375		2,911		4,745		5,353
Total equity in earnings	$	3,967	$	4,360	$	7,582	$	7,980

Net income decreased slightly during the three and six months endedMarch 31, 2012, compared with the three and six months endedMarch 31, 2011, due primarily to slightly lower equity in earnings offset by lower interest expense resulting from a reduction in debt.

Retail and Other Operations

Operating Results

The consolidated financial results of Retail and Other are summarized as follows:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2012			2011			2012			2011
Operating revenues	$	8,277		$	7,826		$	17,308		$	15,952
Operation and maintenance expense	$	7,554		$	7,500		$	15,813		$	15,213
Net (loss)	$	(543	)	$	(328	)	$	(689	)	$	(488	)

Operating revenues increased $451,000, or 5.8 percent, during the three months endedMarch 31, 2012, to $8.3 million compared with $7.8 million during the three months endedMarch 31, 2011, and $1.4 million, or 8.5 percent, during the six months endedMarch 31, 2012, to $17.3 million compared with $16 million during the six months endedMarch 31, 2011. The improvement was due primarily to increased installations and service contracts at NJRHS.

Operation and maintenance expense remained relatively flat during the three months endedMarch 31, 2012, compared with the three months endedMarch 31, 2011. Operation and maintenance expense increased during the six months endedMarch 31, 2012, compared with the six months endedMarch 31, 2011, due primarily to increased compensation cost and advertising expense at NJRHS.

Net loss during the three and six months endedMarch 31, 2012, increased slightly, compared with the three and six months endedMarch 31, 2011, due primarily to higher equipment costs and increased operation and maintenance expense, as discussed above, partially offset by increased operating revenue. The residential solar pilot program generated $199,000 and $326,000 of net income during the three and six months endedMarch 31, 2011. All solar activity was transferred to NJRCEV in the third quarter of fiscal 2011.

Page 39

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Liquidity and Capital Resources

NJR's objective is to maintain an efficient consolidated capital structure that accommodates the different characteristics of each business segment and business operations and provides adequate financial flexibility for accessing capital markets as required.

NJR's consolidated capital structure was as follows:

	March 31, 2012		September 30, 2011
Common stock equity	58	%	57	%
Long-term debt	29		31
Short-term debt	13		12
Total	100	%	100	%

Common stock equity

NJR satisfies its external common equity requirements, if any, through issuances of its common stock, including the proceeds from stock issuances under its Automatic Dividend Reinvestment Plan (DRP) and proceeds from the exercise of options issued under the Company's long-term incentive program. The DRP allows NJR, at its option, to use shares purchased on the open market, treasury shares or newly issued shares.

In 1996, the NJR Board of Directors (Board) authorized the Company to implement a share repurchase program, which has been expanded several times since the inception of the program. In January 2010, the Board of Directors authorized an increase in the number of shares of NJR common stock authorized for repurchase under NJR's Share Repurchase Plan by 2 million shares to a total of 8.75 million shares. As of March 31, 2012, the Company repurchased a total of approximately 7.4 million of those shares and may repurchase an additional 1.3 million shares under the approved program.

Debt

NJR and its unregulated subsidiaries generally rely on cash flows generated from operating activities and utilization of committed credit facilities to provide liquidity to meet working capital and external debt-financing requirements. NJR may from time to time look to access the capital markets to fund long-life assets.

NJR believes that its existing borrowing availability and cash flow from operations will be sufficient to satisfy its and its subsidiaries' working capital, capital expenditures and dividend requirements for the foreseeable future. NJR, NJNG, NJRCEV and NJRES currently anticipate that its financing requirements for the next twelve months will be met primarily through the issuance of short-term debt, meter sale-leasebacks, proceeds from the Company's DRP and may also include the issuance of long-term debt depending on timing of capital investments.

NJR believes that as of March 31, 2012, NJR and NJNG were, and currently are, in compliance with all debt covenants.

Long-Term Debt

NJR has a $50 million, 6.05 percent senior unsecured note, issued through the private placement market, maturing in September 2017.

As of March 31, 2012, NJNG's long-term debt consisted of $172.8 million in secured fixed-rate debt issuances, with maturities ranging from 2018 to 2040, a $60 million, 4.77 percent unsecured senior note maturing in March 2014, $97 million in secured variable rate debt with maturities ranging from 2027 to 2041 and $49.6 million in capital leases with various maturities ranging from 2012 to 2021.

In addition, NJR has a $100 million and a $75 million uncommitted private placement shelf note agreement, expiring in May 2013 and June 2014, respectively, allowing NJR to issue senior notes, the terms and conditions of which, including interest rates and maturity dates, will be agreed upon at the time of each issuance. As of March 31, 2012, NJR had no borrowings outstanding under these agreements.

Page 40

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

Credit Facilities

NJR uses its short-term borrowings primarily to finance its share repurchases, to satisfy NJRES' short-term liquidity needs and to finance, on an initial basis, unregulated investments. NJRES' use of high-injection, high-withdrawal storage facilities and anticipated pipeline park-and-loan arrangements, combined with related economic hedging activities in the volatile wholesale natural gas market, create significant short-term cash requirements. NJR's short-term debt consists of borrowings under an unsecured $325 million committed credit facility, which expires in December 2012 (NJR Credit Facility). The NJR Credit Facility also permits an increase to the facility, from time to time, with the existing or new lenders, in a minimum of $5 million increments up to a maximum $100 million at the lending banks' discretion. Borrowings under the facility are conditional upon compliance with a maximum leverage ratio, as defined in the NJR Credit Facility, of not more than 0.65 to 1.00 at any time. Depending on borrowing levels and credit ratings, NJR's interest rate can either be, at its discretion, the LIBOR or the Federal Funds Open Rate plus an applicable spread and facility fee.

NJNG satisfies its debt needs by issuing short- and long-term debt based upon its own financial profile. The seasonal nature of NJNG's operations creates large short-term cash requirements, primarily to finance natural gas purchases and customer accounts receivable. NJNG obtains working capital for these requirements, and for the temporary financing of construction and MGP remediation expenditures and energy tax payments, through an unsecured $200 million credit facility that allows for the issuance of commercial paper and short-term bank loans, which expires in August 2014 (NJNG Credit Facility). It also permits an increase to the facility, from time to time, with the existing or new lenders, in a minimum of $15 million increments up to a maximum of $50 million at the lending banks' discretion. Depending on borrowing levels and credit ratings, NJNG's interest rate can either be, at its discretion, based upon Prime Rate, the Federal Funds Open Rate or the Daily LIBOR Rate, in each case, plus an applicable spread and facility fee. In addition, borrowings under the NJNG' Credit Facility are conditioned upon compliance with a maximum leverage ratio, as defined in the credit facility, of not more than 0.65 to 1.00 at any time.

Due to the seasonal nature of natural gas prices and demand, NJR and NJNG's short-term borrowings tend to peak in the winter months. As of March 31, 2012, NJR and NJNG had $155.5 million and $166 million, respectively, available under the NJR Credit Facility and NJNG Credit Facility, respectively. In addition, NJNG has a $100 million credit facility to provide liquidity support for its variable rate long-term debt that has not been used to date.

Short-term borrowings were as follows:

	Three Months Ended			Six Months Ended
($ in thousands)	March 31, 2012
NJR
Notes Payable to banks:
Balance at end of period	$	157,300		$	157,300
Weighted average interest rate at end of period	0.53		%	0.53		%
Average balance for the period	$	203,950		$	202,795
Weighted average interest rate for average balance	0.60		%	0.59		%
Month end maximum for the period	$	208,500		$	241,800
NJNG
Commercial Paper:
Balance at end of period	$	34,000		$	34,000
Weighted average interest rate at end of period	0.16		%	0.16		%
Average balance for the period	$	56,427		$	52,652
Weighted average interest rate for average balance	0.14		%	0.14		%
Month end maximum for the period	$	67,200		$	74,700

NJR

As noted above, during the six months endedMarch 31, 2012, NJR's average interest rate was 0.59 percent, resulting in interest expense of $607,600. Based on average borrowings under the NJR Credit Facility of $202.8 million during the period, a 100 basis point change in the underlying average interest rate would have caused a change in interest expense of approximately $1 million during the six months endedMarch 31, 2012.

Page 41

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

As of March 31, 2012, NJR has five letters of credit outstanding totaling $12.2 million, which reduces the amount available under the NJR Credit Facility by the same amount.

NJNG

During the six months endedMarch 31, 2012, NJNG's weighted average interest rate under the NJNG Credit Facility was 0.14 percent, resulting in interest expense of $36,400. Based on average borrowings under the facility of $52.7 million during the period, a 100 basis point change in the underlying average interest rate would have caused a change in interest expense of approximately $266,200 during six months endedMarch 31, 2012.

Neither NJNG nor its assets are obligated or pledged to support the NJR Credit Facility.

Sale-Leaseback

NJNG received $6.5 million and $5.9 million in December 2011 and 2010, respectively, in connection with the sale-leaseback of its natural gas meters. This sale-leaseback program is expected to continue on an annual basis.

Contractual Obligations

In conjunction with NJR's goal to promote clean energy, NJR has entered into various agreements to install solar equipment involving both residential and commercial projects. NJR expects capital expenditures related to the purchase and installation of the equipment associated with these contracts to be approximately $82.6 million in fiscal 2012, of which $79.8 million has either been spent or committed. Capital expenditures are expected to be $90 million fiscal 2013. The capital expenditures related to these projects are subject to a variety of factors, including logistics associated with the start-up of residential and commercial solar projects, such as timing of construction schedules, the permitting and regulatory process and any delays related to electric grid interconnection, which may affect our ability to commence operations at these projects on a timely basis or, at all.

NJNG's total capital expenditures are estimated at $121.2 million and $70 million in fiscal 2012 and 2013, respectively, and consist primarily of its construction program to support customer growth, maintenance of its distribution and transmission system and replacement needed under pipeline safety regulations. Capital expenditures in fiscal 2012 include an estimated $49.9 million related to AIP II. As of March 31, 2012, NJNG's capital expenditures spent or committed were $49.1 million, of which, $14.9 million was related to the AIP II program. Effective October 2011, NJNG is recovering in base rates approximately $8.9 million annually, based on AIP expenditures incurred through August 31, 2011.

Off-Balance-Sheet Arrangements

The Company does not have any off-balance-sheet arrangements, with the exception of guarantees covering approximately $363 million of natural gas purchases and demand fee commitments and outstanding letters of credit totaling $12.2 million, as noted above.

Cash Flow

Operating Activities

As presented in the Unaudited Condensed Consolidated Statements of Cash Flows, cash flow generated from operating activities totaled $104.6 million during the six months endedMarch 31, 2012, compared with $181 million during the six months endedMarch 31, 2011. Operating cash flows are primarily affected by variations in working capital, which can be impacted by the following:

•seasonality of NJR's business;

•fluctuations in wholesale natural gas prices;

•timing of storage injections and withdrawals;

•the deferral and recovery of gas costs;

Page 42

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

•changes in contractual assets utilized to optimize margins related to natural gas transactions;

•timing of the collections of receivables and payments of current liabilities; and

•volumes of natural gas purchased and sold.

Net income increased $23.5 million during the six months endedMarch 31, 2012, compared with the six months endedMarch 31, 2011, due primarily to an increase of $46.4 million in unrealized gains, net of tax, associated with changes in the values of financial derivative instruments.

In addition, the decrease of $76.4 million in cash generated from operations during the six months endedMarch 31, 2012 as compared with the six months endedMarch 31, 2011, was impacted by:

• lower overall commodity prices, which contributed toward favorable changes at NJRES of $69.3 million in receivables balances and $34.6 million in gas in storage, offset by a decrease in cash associated with gas purchases payables at NJRES of $81.3 million.

• a decrease of $67.6 million in broker margin balances at NJRES resulting from an overall decrease in market price of natural gas and resulting favorable impact on open positions held as of March 31, 2012; partially offset by

• a discretionary contribution of $20 million to the Company's pension plan during fiscal 2012 compared with a contribution of $4.9 million during fiscal 2011; and

• credits of $80.7 million issued to NJNG's customers during fiscal 2012 for overrecovered gas costs;

Investing Activities

Cash flow used in investing activities totaled $111.3 million during the six months endedMarch 31, 2012, compared with $59 million during the six months endedMarch 31, 2011. The increase was due primarily to higher capital expenditures at NJRCEV related to its solar projects.

Financing Activities

Financing cash flows generally are seasonal in nature and are impacted by the volatility in pricing in the natural gas markets. NJNG's inventory levels are built up during its natural gas injection season (April through October) and reduced during withdrawal season (November through March) in response to the supply requirements of its customers. Changes in financing cash flows can also be impacted by the funding demands of NJRES' gas management and marketing functions.

Cash flow generated from financing activities totaled $7 million during the six months endedMarch 31, 2012, compared with $(46.5) million used during the six months endedMarch 31, 2011. The increase is due primarily to higher short-term borrowings at NJR and a non-recurring redemption of long-term debt during fiscal 2011.

Credit Ratings

The table below summarizes NJNG's current credit ratings issued by two rating entities, Standard and Poor's (S&P) and Moody's Investors Service, Inc. (Moody's):

	Standard and Poor's	Moody's
Corporate Rating	A	N/A
Commercial Paper	A-1	P-1
Senior Secured	A+	Aa3
Ratings Outlook	Stable	Stable

NJNG's S&P and Moody's ratings are investment-grade ratings. NJR is not a rated entity.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)

NJNG is not party to any lending agreements that would accelerate the maturity date of any obligation caused by a failure to maintain any specific credit rating. If such ratings are downgraded below investment grade, borrowing costs could increase, as would the costs of maintaining certain contractual relationships and future financing. Even if ratings are downgraded without falling below investment grade, NJR and NJNG could still face increased borrowing costs under their credit facilities. A rating set forth above is not a recommendation to buy, sell or hold the Company's or NJNG's securities and may be subject to revision or withdrawal at any time. Each rating set forth above should be evaluated independently of any other rating.

The timing and mix of any external financings will target a common equity ratio that is consistent with maintaining the Company's current short-term and long-term credit ratings.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK                                              

Financial Risk Management

Commodity Market Risks

Natural gas is a nationally traded commodity. Its prices are determined effectively by the NYMEX and over-the-counter markets. The prices on the NYMEX and over-the-counter markets generally reflect the national balance of natural gas supply and demand, but are also significantly influenced from time to time by other events.

The regulated and unregulated natural gas businesses of NJR and its subsidiaries are subject to market risk due to fluctuations in the price of natural gas. To economically hedge against such fluctuations, NJR and its subsidiaries have entered into forwards, futures contracts, options agreements and swap agreements. To manage these derivative instruments, NJR has well-defined risk management policies and procedures that include daily monitoring of volumetric limits and monetary guidelines. NJR's natural gas businesses are conducted through three of its operating subsidiaries. NJNG is a regulated utility that uses futures, options and swaps to economically hedge against price fluctuations, and its recovery of natural gas costs is governed by the BPU. NJRES uses futures, options, swaps and physical contracts to economically hedge purchases and sales of natural gas and NJR Energy from time to time may enter into energy-related ventures.

The following table reflects the changes in the fair market value of financial derivatives related to natural gas purchases and sales from September 30, 2011 to March 31, 2012:

	Balance				Increase				Less			Balance
(Thousands)	September 30, 2011				(Decrease) in Fair Market Value				Amounts Settled			March 31, 2012
NJNG		$	(8,452	)		$	(33,353	)		$	1,700		$	(43,505	)
NJRES		13,661				83,696				53,312			44,045
Total		$	5,209			$	50,343			$	55,012		$	540

There were no changes in methods of valuations during the year ended March 31, 2012.

The following is a summary of fair market value of financial derivatives at March 31, 2012, excluding foreign exchange contracts discussed below, by method of valuation and by maturity for each fiscal year period:

(Thousands)	2012			2013		2014 - 2016				After 2016				Total Fair Value
Price based on NYMEX	$	(14,594	)	$	428		$	28			$	—			$	(14,138	)
Price based on other external data	12,452			4,696			(2,459		)		(11		)		14,678
Total	$	(2,142	)	$	5,124		$	(2,431	)		$	(11	)		$	540

Page 44

New Jersey Resources Corporation

Part I

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)                         

The following is a summary of financial derivatives by type as of March 31, 2012:

		Volume Bcf		Price per MMBtu	Amounts included in Derivatives (Thousands)
NJNG	Futures	14.8		$2.19 - $4.56		$	(44,588	)
	Swaps	3.3		$0.00 - $3.85		1,394
	Options	2.4		$0.07 - $0.26		(311		)
NJRES	Futures	(26.0	)	$2.13 - $4.94		30,450
	Swaps	(0.7	)	$1.47 - $6.75		13,595
Total						$	540

The following table reflects the changes in the fair market value of physical commodity contracts from September 30, 2011 to March 31, 2012:

	Balance			Increase			Less		Balance
(Thousands)	September 30, 2011			(Decrease) in Fair Market Value			Amounts Settled		March 31, 2012
NJRES - Prices based on other external data		$	26,339		(10,160	)		5,814		$	10,365

The Company's market price risk is predominately related to changes in the price of natural gas at Henry Hub, which is the delivery point for the NYMEX natural gas futures contracts. As the fair value of futures and our fixed swaps is derived from this location, the price sensitivity analysis below has been prepared for all open Henry Hub natural gas futures and fixed swap positions. Based on this, an illustrative 10 percent movement in Henry Hub natural gas futures contract prices for example, increases (decreases) the reported derivative fair value of all open, unadjusted Henry Hub natural gas futures and fixed swap positions by approximately $11.1 million. This analysis does not include potential changes to reported credit adjustments embedded in the $39.7 million reported fair value.

Derivative Fair Value Sensitivity Analysis
(Thousands)	Henry Hub Futures and Fixed Price Swaps
Percent increase in NYMEX natural gas futures prices	—%		5%			10%			15%			20%
Estimated change in derivative fair value	$	—	$	(5,574	)	$	(11,148	)	$	(16,721	)	$	(22,295	)
Ending derivative fair value	$	39,739	$	34,165		$	28,591		$	23,018		$	17,444
Percent decrease in NYMEX natural gas futures prices	—%		(5)%			(10)%			(15)%			(20)%
Estimated change in derivative fair value	$	—	$	5,574		$	11,148		$	16,721		$	22,295
Ending derivative fair value	$	39,739	$	45,313		$	50,887		$	56,460		$	62,034

Wholesale Credit Risk

The following is a summary of gross and net credit exposures, grouped by investment and noninvestment grade counterparties, as of March 31, 2012. Gross credit exposure is defined as the unrealized fair value of derivative and energy trading 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. Net credit exposure is defined as gross credit exposure reduced by collateral received from counterparties and/or payables, where netting agreements exist. The amounts presented below exclude accounts receivable for NJNG retail natural gas sales and services.

NJRES' counterparty credit exposure as of March 31, 2012, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	99,850		$	72,563
Noninvestment grade		21,366			20,292
Internally rated investment grade		23,727			9,880
Internally rated noninvestment grade		6,015			—
Total		$	150,958		$	102,735

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New Jersey Resources Corporation

Part I

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)                         

NJNG's counterparty credit exposure as of March 31, 2012, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	7,235		$	6,513
Noninvestment grade		91			5
Internally rated investment grade		1,853			1,538
Internally rated noninvestment grade		1,436			965
Total		$	10,615		$	9,021

Due to the inherent volatility in the prices of natural gas commodities and derivatives, 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 (for example, failed to deliver or pay for natural gas), the Company could sustain a loss. This loss would comprise the loss on natural gas delivered but not paid for and/or the cost of replacing natural gas not delivered or received at a price that is unfavorable to the price in the original contract. Any such loss could have a material impact on the Company's financial condition, results of operations or cash flows.

Liquidation of Clearing Broker

MF Global Inc. (MFGI) and MF Global UK Limited (UKMF), which operated as futures commission merchants and broker/dealer entities of MF Global Holdings Ltd. (collectively with its affiliates, MF Global), were NJRES' clearing brokers through which NJRES held positions in energy futures contracts, options on futures contracts, and swaps cleared on exchanges administered by the Chicago Mercantile Exchange (CME) and the Intercontinental Exchange (ICE). The CME and ICE both require NJRES to maintain adequate margin against NJRES' trading positions, which our former clearing brokers, MFGI and UKMF, were required to hold on our behalf in segregated or secured accounts. MF Global disclosed to the CME that it had a “significant shortfall” in its segregated customer accounts. Shortly thereafter, on October 31, 2011, the Securities Investor Protection Corporation announced that it had initiated the liquidation of MFGI under the Securities Investor Protection Act (SIPA) in the U.S. and the High Court in the U.K. appointed special administrators to conduct the liquidation of UKMF. The SIPA Trustee's latest estimate of the shortfall in commodities customers' segregated account funds is $1.6 billion.

As of the close of business on November 3, 2011, the market value of NJRES' MF Global account was $27.8 million, of which $10.6 million related to CME positions and $17.2 million related to ICE positions. To date, NJRES has received distributions from the SIPA Trustee totaling$7.6 million related to its CME positions. Accordingly, the remaining exposure as of March 31, 2012, is $20.2 million.

NJRES has filed claims in both the MFGI and UKMF liquidation proceedings and intends to vigorously prosecute those claims to recover all of its funds, but it cannot estimate at this time, either how much of those funds will be recovered or when they will be recovered.

Interest Rate Risk

Information regarding NJR's interest rate risk can be found in Item 7A. Quantitative and Qualitative Disclosures About Market Risks Management's Discussion and Analysis of Financial Condition and Results of Operations of its Annual Report on Form 10-K for the period ended September 30, 2011 and the Liquidity and Capital Resources - Debt section of Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Effects of Inflation

Although inflation rates have been relatively low to moderate in recent years, any change in price levels has an effect on operating results due to the capital-intensive and regulated nature of the Company's utility subsidiary. The Company attempts to minimize the effects of inflation through cost control, productivity improvements and regulatory actions when appropriate.

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New Jersey Resources Corporation

Part I

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Under the supervision and with the participation of the Company's management, including the principal executive officer and principal financial officer, the Company conducted an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) (the Exchange Act), as of the end of the period covered by this report. Based on this evaluation, the Company's principal executive officer and principal financial officer concluded that, as of end of the period covered by this report, the Company's disclosure controls and procedures are effective, to ensure that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act, is recorded, processed, summarized and reported, within the time periods specified in the SEC's rules and forms, and that such information is accumulated and communicated to the Company's management, including its principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

There has been no change in internal control over financial reporting (as such term is defined in Exchange Act Rule 13a-15(f)) that occurred during the quarter ended March 31, 2012, that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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New Jersey Resources Corporation

Part II

ITEM 1. LEGAL PROCEEDINGS                                                                                                                                                

Information regarding reportable legal proceedings is contained in Part I, "Item 3. Legal Proceedings" in NJR's Annual Report on Form 10-K for the year ended September 30, 2011, and is set forth in Part I, Item 1, Note 11.Commitment and Contingent Liabilities-Legal Proceedings in the Unaudited Condensed Consolidated Financial Statements. No legal proceedings became reportable during the quarter ended March 31, 2012, and there have been no material developments during such quarter regarding any previously reported legal proceedings, which have not been previously disclosed.

ITEM 1A. RISK FACTORS                                                                                                                                                             

While NJR attempts to identify, manage and mitigate risks and uncertainties associated with its business to the extent practical, under the circumstances, some level of risk and uncertainty will always be present. Part I, Item 1A. Risk Factors of NJR's 2011 Annual Report on Form 10-K includes a detailed discussion of NJR's risk factors. Those risks and uncertainties have the potential to materially affect NJR's financial condition and results of operations. NJR does not believe that there have been any material changes from the risk factors as previously disclosed by NJR in the 2011 Annual Report on Form 10-K.

ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS                                                  

The following table sets forth NJR's repurchase activity for the quarter ended March 31, 2012:

Period	Total Number of Shares (or Units) Purchased	Average Price Paid per Share (or Unit)		Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs	Maximum Number (or Approximate Dollar Value) of Shares (or Units) That May Yet Be Purchased Under the Plans or Programs
01/01/12 - 01/31/12	23,000	$	47.09	23,000	1,336,570
02/01/12 - 02/29/12	—	$	—	—	1,336,570
03/01/12 - 03/31/12	—	—		—	1,336,570
Total	23,000	$	47.09	23,000	1,336,570

(1) The stock repurchase plan, which was authorized by our Board of Directors, became effective in September 1996 and includes 8,750,000 shares of common stock for repurchase, of which, as of March 31, 2012, 1,336,570 shares remained for repurchase. The stock repurchase plan will expire when we have repurchased all shares authorized for repurchase thereunder, unless the repurchase plan is earlier terminated by action of our Board of Directors or further shares are authorized for repurchase.

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New Jersey Resources Corporation

Part II

ITEM 6. EXHIBITS                                                                                                                                                                         

Exhibit Number Exhibit Description

31.1+	Certification of the Chief Executive Officer pursuant to section 302 of the Sarbanes-Oxley Act
31.2+	Certification of the Chief Financial Officer pursuant to section 302 of the Sarbanes-Oxley Act
32.1+ †	Certification of the Chief Executive Officer pursuant to section 906 of the Sarbanes-Oxley Act
32.2+ †	Certification of the Chief Financial Officer pursuant to section 906 of the Sarbanes-Oxley Act
101+	Interactive Data File (Form 10-Q, for the fiscal period ended March 31, 2012, furnished in XBRL (eXtensible Business Reporting Language)).

_______________________________

+ Filed herewith.

†    This certificate accompanies this report pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not be deemed filed by NJR for purposes of Section 18 or any other provision of the Securities Exchange Act of 1934, as amended.

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New Jersey Resources Corporation

Part II

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		NEW JERSEY RESOURCES CORPORATION
		(Registrant)
Date:	May 4, 2012
		By:/s/ Glenn C. Lockwood
		Glenn C. Lockwood
		Executive Vice President and
		Chief Financial Officer

Page 50

EX-31.1

EXHIBIT 31.1

CERTIFICATION OF THE PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

 I, Laurence M. Downes, certify that:

1) I have reviewed this quarterly report on Form 10-Q of New Jersey Resources Corporation;

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

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

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

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

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

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

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

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

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

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

Date:	May 4, 2012	By:	/s/ Laurence M. Downes
			Laurence M. Downes
			Chairman, President & Chief Executive Officer

EX-31.2

EXHIBIT 31.2

CERTIFICATION OF THE PRINCIPAL FINANCIAL OFFICER

PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

 I, Glenn C. Lockwood, certify that:

1) I have reviewed this quarterly report on Form 10-Q of New Jersey Resources Corporation;

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

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

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

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

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

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

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

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

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

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

Date:	May 4, 2012	By:	/s/ Glenn C. Lockwood
			Glenn C. Lockwood
			Executive Vice President and Chief Financial Officer

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED

PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

The undersigned, Laurence M. Downes hereby certifies as follows:

(a) I am the Chief Executive Officer of New Jersey Resources Corporation;

(b) To the best of my knowledge, this quarterly report on Form 10-Q for the period ended March 31, 2012, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(c) To the best of my knowledge, based upon a review of this report, the information contained in this periodic report fairly presents, in all material respects, the financial condition and results of operations of the issuer.

Date:	May 4, 2012	By:	/s/ Laurence M. Downes
			Laurence M. Downes
			Chairman, President and Chief Executive Officer

EX-32.2

EXHIBIT 32.2

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350 AS ADOPTED

PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

The undersigned, Glenn C. Lockwood hereby certifies as follows:

(a) I am the Chief Financial Officer of New Jersey Resources Corporation;

(b) To the best of my knowledge, this quarterly report on Form 10-Q for the period ended March 31, 2012, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(c) To the best of my knowledge, based upon a review of this report, the information contained in this periodic report fairly presents, in all material respects, the financial condition and results of operations of the issuer.

Date:	May 4, 2012	By:	/s/ Glenn C. Lockwood
			Glenn C. Lockwood
			Executive Vice President and Chief Financial Officer

XML

DERIVATIVE INSTRUMENTS, BROKER MARGIN DEPOSITS (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Sep. 30, 2011
Restricted broker margin assets	$ 66,515	$ 22,595
Restricted broker margin liabilities	(29,671)	0
NJNG [Member]
Restricted broker margin assets	46,361	11,722
NJRES [Member]
Restricted broker margin assets	20,154	10,873
Restricted broker margin liabilities	$ (29,671)	$ 0

XML

BUSINESS SEGMENT AND OTHER OPERATIONS DATA, NET FINANCIAL EARNINGS LOSS RECONCILIATION (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				6 Months Ended
	Mar. 31, 2012		Mar. 31, 2011		Mar. 31, 2012		Mar. 31, 2011
Net Financial Earnings	$ 74,126		$ 67,029		$ 119,434		$ 96,159
Unrealized (Gain) Loss from Derivative Instruments and Related Transactions Net of Taxes	7,664	[1]	2,306	[1]	(9,708)	[1]	36,710	[1]
Effects of Economic Hedging Related to Natural Gas Inventory Net of Taxes	11,927		796		17,250		(28,987)
Net income	54,535		63,927		111,892		88,436
Transactions Between NJNG and NJRES [Member]
Unrealized (Gain) Loss from Derivative Instruments and Related Transactions Net of Taxes	$ 79		$ 30		$ 197		$ 32

[1] Excludes unrealized losses related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $79,000 and $30,000, for the three months ended March 31, 2012 and March 31, 2011, respectively, and $197,000, and $32,000 for the six months ended March 31, 2012 and 2011, respectively.

XML

EMPLOYEE BENEFIT PLANS, Defined Contribution (Details) (Pension Plans Excluding Pension Equalization Plan, Defined Benefit [Member], USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2012
Pension Plans Excluding Pension Equalization Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Contributions by Employer	$ 20

XML

BUSINESS SEGMENT AND OTHER OPERATIONS DATA, RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012		Sep. 30, 2011
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ 2,669,739		$ 2,649,444
Categorized Business Segments [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	2,622,957		2,583,747
Natural Gas Distribution [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	1,951,497		1,942,691
Energy Services [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	346,995		400,882
Clean Energy Ventures [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	166,478		80,234
Energy Holdings [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	157,987		159,940
Retail and Other [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	66,742		87,066
Business Intersegment, Eliminations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ (19,960)	[1]	$ (21,369)	[1]

[1] Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.

XML

DEBT, SCHEDULE OF LONG TERM DEBT (Details) (NJNG [Member], USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
NJNG [Member]
Debt Instrument [Line Items]
Sale Leaseback Transaction, Gross Proceeds	$ 6.5	$ 5.9

XML

SUMMARY OF SIGNIFICANT ACCOUTNING POLICIES, AVAILABLE FOR SALE SECURITIES (Details) (USD $)	Mar. 31, 2012		Sep. 30, 2011
Available-for-sale Securities, Gross Unrealized Gain (Loss)	$ 7,700,000		$ 7,700,000
Accumulated Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	4,600,000		4,500,000
Fair Value, Measurements, Recurring [Member]
Available-for-sale Securities, Fair Value Disclosure	10,408,000	[1]	10,348,000	[1]
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Available-for-sale Securities, Fair Value Disclosure	$ 10,408,000	[1]	$ 10,348,000	[1]

[1] Included in other noncurrent assets in the Unaudited Condensed Consolidated Balance Sheets.

XML

INVESTMENTS IN EQUITY INVESTEES (Tables)

6 Months Ended

Mar. 31, 2012

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments [Text Block]

NJR's investments in equity investees include the following investments as of:

(Thousands)	March 31, 2012		September 30, 2011
Steckman Ridge	$	134,703	$	135,130
Iroquois	22,346		23,933
Total	$	157,049	$	159,063

XML

COMMITMENTS AND CONTINGENT LIABILITIES, SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) (USD $)	6 Months Ended
	Mar. 31, 2012
Long-term Purchase Commitment [Line Items]
Current Charges Recoverable Through BGSS	$ 96,000,000
Natural Gas Purchases and Future Demand Fees [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	380,570,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	363,255,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	145,835,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	74,278,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	58,979,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	264,863,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	317,863,000
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	255,313,000
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	47,562,000
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	23,177,000
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	16,313,000
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	29,780,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	62,707,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	107,942,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	98,273,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	51,101,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	42,666,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	235,083,000
Natural Gas Purchases [Member] | NJRES [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	264,023,000
Natural Gas Purchases [Member] | NJRES [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	181,858,000
Natural Gas Purchases [Member] | NJRES [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	6,555,000
Natural Gas Purchases [Member] | NJRES [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	0
Natural Gas Purchases [Member] | NJRES [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	0
Natural Gas Purchases [Member] | NJRES [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	0
Natural Gas Purchases [Member] | NJNG [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	19,877,000
Natural Gas Purchases [Member] | NJNG [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	1,096,000
Natural Gas Purchases [Member] | NJNG [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	0
Natural Gas Purchases [Member] | NJNG [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	0
Natural Gas Purchases [Member] | NJNG [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	0
Natural Gas Purchases [Member] | NJNG [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	0
Storage Demand Fees [Member] | NJRES [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	21,136,000
Storage Demand Fees [Member] | NJRES [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	31,625,000
Storage Demand Fees [Member] | NJRES [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	18,838,000
Storage Demand Fees [Member] | NJRES [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	12,286,000
Storage Demand Fees [Member] | NJRES [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	7,236,000
Storage Demand Fees [Member] | NJRES [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	12,353,000
Storage Demand Fees [Member] | NJNG [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	15,666,000
Storage Demand Fees [Member] | NJNG [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	30,070,000
Storage Demand Fees [Member] | NJNG [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	25,123,000
Storage Demand Fees [Member] | NJNG [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	15,888,000
Storage Demand Fees [Member] | NJNG [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	11,088,000
Storage Demand Fees [Member] | NJNG [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	33,245,000
Pipeline Demand Fees [Member] | NJRES [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	32,704,000
Pipeline Demand Fees [Member] | NJRES [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	41,830,000
Pipeline Demand Fees [Member] | NJRES [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	22,169,000
Pipeline Demand Fees [Member] | NJRES [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	10,891,000
Pipeline Demand Fees [Member] | NJRES [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	9,077,000
Pipeline Demand Fees [Member] | NJRES [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	17,427,000
Pipeline Demand Fees [Member] | NJNG [Member] | Three Months from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	27,164,000
Pipeline Demand Fees [Member] | NJNG [Member] | More than One and within Two Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	76,776,000
Pipeline Demand Fees [Member] | NJNG [Member] | More than Two and within Three Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	73,150,000
Pipeline Demand Fees [Member] | NJNG [Member] | More than Three and within Four Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	35,213,000
Pipeline Demand Fees [Member] | NJNG [Member] | More than Four and within Five Years from Balance Sheet Date [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	31,578,000
Pipeline Demand Fees [Member] | NJNG [Member] | More than Five Years from Balance Sheet Date and Thereafter [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	$ 201,838,000

[1] Does not include amounts related to intercompany asset management agreements between NJRES and NJNG.

XML

FAIR VALUE, HIERARCHY (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012		Sep. 30, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	$ 106,839		$ 106,853
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities, Fair Value Disclosure	10,408	[1]	10,348	[1]
Other Assets, Fair Value Disclosure	3,865		2,820
Assets Fair Value Disclosure Total	121,112		120,021
Other Liabilities Fair Value Disclosure	729		616
Liabilities Fair Value Disclosure	96,508		75,655
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities, Fair Value Disclosure	10,408	[1]	10,348	[1]
Other Assets, Fair Value Disclosure	3,865		2,820
Assets Fair Value Disclosure Total	61,485		38,785
Other Liabilities Fair Value Disclosure	729		616
Liabilities Fair Value Disclosure	62,080		24,331
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities, Fair Value Disclosure	0	[1]	0	[1]
Other Assets, Fair Value Disclosure	0		0
Assets Fair Value Disclosure Total	59,627		81,236
Other Liabilities Fair Value Disclosure	0		0
Liabilities Fair Value Disclosure	34,428		51,324
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale Securities, Fair Value Disclosure	0	[1]	0	[1]
Other Assets, Fair Value Disclosure	0		0
Assets Fair Value Disclosure Total	0		0
Other Liabilities Fair Value Disclosure	0		0
Liabilities Fair Value Disclosure	0		0
Physical Forward Commodity Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	22,119		37,690
Derivative Liabilities, Fair Value Disclosure	11,754		11,351
Physical Forward Commodity Contracts [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	0		0
Derivative Liabilities, Fair Value Disclosure	0		0
Physical Forward Commodity Contracts [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	22,119		37,690
Derivative Liabilities, Fair Value Disclosure	11,754		11,351
Physical Forward Commodity Contracts [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	0		0
Derivative Liabilities, Fair Value Disclosure	0		0
Financial Commodity Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	84,500		68,883
Derivative Liabilities, Fair Value Disclosure	83,960		63,674
Financial Commodity Contracts [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	47,212		25,617
Derivative Liabilities, Fair Value Disclosure	61,351		23,715
Financial Commodity Contracts [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	37,288		43,266
Derivative Liabilities, Fair Value Disclosure	22,609		39,959
Financial Commodity Contracts [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	0		0
Derivative Liabilities, Fair Value Disclosure	0		0
Financial commodity contracts - foreign exchange [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	220		280
Derivative Liabilities, Fair Value Disclosure	65		14
Financial commodity contracts - foreign exchange [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	0		0
Derivative Liabilities, Fair Value Disclosure	0		0
Financial commodity contracts - foreign exchange [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	220		280
Derivative Liabilities, Fair Value Disclosure	65		14
Financial commodity contracts - foreign exchange [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Fair Value Disclosure	0
Derivative Liabilities, Fair Value Disclosure	$ 0		$ 0

[1] Included in other noncurrent assets in the Unaudited Condensed Consolidated Balance Sheets.

XML

DERIVATIVE INSTRUMENTS, INCOME STATEMENT RELATED DISCLOSURES (Details) (USD $)	3 Months Ended				6 Months Ended
	Mar. 31, 2012		Mar. 31, 2011		Mar. 31, 2012		Mar. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Foreign Currency Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months	$ 105,000				$ 105,000
Maximum Length of Time Hedged in Foreign Currency Cash Flow Hedge					April 2015
Foreign Exchange Contract [Member] | Gas Purchases [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income, Effective Portion, Net	(25,000)	[1]	42,000	[1]	(75,000)	[1]	161,000	[1]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(23,000)		(50,000)		(35,000)		(59,000)
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0		0		0		0
NJRES [Member] | Nondesignated [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Income, Net	49,372,000		32,354,000		104,193,000		(8,677,000)
NJRES [Member] | Physical Commodity Contracts [Member] | Operating Revenues [Member] | Nondesignated [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Income, Net	8,745,000		41,306,000		(3,163,000)		24,837,000
NJRES [Member] | Physical Commodity Contracts [Member] | Gas Purchases [Member] | Nondesignated [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Income, Net	116,000		(9,448,000)		4,391,000		(5,739,000)
NJRES [Member] | Financial Commodity Contracts [Member] | Gas Purchases [Member] | Nondesignated [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Income, Net	40,511,000		496,000		102,965,000		(27,775,000)
NJNG [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Gain Loss Recognized in Regulatory Assets and Liabilities Net	$ (15,400,000)		$ (2,200,000)		$ (35,300,000)		$ (4,900,000)

[1] )The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $105,000 from OCI into earnings. The maximum tenor is April 2015

XML

COMMITMENTS AND CONTINGENT LIABILITIES, LEGAL PROCEEDINGS (Details) (USD $)	6 Months Ended
	Mar. 31, 2012	Sep. 30, 2011
Site Contingency [Line Items]
Site Contingency, Recovery from Third Party of Environmental Remediation Cost	$ 20,000,000
Regulatory assets	410,901,000	434,185,000
Maximum [Member]
Site Contingency [Line Items]
Litigation Settlement, Gross	278,500,000
Minimum [Member]
Site Contingency [Line Items]
Litigation Settlement, Gross	161,500,000
Enviromental remediation costs expended, net of recoveries [Member]
Site Contingency [Line Items]
Regulatory assets	61,259,000	75,646,000
Enviromental remediation costs liability for future expenditures [Member]
Site Contingency [Line Items]
Regulatory assets	$ 182,900,000	$ 182,900,000

XML

EMPLOYEE BENEFIT PLANS, Defined Benefit Plans (Details) (USD $)			3 Months Ended		6 Months Ended			3 Months Ended		6 Months Ended
	Mar. 31, 2012	Sep. 30, 2011	Mar. 31, 2012 Pension [Member]	Mar. 31, 2011 Pension [Member]	Mar. 31, 2012 Pension [Member]	Mar. 31, 2011 Pension [Member]	Mar. 31, 2012 Pension Plans Excluding Pension Equalization Plan, Defined Benefit [Member]	Mar. 31, 2012 OPEB [Member]	Mar. 31, 2011 OPEB [Member]	Mar. 31, 2012 OPEB [Member]	Mar. 31, 2011 OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Contributions by Employer							$ 20,000,000
Change in Benefit Obligation [Roll Forward]
Service cost			1,344,000	1,194,000	2,688,000	2,388,000		896,000	836,000	1,792,000	1,672,000
Interest cost			2,206,000	2,095,000	4,412,000	4,189,000		1,283,000	1,212,000	2,566,000	2,423,000
Change in plan assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer							20,000,000
Amounts recognized on Consolidated Balance Sheets, Postemployment benefit liability
Non-current	(95,176,000)	(114,305,000)
Amounts Recognized in Regulatory Assets and Accumulated Other Comprehensive Income [Roll Forward]
Recognized actuarial loss			1,254,000	987,000	2,508,000	1,973,000		724,000	653,000	1,448,000	1,306,000
Prior service cost amortization			11,000	12,000	22,000	24,000		6,000	19,000	12,000	38,000
Recognized net initial obligation			0	0	0	0		89,000	89,000	178,000	178,000
Components of net periodic cost
Service cost			1,344,000	1,194,000	2,688,000	2,388,000		896,000	836,000	1,792,000	1,672,000
Interest cost			2,206,000	2,095,000	4,412,000	4,189,000		1,283,000	1,212,000	2,566,000	2,423,000
Expected return on plan assets			(3,171,000)	(2,873,000)	(6,342,000)	(5,745,000)		(686,000)	(618,000)	(1,372,000)	(1,236,000)
Recognized actuarial loss			1,254,000	987,000	2,508,000	1,973,000		724,000	653,000	1,448,000	1,306,000
Prior service cost amortization			11,000	12,000	22,000	24,000		6,000	19,000	12,000	38,000
Recognized net initial obligation			0	0	0	0		89,000	89,000	178,000	178,000
Net periodic cost			$ 1,644,000	$ 1,415,000	$ 3,288,000	$ 2,829,000		$ 2,312,000	$ 2,191,000	$ 4,624,000	$ 4,381,000

XML

REGULATION

6 Months Ended

Mar. 31, 2012

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. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes 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, 2012		September 30, 2011
Regulatory assets-current
Conservation Incentive Program	$	20,871	$	9,178
Underrecovered gas costs	16,544		—
Derivatives, net	43,505		8,452
Total current	$	80,920	$	17,630
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	61,259	$	75,646
Liability for future expenditures	182,900		182,900
Deferred income taxes	10,879		10,879
Energy Efficiency Program	17,913		11,906
New Jersey Clean Energy Program	13,522		20,144
Postemployment and other benefit costs	120,247		123,827
Other	4,181		8,883
Total noncurrent	$	410,901	$	434,185
Regulatory liability-current
Overrecovered gas costs	$	—	$	4,633
Total current	$	—	$	4,633
Regulatory liabilities-noncurrent
Cost of removal obligation	$	63,133	$	59,752
Other	258		85
Total noncurrent	$	63,391	$	59,837

NJNG's recovery of costs is facilitated through its base rates, Basic Gas Supply Service (BGSS) and other regulatory 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 November 17, 2011, NJNG notified the BPU that it will provide bill credits to NJNG's residential and small commercial customers during December 2011 and January 2012, as a result of the decline in the wholesale prices of natural gas and a change in the methodology used to develop estimates of unaccounted-for gas. On January 25, 2012 and March 9, 2012, NJNG notified the BPU that it would extend bill credits through February 2012 and March 2012, respectively. In total, customers received approximately $90.7 million in credits based on usage during the four-month period.

• On January 18, 2012, the BPU approved an extension of NJNG's Energy Efficiency program (EE) for one year with an additional $18.4 million of investments in customer incentives and financing earning a weighted average cost of capital of 7.1 percent, including a cost of equity of 10.3 percent.

• On January 18, 2012, the BPU issued an Order approving NJNG's 2010 Societal Benefits Clause (SBC) filing, in which NJNG requested approval of its manufactured gas plant remediation expenditures incurred through September 30, 2009, as well as continuation of its existing overall SBC rate. In February 2012, NJNG filed its 2011 SBC filing, which requested approval of its MGP expenditures incurred through September 30, 2011, with no additional rate impact on customers.

• On March 9, 2012, NJNG notified the BPU that it will implement a 3.6 percent decrease to its BGSS rate, effective April 1, 2012, with an annual impact of approximately $19 million.

• On March 20, 2012, NJNG filed a petition with the BPU seeking to implement a Safety Acceleration and Facility Enhancement (SAFE) program, whereby NJNG would invest up to $204 million over a five-year period to replace portions of NJNG's gas distribution infrastructure. If approved, commencing in 2013, NJNG would file a petition with the BPU annually in June to recover costs over the life of the program, including an overall weighted average cost of capital of 7.76 percent, including a cost of equity of 10.3 percent.

XML

INVESTMENTS IN EQUITY INVESTEES (Details) (USD $)	Mar. 31, 2012	Sep. 30, 2011
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 157,049,000	$ 159,063,000
Steckman Ridge [Member]
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	134,703,000	135,130,000
Iroquois [Member]
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	22,346,000	23,933,000
Equity Method Investee [Member] | Steckman Ridge [Member]
Schedule of Equity Method Investments [Line Items]
Outstanding principal balance	$ 70,400,000

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COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

6 Months Ended

Mar. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment [Table Text Block]

Commitments as of March 31, 2012, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2012		2013		2014		2015		2016		Thereafter
NJRES:
Natural gas purchases	$	264,023	$	181,858	$	6,555	$	—	$	—	$	—
Storage demand fees	21,136		31,625		18,838		12,286		7,236		12,353
Pipeline demand fees	32,704		41,830		22,169		10,891		9,077		17,427
Sub-total NJRES	$	317,863	$	255,313	$	47,562	$	23,177	$	16,313	$	29,780
NJNG:
Natural gas purchases	$	19,877	$	1,096	$	—	$	—	$	—	$	—
Storage demand fees	15,666		30,070		25,123		15,888		11,088		33,245
Pipeline demand fees	27,164		76,776		73,150		35,213		31,578		201,838
Sub-total NJNG	$	62,707	$	107,942	$	98,273	$	51,101	$	42,666	$	235,083
Total (1)	$	380,570	$	363,255	$	145,835	$	74,278	$	58,979	$	264,863

(1) Does not include amounts related to intercompany asset management agreements between NJRES and NJNG.

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EMPLOYEE BENEFIT PLANS (Tables)

6 Months Ended

Mar. 31, 2012

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Benefit Costs [Table Text Block]

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)	2012			2011			2012			2011			2012			2011			2012			2011
Service cost	$	1,344		$	1,194		$	2,688		$	2,388		$	896		$	836		$	1,792		$	1,672
Interest cost	2,206			2,095			4,412			4,189			1,283			1,212			2,566			2,423
Expected return on plan assets	(3,171		)	(2,873		)	(6,342		)	(5,745		)	(686		)	(618		)	(1,372		)	(1,236		)
Recognized actuarial loss	1,254			987			2,508			1,973			724			653			1,448			1,306
Prior service cost amortization	11			12			22			24			6			19			12			38
Recognized net initial obligation	—			—			—			—			89			89			178			178
Net periodic benefit cost	$	1,644		$	1,415		$	3,288		$	2,829		$	2,312		$	2,191		$	4,624		$	4,381

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RELATED PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended	6 Months Ended
	Mar. 31, 2012	Mar. 31, 2012
NJRES to Steckman Ridge Affiliate
Related Party Transaction [Line Items]
Demand Fees Expense Recognized by NJRES Pertaining to Related Party Agreement	$ 2,100,000	$ 4,100,000
Due to Related Parties	238,000	238,000
NJRES to Iroquois Affiliate [Member]
Related Party Transaction [Line Items]
Due to Related Parties	392,000	392,000
NJNG to NJRES Affilate [Member]
Related Party Transaction [Line Items]
Natural Gas Sold at Cost Under Asset Management Agreement (MMcf)		1,000
NJNG to Steckman RIdge Affiliate
Related Party Transaction [Line Items]
Demand Fees Expense Recognized by NJRES Pertaining to Related Party Agreement	1,900,000	4,000,000
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
Due to Related Parties	775,000	775,000
NJNG to Iroquois Affiliate [Member]
Related Party Transaction [Line Items]
Due from Related Parties	$ (146,000)	$ (146,000)

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EARNINGS PER SHARE (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended				6 Months Ended
	Mar. 31, 2012		Mar. 31, 2011		Mar. 31, 2012		Mar. 31, 2011
Earnings Per Share, Basic [Line Items]
Net income	$ 54,535		$ 63,927		$ 111,892		$ 88,436
Basic earnings per share
Weighted average shares of common stock outstanding-basic	41,509,000		41,352,000		41,472,000		41,316,000
Basic earnings per common share	$ 1.31		$ 1.55		$ 2.70		$ 2.14
Diluted earnings per share
Incremental shares	202,000	[1]	201,000	[1]	201,000	[1]	200,000	[1]
Weighted average shares of common stock outstanding-diluted	41,711,000		41,553,000		41,673,000		41,516,000
Diluted earnings per common share	$ 1.31	[2]	$ 1.54	[2]	$ 2.68	[2]	$ 2.13	[2]
Antidilutive securities excluded from computation of earnings per share, amount	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 March 31, 2012 and 2011.

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA (Tables)

6 Months Ended

Mar. 31, 2012

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment [Table Text Block]

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)	2012			2011			2012			2011
Operating revenues
Natural Gas Distribution
External customers	$	226,023		$	433,248		$	417,397		$	723,924
Intercompany	—			—			—			—
Energy Services
External customers	378,356			535,987			820,162			950,418
Intercompany	2,654			37,088			2,848			53,431
Clean Energy Ventures
External customers	527			—			907			—
Segment subtotal	607,560			1,006,323			1,241,314			1,727,773
Retail and Other
External customers	8,014			7,751			16,866			15,796
Intercompany	263			75			442			156
Eliminations	(2,916		)	(37,162		)	(3,290		)	(53,586		)
Total	$	612,921		$	976,987		$	1,255,332		$	1,690,139
Depreciation and amortization
Natural Gas Distribution	$	8,749		$	8,235		$	17,381		$	16,458
Energy Services	16			15			32			31
Clean Energy Ventures	1,511			28			2,321			28
Energy Holdings	2			2			3			3
Segment subtotal	10,278			8,280			19,737			16,520
Retail and Other	161			197			302			411
Total	$	10,439		$	8,477		$	20,039		$	16,931
Interest income (1)
Natural Gas Distribution	$	214		$	280		$	460		$	540
Energy Services	(5		)	3			26			8
Energy Holdings	285			224			533			452
Segment subtotal	494			507			1,019			1,000
Retail and Other	1			1			1			1
Eliminations	(268		)	(217		)	(503		)	(438		)
Total	$	227		$	291		$	517		$	563

(1) Included in other income in the Unaudited Condensed Consolidated Statements of Operations.

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2012			2011			2012			2011
Interest expense, net of capitalized interest
Natural Gas Distribution	$	3,713		$	3,808		$	7,450		$	7,824
Energy Services	245			323			515			599
Clean Energy Ventures	198			3			340			7
Energy Holdings	683			817			1,397			1,625
Segment subtotal	4,839			4,951			9,702			10,055
Retail and Other	588			127			730			286
Total	$	5,427		$	5,078		$	10,432		$	10,341
Income tax provision (benefit)
Natural Gas Distribution	$	27,016		$	26,278		$	42,612		$	40,879
Energy Services	(2,105		)	7,525			9,403			6,683
Clean Energy Ventures	(14,826		)	(6,071		)	(26,997		)	(6,710		)
Energy Holdings	1,393			1,487			2,624			2,670
Segment subtotal	11,478			29,219			27,642			43,522
Retail and Other	(312		)	(588		)	(371		)	(1,044		)
Eliminations	(72		)	(19		)	(140		)	(13		)
Total	$	11,094		$	28,612		$	27,131		$	42,465
Equity in earnings of affiliates
Energy Holdings	$	3,967		$	4,360		$	7,582		$	7,980
Segment subtotal	3,967			4,360			7,582			7,980
Eliminations	(949		)	(750		)	(1,910		)	(1,453		)
Total	$	3,018		$	3,610		$	5,672		$	6,527
Net financial earnings (loss)
Natural Gas Distribution	$	44,936		$	44,040		$	70,910		$	68,396
Energy Services	15,871			16,001			23,486			19,168
Clean Energy Ventures	11,862			5,171			21,959			5,225
Energy Holdings	2,021			2,145			3,804			3,858
Segment subtotal	74,690			67,357			120,159			96,647
Retail and Other	(543		)	(328		)	(689		)	(488		)
Eliminations	(21		)	—			(36		)	—
Total	$	74,126		$	67,029		$	119,434		$	96,159
Capital expenditures
Natural Gas Distribution	$	27,427		$	18,988		$	49,145		$	47,186
Clean Energy Ventures	14,175			9,038			61,786			9,937
Segment subtotal	41,602			28,026			110,931			57,123
Retail and Other	370			1,717			459			1,963
Total	$	41,972		$	29,743		$	111,390		$	59,086

Reconciliation of Consolidated Net Financial Earnings to Consolidated Net Income [Text Block]

A reconciliation of consolidated net financial earnings to consolidated net income is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2012		2011		2012			2011
Consolidated net financial earnings	$	74,126	$	67,029	$	119,434		$	96,159
Less:
Unrealized loss (gain) from derivative instruments and related transactions, net of taxes (1)	7,664		2,306		(9,708		)	36,710
Effects of economic hedging related to natural gas inventory, net of taxes	11,927		796		17,250			(28,987		)
Consolidated net income	$	54,535	$	63,927	$	111,892		$	88,436

(1) Excludes unrealized losses related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $79,000 and $30,000, for the three months ended March 31, 2012 and March 31, 2011, respectively, and $197,000, and $32,000 for the six months endedMarch 31, 2012 and 2011, respectively.

Reconciliation of Assets from Segment to Consolidated [Text Block]

The Company's assets for the various business segments and business operations are detailed below:

(Thousands)	March 31, 2012			September 30, 2011
Assets at end of period:
Natural Gas Distribution	$	1,951,497		$	1,942,691
Energy Services	346,995			400,882
Clean Energy Ventures	166,478			80,234
Energy Holdings	157,987			159,940
Segment subtotal	2,622,957			2,583,747
Retail and Other	66,742			87,066
Intercompany assets (1)	(19,960		)	(21,369		)
Total	$	2,669,739		$	2,649,444

(1) Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.

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NATURE OF BUSINESS (Details)	6 Months Ended
	Mar. 31, 2012 Customers
Total Retail Customers	499,500
Steckman Ridge [Member]
Equity Method Investment, Ownership Percentage	50.00%
Iroquois [Member]
Equity Method Investment, Ownership Percentage	5.53%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Mar. 31, 2012

Accounting Policies [Abstract]

Significant Accounting Policies [Text Block]

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 (SEC). The September 30, 2011, 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 financial statements and the notes thereto included in NJR's 2011 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, 2012.

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, 2012				September 30, 2011
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJNG		$	67,104	10.7		$	159,328	23.1
NJRES		108,105		41.9		135,147		36.8
Total		$	175,209	52.6		$	294,475	59.9

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 $10.4 million and $10.3 million as of March 31, 2012 and September 30, 2011, 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 $7.7 million ($4.6 million, after tax) and $7.7 million ($4.5 million, after tax) as of March 31, 2012 and September 30, 2011, respectively.

Recent Updates to the Accounting Standards Codification (ASC)

Fair Value

In May 2011, the FASB issued an amendment to ASC Topic 820, Fair Value Measurements and Disclosures, clarifying certain guidance to ensure that U.S. generally accepted accounting principles (U.S. GAAP) and International Financial Reporting Standards (IFRS) have the same fair value meaning, measurements and disclosure requirements. The amended guidance became effective for interim and annual periods beginning after December 15, 2011. There was no impact to the Company's financial position, results of operations or cash flows upon adoption.

Presentation of Comprehensive Income

In June 2011, the FASB issued an update to ASC Topic 220, Comprehensive Income, allowing two alternatives for the presentation of comprehensive income, eliminating the option to present the components of comprehensive income (OCI) as a part of the statement of changes in stockholder's equity and requiring that reclassification adjustments from OCI to income be presented on the face of the financial statements. The amended guidance requires that comprehensive income, including the components of net income and OCI, be presented in either one statement or in two separate but consecutive statements. In December 2011, the FASB issued a subsequent amendment indefinitely deferring the provisions requiring reclassification adjustments out of OCI to be presented on the face of the financial statements. The other portions of the original update remain unchanged and became effective for interim and annual periods beginning after December 15, 2011, with early adoption permitted. Effective September 30, 2011, NJR adopted the two-statement approach retrospectively. There was no impact to the Company's financial position, results of operations or cash flows upon adoption.

Balance Sheet Offsetting

In December 2011, the FASB issued an amendment to ASC Topic 210, Balance Sheet, requiring additional disclosures about the nature of an entity's rights of setoff and related master netting arrangements associated with its financial and derivative instruments. The objective of the disclosures is to facilitate comparison between financial statements prepared on the basis of U.S. generally accepted accounting principles (U.S. GAAP) and those prepared on the basis of International Financial Reporting Standards (IFRS). The amended guidance will become effective for interim and annual periods beginning on or after January 1, 2013 and will be applied retrospectively. The Company has determined that the new guidance will not impact its financial position, results of operations or cash flows upon adoption.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES, GAS IN STORAGE (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012 MMcf	Sep. 30, 2011 MMcf
Public Utilities, Inventory [Line Items]
Gas in storage (BCF)	52,600	59,900
Gas in storage	$ 175,209	$ 294,475
NJNG [Member]
Public Utilities, Inventory [Line Items]
Gas in storage (BCF)	10,700	23,100
Gas in storage	67,104	159,328
NJRES [Member]
Public Utilities, Inventory [Line Items]
Gas in storage (BCF)	41,900	36,800
Gas in storage	$ 108,105	$ 135,147

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DERIVATIVE INSTRUMENTS, CREDIT RISK EXPOSURE (Details) (USD $)	6 Months Ended		6 Months Ended
	Mar. 31, 2012	Sep. 30, 2011	Mar. 31, 2012 External Credit Rating, Investment Grade [Member]	Mar. 31, 2012 External Credit Rating, Non Investment Grade [Member]	Mar. 31, 2012 Internally Rated Investment Grade [Member]	Mar. 31, 2012 Internally Rated Noninvestment Grade [Member]	Mar. 31, 2012 NJRES [Member]	Nov. 03, 2011 NJRES [Member]	Mar. 31, 2012 NJRES [Member] CHICAGO MERCANTILE EXCHANGE [Member]	Mar. 31, 2012 NJRES [Member] INTERCONTINENTAL EXCHANGE [Member]	Mar. 31, 2012 NJRES [Member] Long Position [Member] CHICAGO MERCANTILE EXCHANGE [Member]	Feb. 10, 2012 MF Global Potential Segregation and Compliance Shortfalls [Member]
Credit Risk Exposure [Line Items]
Gross credit exposure	$ 161,573,000		$ 107,085,000	$ 21,457,000	$ 25,580,000	$ 7,451,000
Derivative, Net Liability Position, Aggregate Fair Value	2,600,000	4,100,000
Additional Collateral, Aggregate Fair Value	2,200,000	1,700,000
MF Global Potential Segregation and Compliance Shortfalls												1,600,000,000
Margin Deposit Assets							$ 20,200,000	$ 27,800,000	$ 10,600,000	$ 17,200,000	$ 7,600,000

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA, RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				6 Months Ended
	Mar. 31, 2012		Mar. 31, 2011		Mar. 31, 2012		Mar. 31, 2011
Segment Reporting Information [Line Items]
Utility	$ 226,023		$ 433,248		$ 417,397		$ 723,924
Nonutility	386,898		543,739		837,935		966,215
Total operating revenues	612,921		976,987		1,255,332		1,690,139
Depreciation and amortization	10,439		8,477		20,039		16,931
Investment Income, Interest	227	[1]	291	[1]	517	[1]	563	[1]
Interest expense, net of capitalized interest	5,427		5,078		10,432		10,341
Income tax provision (benefit)	11,094		28,612		27,131		42,465
Equity in earnings of affiliates	3,018		3,610		5,672		6,527
Net Financial Earnings (Loss)	74,126		67,029		119,434		96,159
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	41,972		29,743		111,390		59,086
Reportable Segment [Member]
Segment Reporting Information [Line Items]
Total operating revenues	607,560		1,006,323		1,241,314		1,727,773
Depreciation and amortization	10,278		8,280		19,737		16,520
Investment Income, Interest	494	[1]	507	[1]	1,019	[1]	1,000	[1]
Interest expense, net of capitalized interest	4,839		4,951		9,702		10,055
Income tax provision (benefit)	11,478		29,219		27,642		43,522
Equity in earnings of affiliates	3,967		4,360		7,582		7,980
Net Financial Earnings (Loss)	74,690		67,357		120,159		96,647
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	41,602		28,026		110,931		57,123
Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	8,749		8,235		17,381		16,458
Investment Income, Interest	214	[1]	280	[1]	460	[1]	540	[1]
Interest expense, net of capitalized interest	3,713		3,808		7,450		7,824
Income tax provision (benefit)	27,016		26,278		42,612		40,879
Net Financial Earnings (Loss)	44,936		44,040		70,910		68,396
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	27,427		18,988		49,145		47,186
Natural Gas Distribution [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Utility	226,023		433,248		417,397		723,924
Natural Gas Distribution [Member] | Intercompany [Member]
Segment Reporting Information [Line Items]
Utility	0		0		0		0
Energy Services [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	16		15		32		31
Investment Income, Interest	(5)	[1]	3	[1]	26	[1]	8	[1]
Interest expense, net of capitalized interest	245		323		515		599
Income tax provision (benefit)	(2,105)		7,525		9,403		6,683
Net Financial Earnings (Loss)	15,871		16,001		23,486		19,168
Energy Services [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility	378,356		535,987		820,162		950,418
Energy Services [Member] | Intercompany [Member]
Segment Reporting Information [Line Items]
Nonutility	2,654		37,088		2,848		53,431
Energy Holdings [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	2		2		3		3
Investment Income, Interest	285	[1]	224	[1]	533	[1]	452	[1]
Interest expense, net of capitalized interest	683		817		1,397		1,625
Income tax provision (benefit)	1,393		1,487		2,624		2,670
Equity in earnings of affiliates	3,967		4,360		7,582		7,980
Net Financial Earnings (Loss)	2,021		2,145		3,804		3,858
Clean Energy Ventures [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	1,511		28		2,321		28
Interest expense, net of capitalized interest	198		3		340		7
Income tax provision (benefit)	(14,826)		(6,071)		(26,997)		(6,710)
Net Financial Earnings (Loss)	11,862		5,171		21,959		5,225
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	14,175		9,038		61,786		9,937
Clean Energy Ventures [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility	527		0		907		0
Retail and Other [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	161		197		302		411
Investment Income, Interest	1	[1]	1	[1]	1	[1]	1	[1]
Interest expense, net of capitalized interest	588		127		730		286
Income tax provision (benefit)	(312)		(588)		(371)		(1,044)
Net Financial Earnings (Loss)	(543)		(328)		(689)		(488)
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	370		1,717		459		1,963
Retail and Other [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility	8,014		7,751		16,866		15,796
Retail and Other [Member] | Intercompany [Member]
Segment Reporting Information [Line Items]
Nonutility	263		75		442		156
Business Intersegment, Eliminations [Member]
Segment Reporting Information [Line Items]
Nonutility	(2,916)		(37,162)		(3,290)		(53,586)
Investment Income, Interest	(268)	[1]	(217)	[1]	(503)	[1]	(438)	[1]
Income tax provision (benefit)	(72)		(19)		(140)		(13)
Equity in earnings of affiliates	(949)		(750)		(1,910)		(1,453)
Net Financial Earnings (Loss)	$ (21)		$ 0		$ (36)		$ 0

[1] Included in other income in the Unaudited Condensed Consolidated Statements of Operations.

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CONSOLIDATED STATEMENTS OF OPERATIONS (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended				6 Months Ended
	Mar. 31, 2012		Mar. 31, 2011		Mar. 31, 2012		Mar. 31, 2011
OPERATING REVENUES
Utility	$ 226,023		$ 433,248		$ 417,397		$ 723,924
Nonutility	386,898		543,739		837,935		966,215
Total operating revenues	612,921		976,987		1,255,332		1,690,139
OPERATING EXPENSES
Gas Purchases - Utility	78,301		235,001		163,931		395,450
Gas Purchases - Nonutility	382,055		548,618		788,472		977,865
Operation and maintenance	39,185		37,896		78,130		75,312
Regulatory rider expenses	18,443		24,304		30,986		41,002
Depreciation and amortization	10,439		8,477		20,039		16,931
Energy and other taxes	16,809		29,489		30,867		50,114
Total operating expenses	545,232		883,785		1,112,425		1,556,674
OPERATING INCOME	67,689		93,202		142,907		133,465
Other income	349		805		876		1,250
Interest expense, net of capitalized interest	5,427		5,078		10,432		10,341
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	62,611		88,929		133,351		124,374
Income tax provision	11,094		28,612		27,131		42,465
Equity in earnings of affiliates	3,018		3,610		5,672		6,527
NET INCOME	$ 54,535		$ 63,927		$ 111,892		$ 88,436
EARNINGS PER COMMON SHARE
BASIC	$ 1.31		$ 1.55		$ 2.70		$ 2.14
DILUTED	$ 1.31	[1]	$ 1.54	[1]	$ 2.68	[1]	$ 2.13	[1]
DIVIDENDS PER COMMON SHARE	$ 0.38		$ 0.36		$ 0.76		$ 0.72
WEIGHTED AVERAGE SHARES OUTSTANDING
BASIC	41,509		41,352		41,472		41,316
DILUTED	41,711		41,553		41,673		41,516

[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, 2012 and 2011.

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DEBT, CREDIT FACILITIES (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012		Sep. 30, 2011
Notes Payable to Banks [Member] | NJR [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amount Outstanding	$ 157,300		$ 132,850
Debt Weighted Average Interest Rate	0.53%		0.54%
Commercial Paper [Member] | NJNG [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amount Outstanding	34,000		26,500
Debt Weighted Average Interest Rate	0.16%		0.24%
Debt Shelf Facilities Long term [Member] | NJR [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	175,000	[1],[2],[3]	175,000	[1],[2],[3]
Debt Shelf Facility MetLife [Member] | NJR [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	100,000
Debt Shelf Facility Prudential [Member] | NJR [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	75,000
Bank Credit Facilities Short term [Member] | NJR [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	325,000	[4]	325,000	[4]
Line of Credit Facility, Remaining Borrowing Capacity	155,453		157,853
Bank Credit Facilities Short term [Member] | NJNG [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	200,000	[4]	200,000	[4]
Line of Credit Facility, Remaining Borrowing Capacity	166,000		173,500
Bank Credit Facilities, EDA Bonds [Member] | NJNG [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 100,000	[1],[4]	$ 100,000	[1],[4]

[1] There were no borrowings outstanding as of March 31, 2012 and September 30, 2011, respectively.

[2] Uncommitted, long-term debt shelf facilities, which require no commitment fees on the unused amounts.

[3] $100 million debt shelf expires May 2013 and $75 million debt shelf expires June 2014.

[4] Committed credit facilities, which require commitment fees on the unused amounts.

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CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Sep. 30, 2011
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 1,634,936	$ 1,595,278
Real estate properties, solar and other, at cost	179,402	110,886
Total property, plant and equipment	1,814,338	1,706,164
Accumulated depreciation and amortization	(417,563)	(410,237)
Property, plant and equipment, net	1,396,775	1,295,927
CURRENT ASSETS
Cash and cash equivalents	7,802	7,440
Customer accounts receivable
Billed	179,006	209,266
Unbilled revenues	16,428	7,333
Allowance for doubtful accounts	(4,806)	(4,612)
Regulatory assets	80,920	17,630
Gas in storage, at average cost	175,209	294,475
Materials and supplies, at average cost	7,741	7,395
Prepaid and Accrued taxes	23,803	54,311
Derivatives, at fair value	103,506	100,338
Restricted broker margin accounts	66,515	22,595
Deferred taxes	0	1,498
Other	18,552	14,698
Total current assets	674,676	732,367
NONCURRENT ASSETS
Investments in equity investees	157,049	159,063
Regulatory assets	410,901	434,185
Derivatives, at fair value	3,333	6,515
Other	27,005	21,387
Total noncurrent assets	598,288	621,150
Total assets	2,669,739	2,649,444
CAPITALIZATION
Common stock equity	862,242	776,257
Long-term debt	429,450	426,797
Total capitalization	1,291,692	1,203,054
CURRENT LIABILITIES
Current maturities of long-term debt	8,117	7,575
Short-term debt	191,300	159,350
Gas purchases payable	171,750	252,691
Accounts payable and other	63,268	65,960
Dividends payable	15,780	14,912
Deferred and accrued taxes	17,295	778
Regulatory liabilities	0	4,633
New Jersey clean energy program	13,522	15,011
Derivatives, at fair value	92,028	68,698
Restricted broker margin accounts	29,671	0
Customers' credit balances and deposits	31,455	113,776
Total current liabilities	634,186	703,384
NONCURRENT LIABILITIES
Deferred income taxes	353,237	327,782
Deferred investment tax credits	6,066	6,227
Deferred revenue	5,966	7,633
Derivatives, at fair value	3,751	6,341
Manufactured gas plant remediation	182,900	182,900
Postemployment employee benefit liability	95,176	114,305
Regulatory liabilities	63,391	59,837
New Jersey clean energy program	0	5,133
Asset retirement obligation	27,537	27,026
Other	5,837	5,822
Total noncurrent liabilities	743,861	743,006
Commitments and contingent liabilities (Note 11)
Total capitalization and liabilities	$ 2,669,739	$ 2,649,444

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REGULATION, REGULATORY FILINGS (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2012
BGSS [Member]
Schedule of Regulatory [Line Items]
Annual Recovery Amount Proposed to the Public Utility Regulatory Authority	$ (19)
Rate Increase (Decrease) Proposed to the Public Utility Regulatory Authority	(3.60%)
Customer Refunds And Bill Credits	(90.7)
EE [Member]
Schedule of Regulatory [Line Items]
Weighted Cost of Capital	7.10%
Return on Equity	10.30%
EE-Rebates and Incentives [Member]
Schedule of Regulatory [Line Items]
Recovery Amount Approved by the Board of Public Utilities	18.4
SAFE-Safety Acceleration and Facility Enhancement Program [Member]
Schedule of Regulatory [Line Items]
Originally Filed Petition for Capital Investments to the Public Utility Regulatory Authority	$ 204
Weighted Cost of Capital	7.76%
Return on Equity	10.30%

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REGULATION (Tables)

6 Months Ended

Mar. 31, 2012

Regulated Operations [Abstract]

Schedule of Regulatory Assets and Liabilities [Text Block]

Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets are comprised of the following:

(Thousands)	March 31, 2012		September 30, 2011
Regulatory assets-current
Conservation Incentive Program	$	20,871	$	9,178
Underrecovered gas costs	16,544		—
Derivatives, net	43,505		8,452
Total current	$	80,920	$	17,630
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	61,259	$	75,646
Liability for future expenditures	182,900		182,900
Deferred income taxes	10,879		10,879
Energy Efficiency Program	17,913		11,906
New Jersey Clean Energy Program	13,522		20,144
Postemployment and other benefit costs	120,247		123,827
Other	4,181		8,883
Total noncurrent	$	410,901	$	434,185
Regulatory liability-current
Overrecovered gas costs	$	—	$	4,633
Total current	$	—	$	4,633
Regulatory liabilities-noncurrent
Cost of removal obligation	$	63,133	$	59,752
Other	258		85
Total noncurrent	$	63,391	$	59,837

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DERIVATIVE INSTRUMENTS, BALANCE SHEET RELATED DISCLOSURES (Details) (USD $)	Mar. 31, 2012	Sep. 30, 2011
Derivatives, Fair Value [Line Items]
Derivative Assets, Current	$ 103,506,000	$ 100,338,000
Derivative Liabilities, Current	92,028,000	68,698,000
Derivative Assets, Noncurrent	3,333,000	6,515,000
Derivative Liabilities, Noncurrent	3,751,000	6,341,000
Derivative Assets	106,839,000	106,853,000
Derivative Liabilities	95,779,000	75,039,000
Notional Amount of Foreign Currency Derivatives	11,500,000
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets	106,619,000	106,573,000
Derivative Liabilities	95,714,000	75,025,000
Physical Commodity Contracts [Member] | NJRES [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets, Current	21,541,000	33,240,000
Derivative Liabilities, Current	11,150,000	10,570,000
Derivative Assets, Noncurrent	578,000	4,450,000
Derivative Liabilities, Noncurrent	604,000	781,000
Financial Commodity Contracts [Member] | NJRES [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets, Current	75,789,000	61,521,000
Derivative Liabilities, Current	31,139,000	44,862,000
Derivative Assets, Noncurrent	2,499,000	1,936,000
Derivative Liabilities, Noncurrent	3,104,000	4,934,000
Financial Commodity Contracts [Member] | NJNG [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets, Current	6,049,000	5,424,000
Derivative Liabilities, Current	49,717,000	13,258,000
Derivative Assets, Noncurrent	163,000	2,000
Derivative Liabilities, Noncurrent	0	620,000
Foreign Exchange Contract [Member] | NJRES [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets, Current	127,000	153,000
Derivative Liabilities, Current	22,000	8,000
Derivative Assets, Noncurrent	93,000	127,000
Derivative Liabilities, Noncurrent	43,000	6,000
Derivative Assets	220,000	280,000
Derivative Liabilities	$ 65,000	$ 14,000

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FAIR VALUE (Tables)

6 Months Ended

Mar. 31, 2012

Fair Value Disclosures [Abstract]

Fair Value, by Balance Sheet Grouping [Text Block]

The estimated fair value of long-term debt, including current maturities is as follows:

(Thousands)	March 31, 2012		September 30, 2011
Carrying value	$	437,567	$	434,372
Fair market value	$	478,010	$	471,022

Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis [Text Block]

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, 2012:
Assets:
Physical forward commodity contracts		$	—		$	22,119		$	—	$	22,119
Financial derivative contracts - natural gas		47,212			37,288			—		84,500
Financial commodity contracts - foreign exchange		—			220			—		220
Available for sale equity securities - energy industry (1)		10,408			—			—		10,408
Other		3,865			—			—		3,865
Total assets at fair value		$	61,485		$	59,627		$	—	$	121,112
Liabilities:
Physical forward commodity contracts		$	—		$	11,754		$	—	$	11,754
Financial commodity contracts - natural gas		61,351			22,609			—		83,960
Financial commodity contracts - foreign exchange		—			65			—		65
Other		729			—			—		729
Total liabilities at fair value		$	62,080		$	34,428		$	—	$	96,508
As of September 30, 2011:
Assets:
Physical forward commodity contracts		$	—		$	37,690		$	—	$	37,690
Financial derivative contracts - natural gas		25,617			43,266			—		68,883
Financial commodity contracts - foreign exchange		—			280					280
Available for sale equity securities - energy industry(1)		10,348			—			—		10,348
Other		2,820			—			—		2,820
Total assets at fair value		$	38,785		$	81,236		$	—	$	120,021
Liabilities:
Physical forward commodity contracts		$	—		$	11,351		$	—	$	11,351
Financial derivative contracts - natural gas		23,715			39,959			—		63,674
Financial commodity contracts - foreign exchange		—			14			—		14
Other		616			—			—		616
Total liabilities at fair value		$	24,331		$	51,324		$	—	$	75,655

(1) Included in other noncurrent assets in the Unaudited Condensed Consolidated Balance Sheets.

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NATURE OF BUSINESS

6 Months Ended

Mar. 31, 2012

NATURE OF THE BUSINESS [Abstract]

Nature of Operations [Text Block]

NATURE OF THE BUSINESS

New Jersey Resources Corporation (NJR or the Company) provides regulated gas distribution services and certain non-regulated businesses primarily through the following subsidiaries:

New Jersey Natural Gas Company (NJNG) provides natural gas utility service to approximately 499,500 retail customers in central and northern New Jersey and is subject to rate regulation by the New Jersey Board of Public Utilities (BPU). NJNG comprises the Natural Gas Distribution segment;

NJR Energy Services Company (NJRES) 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 (NJRCEV) comprises the Clean Energy Ventures segment and reports the results of operations and assets related to the Company's capital investments in renewable energy projects, including commercial and residential solar projects;

NJR Energy Holdings Corporation (NJREH) primarily invests in energy-related ventures through its subsidiaries, NJNR Pipeline Company (Pipeline), which holds the Company's 5.53 percent ownership interest in Iroquois Gas Transmission L.P. (Iroquois), and NJR Steckman Ridge Storage Company, which holds the Company's 50 percent combined interest in Steckman Ridge GP, LLC and Steckman Ridge, LP (collectively, Steckman Ridge). Iroquois and Steckman Ridge comprise the Energy Holdings segment (previously Midstream Assets);

NJR Retail Holdings Corporation (Retail Holdings) has two principal subsidiaries, NJR Home Services Company (NJRHS) and Commercial Realty & Resources Corporation (CR&R). Retail Holdings and NJR Energy Corporation (NJR Energy) are included in Retail and Other operations.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Thousands, unless otherwise specified	3 Months Ended				6 Months Ended
	Mar. 31, 2012		Mar. 31, 2011		Mar. 31, 2012		Mar. 31, 2011
Net income	$ 54,535		$ 63,927		$ 111,892		$ 88,436
Unrealized gain on available for sale securities, net of tax of $ 575, $(266), $(25) and $(552), respectively	(833)	[1]	390	[1]	36	[1]	800	[1]
Net unrealized (loss) on derivatives, net of tax of $18, $(16), $41 and $(55), respectively	(30)		26		(70)		95
Adjustment to postemployment benefit obligation, net of tax of $(149), $0, $(299) and $0, respectively	219		0		438		0
Other comprehensive income (loss)	(644)		416		404		895
Comprehensive income	$ 53,891		$ 64,343		$ 112,296		$ 89,331

[1] Available for sale securities are included in other noncurrent assets in the Unaudited Condensed Consolidated Balance Sheets.

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COMMITMENTS AND CONTINGENT LIABILITIES

6 Months Ended

Mar. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies Disclosure [Text Block]

COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through November 2024, for the supply, storage and delivery of natural gas. These contracts include current annual fixed charges of approximately $96 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 five years. Demand charges are based on established rates as 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, 2012, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2012		2013		2014		2015		2016		Thereafter
NJRES:
Natural gas purchases	$	264,023	$	181,858	$	6,555	$	—	$	—	$	—
Storage demand fees	21,136		31,625		18,838		12,286		7,236		12,353
Pipeline demand fees	32,704		41,830		22,169		10,891		9,077		17,427
Sub-total NJRES	$	317,863	$	255,313	$	47,562	$	23,177	$	16,313	$	29,780
NJNG:
Natural gas purchases	$	19,877	$	1,096	$	—	$	—	$	—	$	—
Storage demand fees	15,666		30,070		25,123		15,888		11,088		33,245
Pipeline demand fees	27,164		76,776		73,150		35,213		31,578		201,838
Sub-total NJNG	$	62,707	$	107,942	$	98,273	$	51,101	$	42,666	$	235,083
Total (1)	$	380,570	$	363,255	$	145,835	$	74,278	$	58,979	$	264,863

(1) Does not include amounts related to intercompany asset management agreements between NJRES and NJNG.

NJNG's capital expenditures are estimated at $121.2 million and $70 million in fiscal 2012 and 2013, respectively, and consist primarily of its construction program to support customer growth, maintenance of its distribution system and replacement needed under pipeline safety regulations. Approximately $49.1 million has been committed or spent on capital expenditures, including accruals, during the six months endedMarch 31, 2012. The expected expenditures in fiscal 2012 include an estimate of $49.9 million related to AIP II. NJNG has committed or spent $14.9 million related to AIP II programs during the six months endedMarch 31, 2012.

The Company has entered into various agreements to install solar equipment involving both residential and commercial projects. Total solar-related capital expenditures during the six months endedMarch 31, 2012 were $61.8 million. The Company currently estimates solar-related capital expenditures of $82.6 million during fiscal 2012, of which $79.8 million has been committed or spent. Solar-related capital expenditures in fiscal 2013 are estimated to be $90 million. These investments are subject to a variety of factors, such as the identification of appropriate projects, the timing of construction schedules, the permitting and regulatory process and delays related to electric grid interconnection, which may affect our ability to commence operations at these projects on a timely basis or, at all.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of five manufactured gas plant (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 New Jersey Department of Environmental Protection (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. On January 18, 2012, the BPU approved the recovery of the remediation expenditures incurred through September 30, 2009, which maintained the expected annual recovery at approximately $20 million. As of March 31, 2012, $61.3 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.

In September 2011, NJNG updated 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 $161.5 million to $278.5 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. However, NJNG expects actual costs to differ from these estimates. 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, NJNG has recorded an MGP remediation liability and a corresponding regulatory asset of $182.9 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.

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Document and Entity Information	6 Months Ended
	Mar. 31, 2012	Apr. 30, 2012
Document Information [Line Items]
Entity Registrant Name	NEW JERSEY RESOURCES CORP
Entity Central Index Key	0000356309
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	Yes
Current Fiscal Year End Date	--09-30
Entity Common Stock, Shares Outstanding		41,551,934
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q2
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer

XML

BUSINESS SEGMENT AND OTHER OPERATIONS DATA

6 Months Ended

Mar. 31, 2012

Segment Reporting [Abstract]

Segment Reporting Disclosure [Text Block]

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 consist of capital investments in renewable energy projects; the Energy Holdings segment (previously Midstream Assets) consists of NJR's investments in natural gas transportation and storage facilities; the Retail and Other operations consist of appliance and installation services, commercial real estate development, renewable energy and 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)	2012			2011			2012			2011
Operating revenues
Natural Gas Distribution
External customers	$	226,023		$	433,248		$	417,397		$	723,924
Intercompany	—			—			—			—
Energy Services
External customers	378,356			535,987			820,162			950,418
Intercompany	2,654			37,088			2,848			53,431
Clean Energy Ventures
External customers	527			—			907			—
Segment subtotal	607,560			1,006,323			1,241,314			1,727,773
Retail and Other
External customers	8,014			7,751			16,866			15,796
Intercompany	263			75			442			156
Eliminations	(2,916		)	(37,162		)	(3,290		)	(53,586		)
Total	$	612,921		$	976,987		$	1,255,332		$	1,690,139
Depreciation and amortization
Natural Gas Distribution	$	8,749		$	8,235		$	17,381		$	16,458
Energy Services	16			15			32			31
Clean Energy Ventures	1,511			28			2,321			28
Energy Holdings	2			2			3			3
Segment subtotal	10,278			8,280			19,737			16,520
Retail and Other	161			197			302			411
Total	$	10,439		$	8,477		$	20,039		$	16,931
Interest income (1)
Natural Gas Distribution	$	214		$	280		$	460		$	540
Energy Services	(5		)	3			26			8
Energy Holdings	285			224			533			452
Segment subtotal	494			507			1,019			1,000
Retail and Other	1			1			1			1
Eliminations	(268		)	(217		)	(503		)	(438		)
Total	$	227		$	291		$	517		$	563

(1) Included in other income in the Unaudited Condensed Consolidated Statements of Operations.

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2012			2011			2012			2011
Interest expense, net of capitalized interest
Natural Gas Distribution	$	3,713		$	3,808		$	7,450		$	7,824
Energy Services	245			323			515			599
Clean Energy Ventures	198			3			340			7
Energy Holdings	683			817			1,397			1,625
Segment subtotal	4,839			4,951			9,702			10,055
Retail and Other	588			127			730			286
Total	$	5,427		$	5,078		$	10,432		$	10,341
Income tax provision (benefit)
Natural Gas Distribution	$	27,016		$	26,278		$	42,612		$	40,879
Energy Services	(2,105		)	7,525			9,403			6,683
Clean Energy Ventures	(14,826		)	(6,071		)	(26,997		)	(6,710		)
Energy Holdings	1,393			1,487			2,624			2,670
Segment subtotal	11,478			29,219			27,642			43,522
Retail and Other	(312		)	(588		)	(371		)	(1,044		)
Eliminations	(72		)	(19		)	(140		)	(13		)
Total	$	11,094		$	28,612		$	27,131		$	42,465
Equity in earnings of affiliates
Energy Holdings	$	3,967		$	4,360		$	7,582		$	7,980
Segment subtotal	3,967			4,360			7,582			7,980
Eliminations	(949		)	(750		)	(1,910		)	(1,453		)
Total	$	3,018		$	3,610		$	5,672		$	6,527
Net financial earnings (loss)
Natural Gas Distribution	$	44,936		$	44,040		$	70,910		$	68,396
Energy Services	15,871			16,001			23,486			19,168
Clean Energy Ventures	11,862			5,171			21,959			5,225
Energy Holdings	2,021			2,145			3,804			3,858
Segment subtotal	74,690			67,357			120,159			96,647
Retail and Other	(543		)	(328		)	(689		)	(488		)
Eliminations	(21		)	—			(36		)	—
Total	$	74,126		$	67,029		$	119,434		$	96,159
Capital expenditures
Natural Gas Distribution	$	27,427		$	18,988		$	49,145		$	47,186
Clean Energy Ventures	14,175			9,038			61,786			9,937
Segment subtotal	41,602			28,026			110,931			57,123
Retail and Other	370			1,717			459			1,963
Total	$	41,972		$	29,743		$	111,390		$	59,086

The chief operating decision maker of the Company is the Chief Executive Officer (CEO). The CEO uses net financial earnings as a measure of profit or loss in measuring the results of the Company's segments and operations. A reconciliation of consolidated net financial earnings to consolidated net income is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2012		2011		2012			2011
Consolidated net financial earnings	$	74,126	$	67,029	$	119,434		$	96,159
Less:
Unrealized loss (gain) from derivative instruments and related transactions, net of taxes (1)	7,664		2,306		(9,708		)	36,710
Effects of economic hedging related to natural gas inventory, net of taxes	11,927		796		17,250			(28,987		)
Consolidated net income	$	54,535	$	63,927	$	111,892		$	88,436

(1) Excludes unrealized losses related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $79,000 and $30,000, for the three months ended March 31, 2012 and March 31, 2011, respectively, and $197,000, and $32,000 for the six months endedMarch 31, 2012 and 2011, 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.

Net financial earnings 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 net financial earnings, current period unrealized gains and losses on the derivatives are excluded from net financial earnings as a reconciling item. Additionally, realized derivative gains and losses are also included in current period net income. However, net financial earnings include 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.

The Company's assets for the various business segments and business operations are detailed below:

(Thousands)	March 31, 2012			September 30, 2011
Assets at end of period:
Natural Gas Distribution	$	1,951,497		$	1,942,691
Energy Services	346,995			400,882
Clean Energy Ventures	166,478			80,234
Energy Holdings	157,987			159,940
Segment subtotal	2,622,957			2,583,747
Retail and Other	66,742			87,066
Intercompany assets (1)	(19,960		)	(21,369		)
Total	$	2,669,739		$	2,649,444

(1) Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parentheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Mar. 31, 2012	Mar. 31, 2011
Tax on Unrealized gain on available for sale securities	$ 575	$ (266)	$ (25)	$ (552)
Tax on Net unrealized gain (loss) on derivatives	18	(16)	41	(55)
Tax on adjustment for postemployment benefit obligation	$ (149)	$ 0	$ (299)	$ 0

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INVESTMENTS IN EQUITY INVESTEES

6 Months Ended

Mar. 31, 2012

Equity Method Investments and Joint Ventures [Abstract]

INVESTMENTS IN EQUITY INVESTEES [Table Text Block]

INVESTMENTS IN EQUITY INVESTEES

NJR uses the equity method of accounting for its investments in Steckman Ridge and Iroquois. Earnings or losses from equity method investments are included in Equity in earnings of affiliates in the Unaudited Condensed Consolidated Statements of Operations.

NJR's investments in equity investees include the following investments as of:

(Thousands)	March 31, 2012		September 30, 2011
Steckman Ridge	$	134,703	$	135,130
Iroquois	22,346		23,933
Total	$	157,049	$	159,063

As of March 31, 2012, the investment of 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 December 31, 2017.

NJRES and NJNG have entered into transportation, storage and park and loan agreements with Iroquois and Steckman Ridge. See Note 13. Related Party Transactions for more information on these affiliate transactions.

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FAIR VALUE

6 Months Ended

Mar. 31, 2012

Fair Value Disclosures [Abstract]

Fair Value Disclosures [Text Block]

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. The estimated fair value of long-term debt, including current maturities is as follows:

(Thousands)	March 31, 2012		September 30, 2011
Carrying value	$	437,567	$	434,372
Fair market value	$	478,010	$	471,022

Effective January 1, 2012, NJR changed its valuation technique from a market approach to an income approach. NJR considers the discounted cash flow method to provide a more consistently reliable fair value. Inputs include U.S. Treasury securities and credit spreads, both of which are observable inputs. Any adjustments to the measurement for duration, as applicable, are not considered to be significant, therefore, NJR classifies 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 contracts, listed equities, and money market funds.

Level 2 Price data, which includes both commodity and basis price data other than Level 1 quotes, 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. These additional adjustments are not considered 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.

NJNG's and NJRES' financial derivatives portfolios consist mainly of futures, options and swaps. NJR primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market, therefore, the primary source for its price inputs is the New York Mercantile (NYMEX) exchange. NJRES also uses Natural Gas Exchange (NGX) for Canadian delivery points and Platts and NYMEX ClearPort for certain over-the-counter physical forward commodity contracts. However, NJRES also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the cost to transport to the final delivery location is not significant to the overall valuation. If required, NJRES' policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or pricing services.

NJR also has available for sale securities and other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When NJR determines fair values, measurements are adjusted, as needed, for credit risk associated with its counterparties, as well as its own credit risk. NJR determines these adjustments by using historical default probabilities that correspond to the applicable Standard and Poor's issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.

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, 2012:
Assets:
Physical forward commodity contracts		$	—		$	22,119		$	—	$	22,119
Financial derivative contracts - natural gas		47,212			37,288			—		84,500
Financial commodity contracts - foreign exchange		—			220			—		220
Available for sale equity securities - energy industry (1)		10,408			—			—		10,408
Other		3,865			—			—		3,865
Total assets at fair value		$	61,485		$	59,627		$	—	$	121,112
Liabilities:
Physical forward commodity contracts		$	—		$	11,754		$	—	$	11,754
Financial commodity contracts - natural gas		61,351			22,609			—		83,960
Financial commodity contracts - foreign exchange		—			65			—		65
Other		729			—			—		729
Total liabilities at fair value		$	62,080		$	34,428		$	—	$	96,508
As of September 30, 2011:
Assets:
Physical forward commodity contracts		$	—		$	37,690		$	—	$	37,690
Financial derivative contracts - natural gas		25,617			43,266			—		68,883
Financial commodity contracts - foreign exchange		—			280					280
Available for sale equity securities - energy industry(1)		10,348			—			—		10,348
Other		2,820			—			—		2,820
Total assets at fair value		$	38,785		$	81,236		$	—	$	120,021
Liabilities:
Physical forward commodity contracts		$	—		$	11,351		$	—	$	11,351
Financial derivative contracts - natural gas		23,715			39,959			—		63,674
Financial commodity contracts - foreign exchange		—			14			—		14
Other		616			—			—		616
Total liabilities at fair value		$	24,331		$	51,324		$	—	$	75,655

(1) Included in other noncurrent assets in the Unaudited Condensed Consolidated Balance Sheets.

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DERIVATIVE INSTRUMENTS (Tables)

6 Months Ended

Mar. 31, 2012

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Text Block]

The following table reflects the fair value of NJR's derivative assets and liabilities recognized in the Unaudited Condensed Consolidated Balance Sheets as of:

			Fair Value
			March 31, 2012						September 30, 2011
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	127		$	22		$	153		$	8
	Derivatives - noncurrent		93			43			127			6
Fair value of derivatives designated as hedging instruments			$	220		$	65		$	280		$	14
Derivatives not designated as hedging instruments:
NJNG:
Financial commodity contracts	Derivatives - current		$	6,049		$	49,717		$	5,424		$	13,258
	Derivatives - noncurrent		163			—			2			620
NJRES:
Physical forward commodity contracts	Derivatives - current		21,541			11,150			33,240			10,570
	Derivatives - noncurrent		578			604			4,450			781
Financial commodity contracts	Derivatives - current		75,789			31,139			61,521			44,862
	Derivatives - noncurrent		2,499			3,104			1,936			4,934
Fair value of derivatives not designated as hedging instruments			$	106,619		$	95,714		$	106,573		$	75,025
Total fair value of derivatives			$	106,839		$	95,779		$	106,853		$	75,039

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]

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:		2012		2011			2012			2011
NJRES:
Physical commodity contracts	Operating revenues	$	8,745	$	41,306		$	(3,163	)	$	24,837
Physical commodity contracts	Gas purchases	116		(9,448		)	4,391			(5,739		)
Financial commodity contracts	Gas purchases	40,511		496			102,965			(27,775		)
Total unrealized and realized gains (losses)		$	49,372	$	32,354		$	104,193		$	(8,677	)

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Text Block]

The following table reflect the effect of derivative instruments designated as cash flow hedges on OCI as of:

(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:	2012			2011		2012			2011			2012		2011
Foreign currency contracts	$	(25	)	$	42	$	(23	)	$	(50	)	$	—	$	—

(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:	2012			2011		2012			2011			2012		2011
Foreign currency contracts	$	(75	)	$	161	$	(35	)	$	(59	)	$	—	$	—

(1) The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $105,000 from OCI into earnings. The maximum tenor is April 2015

Schedule of Derivative Instruments [Text Block]

NJNG and NJRES had the following outstanding long (short) derivatives as of:

		Volume (Bcf)
		March 31, 2012		September 30, 2011
NJNG	Futures	14.8		23.7
	Swaps	3.3		(1.8	)
	Options	2.4		1.1
NJRES	Futures	(26.0	)	(13.8	)
	Swaps	(0.7	)	(41.9	)
	Options	—		—
	Physical	24.6		58.3

Schedule of Due to (from) Broker-Dealers and Clearing Organizations [Text Block]

The Company maintains broker margin accounts for NJNG and NJRES. The balances by company, are as follows:

(Thousands)	Balance Sheet Location	March 31, 2012			September 30, 2011
NJNG	Broker margin - Current assets	$	46,361		$	11,722
NJRES	Broker margin - Current assets	$	20,154		$	10,873
NJRES	Broker margin - Current (liabilities)	$	(29,671	)	$	—

Schedules of Concentration of Risk, by Risk Factor [Table Text Block]

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		$	107,085
Noninvestment grade		21,457
Internally rated investment grade		25,580
Internally rated noninvestment grade		7,451
Total		$	161,573

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RELATED PARTY TRANSACTIONS

6 Months Ended

Mar. 31, 2012

Related Party Transactions [Abstract]

Related Party Transactions Disclosure [Text Block]

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 Gas Transmission. As of March 31, 2012, NJRES has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which expire by October 2012. Additionally, NJRES has transportation capacity with Iroquois Gas Transmission that expires by March 2019. Demand fees associated with both Steckman Ridge and Iroquois Gas Transmission were $2.1 million and $4.1 million during the three and six months endedMarch 31, 2012, respectively. As of March 31, 2012, NJRES had fees payable of $238,000 and $392,000 to Steckman Ridge and Iroquois Gas Transmission, respectively.

In January 2010, NJNG entered into a ten-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. These fees are recoverable through NJNG's BGSS mechanism. Additionally, NJNG has transportation capacity with Iroquois Gas Transmission that expires by January 2019. Demand fees associated with both Steckman Ridge and Iroquois Gas Transmission were $1.9 million and $4 million during the three and six months endedMarch 31, 2012, respectively. As of March 31, 2012, NJNG had fees payable (receivable) to Steckman Ridge and Iroquois Gas Transmission in the amount of $775,000 and $(146,000), respectively.

In December 2009, NJNG and NJRES entered into an asset management agreement that began in January 2010 and ends in March 2013. 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 another asset management agreement that began in September 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.

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EMPLOYEE BENEFIT PLANS

6 Months Ended

Mar. 31, 2012

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans (OPEB)

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)	2012			2011			2012			2011			2012			2011			2012			2011
Service cost	$	1,344		$	1,194		$	2,688		$	2,388		$	896		$	836		$	1,792		$	1,672
Interest cost	2,206			2,095			4,412			4,189			1,283			1,212			2,566			2,423
Expected return on plan assets	(3,171		)	(2,873		)	(6,342		)	(5,745		)	(686		)	(618		)	(1,372		)	(1,236		)
Recognized actuarial loss	1,254			987			2,508			1,973			724			653			1,448			1,306
Prior service cost amortization	11			12			22			24			6			19			12			38
Recognized net initial obligation	—			—			—			—			89			89			178			178
Net periodic benefit cost	$	1,644		$	1,415		$	3,288		$	2,829		$	2,312		$	2,191		$	4,624		$	4,381

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 in December 2011.

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EARNINGS PER SHARE

6 Months Ended

Mar. 31, 2012

Earnings Per Share [Abstract]

Earnings Per Share [Text Block]

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)	2012		2011		2012		2011
Net income , as reported	$	54,535	$	63,927	$	111,892	$	88,436
Basic earnings per share
Weighted average shares of common stock outstanding-basic	41,509		41,352		41,472		41,316
Basic earnings per common share	$1.31		$1.55		$2.70		$2.14
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	41,509		41,352		41,472		41,316
Incremental shares (1)	202		201		201		200
Weighted average shares of common stock outstanding-diluted	41,711		41,553		41,673		41,516
Diluted earnings per common share (2)	$1.31		$1.54		$2.68		$2.13

(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 endedMarch 31, 2012 and 2011.

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DEBT

6 Months Ended

Mar. 31, 2012

Debt Disclosure [Abstract]

Debt Disclosure [Text Block]

DEBT

NJR and NJNG finance working capital requirements and capital expenditures through the issuance of various long-term debt and other financing arrangements, including unsecured credit 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.

A summary of NJR's and NJNG's debt shelf and credit facilities are as follows:

(Thousands)	March 31, 2012			September 30, 2011			Maturity Dates
NJR
Debt shelf facilities (1) (2) (3)	$	175,000		$	175,000		Various (3)
Bank credit facilities(4)	$	325,000		$	325,000		December 2012
Notes payable outstanding at end of period	$	157,300		$	132,850
Weighted average interest rate at end of period	0.53		%	0.54		%
Amount available at end of period	$	155,453		$	157,853
NJNG
Bank credit facility dedicated to EDA Bonds (2) (4)	$	100,000		$	100,000		August 2015
Bank credit facilities (4)	$	200,000		$	200,000		August 2014
Commercial paper outstanding at end of period	$	34,000		$	26,500
Weighted average interest rate at end of period	0.16		%	0.24		%
Amount available at end of period	$	166,000		$	173,500

(1) Uncommitted, long-term debt shelf facilities, which require no commitment fees on the unused amounts.

(2) There were no borrowings outstanding as of March 31, 2012 and September 30, 2011, respectively.

(3) $100 million debt shelf expires May 2013 and $75 million debt shelf expires June 2014.

(4) Committed credit facilities, which require commitment fees on the unused amounts.

Other

NJNG received $6.5 million and $5.9 million in December 2011 and 2010, respectively, in connection with the sale-leaseback of its natural gas meters. This sale-leaseback program is expected to continue on an annual basis.

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INCOME TAXES

6 Months Ended

Mar. 31, 2012

Income Tax Disclosure [Abstract]

Income Tax Disclosure [Text Block]

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 endedMarch 31, 2012 and 2011, 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 endedMarch 31, 2012 and 2011, are 19.5 percent and 32.4 percent, respectively. The decrease in the rate is due primarily to federal investment tax credits (ITC) of $24.9 million and $6.1 million, generated by NJRCEV's solar investments placed into service in the six months endedMarch 31, 2012 and 2011, respectively, and solar investments forecasted to be completed before the end of the fiscal year.

To calculate the estimated annual effective tax rate, NJR considers projects that are probable of being completed and available for use 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 and interconnection. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

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REGULATION, REGULATORY ASSETS AND LIABILITIES (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Sep. 30, 2011
Regulatory Assets And Liabilities [Line Items]
Regulatory assets current	$ 80,920	$ 17,630
Regulatory assets noncurrent	410,901	434,185
Regulatory liability current	0	4,633
Regulatory liability noncurrent	63,391	59,837
Overrecovered gas costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liability current	0	4,633
Cost of removal obligation [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liability noncurrent	63,133	59,752
Other [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liability noncurrent	258	85
Underrecovered gas costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets current	16,544	0
Conservation Incentive Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets current	20,871	9,178
Derivatives, net [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets current	43,505	8,452
Enviromental remediation costs expended, net of recoveries [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets noncurrent	61,259	75,646
Enviromental remediation costs liability for future expenditures [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets noncurrent	182,900	182,900
Deferred income and other taxes [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets noncurrent	10,879	10,879
Energy Efficiency Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets noncurrent	17,913	11,906
New Jersey Clean Energy Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets noncurrent	13,522	20,144
Post Employment Benefit Costs (Note 10) [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets noncurrent	120,247	123,827
Other [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets noncurrent	$ 4,181	$ 8,883

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COMMITMENTS AND CONTINGENT LIABILITIES, CAPITAL EXPENDITURES (Details) (USD $)	6 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Long-term Purchase Commitment [Line Items]
Payments to Acquire Other Productive Assets	$ 61,786,000	$ 11,533,000
Solar Related Expenditures [Member]
Long-term Purchase Commitment [Line Items]
Estimated Capital Expenditures	82,600,000
Estimated Capital Expenditures Subsequent Fiscal Year	90,000,000
Payments to Acquire Productive Assets	61,800,000
Capital Expenditures Paid and Committed	79,800,000
Gas Distribution [Member]
Long-term Purchase Commitment [Line Items]
Estimated Capital Expenditures	121,200,000
Estimated Capital Expenditures Subsequent Fiscal Year	70,000,000
Capital Expenditures Paid And Accrued	49,100,000
AIP II Construction Costs [Member]
Long-term Purchase Commitment [Line Items]
Estimated Capital Expenditures	49,900,000
Capital Expenditures Paid And Accrued	$ 14,900,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

6 Months Ended

Mar. 31, 2012

Accounting Policies [Abstract]

Schedule of Utility Inventory [Table Text Block]

The following table summarizes gas in storage, at average cost by company as of:

	March 31, 2012				September 30, 2011
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJNG		$	67,104	10.7		$	159,328	23.1
NJRES		108,105		41.9		135,147		36.8
Total		$	175,209	52.6		$	294,475	59.9

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EARNINGS PER SHARE (Tables)

6 Months Ended

Mar. 31, 2012

Earnings Per Share [Abstract]

Schedule of Earnings Per Share Basic and Diluted Table [Text Block]

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)	2012		2011		2012		2011
Net income , as reported	$	54,535	$	63,927	$	111,892	$	88,436
Basic earnings per share
Weighted average shares of common stock outstanding-basic	41,509		41,352		41,472		41,316
Basic earnings per common share	$1.31		$1.55		$2.70		$2.14
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	41,509		41,352		41,472		41,316
Incremental shares (1)	202		201		201		200
Weighted average shares of common stock outstanding-diluted	41,711		41,553		41,673		41,516
Diluted earnings per common share (2)	$1.31		$1.54		$2.68		$2.13

(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 endedMarch 31, 2012 and 2011.

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INCOME TAXES Income Tax (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Income Tax Disclosure [Abstract]
Effective income tax rate	19.50%	32.40%
Income Tax Reconciliation, Tax Credits, Investment	$ 24.9	$ 6.1

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FAIR VALUE, DEBT (Details) (Fair Value, Inputs, Level 2 [Member], USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Sep. 30, 2011
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 437,567	$ 434,372
Estimate of Fair Value, Fair Value Disclosure [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 478,010	$ 471,022

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CONSOLIDATED STATEMENT OF CASH FLOWS (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 111,892	$ 88,436
Adjustments to reconcile net income to cash flows from operating activities:
Unrealized (gain) loss on derivative instruments	(15,353)	58,049
Depreciation and amortization	20,039	17,369
Allowance for equity used during construction	(139)	(499)
Allowance for bad debt expense	1,586	2,572
Deferred income taxes	20,920	(6,374)
Manufactured gas plant remediation costs	(4,964)	(5,727)
Equity in earnings of affiliates, net of distributions received	3,852	(13)
Cost of removal - asset retirement obligations	(368)	(456)
Contributions to postemployment benefit plans	(22,982)	(8,068)
Changes in:
Components of working capital	(31,567)	9,862
Other noncurrent assets	11,690	16,234
Other noncurrent liabilities	10,018	9,624
Cash flows from operating activities	104,624	181,009
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Utility plant expenditures	(42,380)	(43,581)
Solar equipment expenditures	(61,786)	(11,533)
Real estate properties and other expenditures	(459)	(367)
Cost of removal expenditures	(6,765)	(3,605)
Withdrawal from restricted cash construction fund	136	38
Cash flows (used in) investing activities	(111,254)	(59,048)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Proceeds from issuance of common stock	7,164	7,297
Tax benefit from stock options exercised	222	347
Proceeds from sale-leaseback transaction	6,522	5,901
Payments of long-term debt	(3,371)	(23,919)
Purchases of treasury stock	(4,800)	(7,222)
Payments of common stock dividends	(30,695)	(28,917)
Net proceeds from short-term debt	31,950	0
Cash flows from (used in) financing activities	6,992	(46,513)
Change in cash and cash equivalents	362	75,448
Cash and temporary investments at beginning of period	7,440	943
Cash and temporary investments at end of period	7,802	76,391
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	19,773	(106,839)
Inventories	118,920	141,246
Recovery of gas costs	(21,177)	28,309
Gas purchases payable	(80,941)	(1,285)
Prepaid and accrued taxes	47,025	78,809
Accounts payable and other	(4,573)	(3,414)
Restricted broker margin accounts	(14,249)	(48,713)
Customers' credit balances and deposits	(82,321)	(77,917)
Other current assets	(14,024)	(334)
Components of working capital	(31,567)	9,862
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for Interest (net of amounts capitalized)	8,324	9,172
Cash paid for Income taxes	814	4,047
Accrued Capital Expenditures	$ 5,041	$ (3,472)

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DERIVATIVE INSTRUMENTS

6 Months Ended

Mar. 31, 2012

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities Disclosure [Text Block]

DERIVATIVE INSTRUMENTS

The Company and certain of its subsidiaries are subject to commodity price risk due to fluctuations in the market price of natural gas. To manage this risk, the Company and certain of its subsidiaries enter 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. 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 in 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, changes in the fair value of these derivative instruments are recorded as a component of gas purchases or operating revenues, as appropriate for NJRES, in 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. 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 other comprehensive income (OCI). When the foreign exchange contracts are settled, realized gains and (losses) are recognized in gas purchases in 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 potential 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 in 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 in 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.

The Company elects normal purchase/normal sale 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 earnings when the contract settles and the natural gas is delivered.

Fair Value of Derivatives

The following table reflects the fair value of NJR's derivative assets and liabilities recognized in the Unaudited Condensed Consolidated Balance Sheets as of:

			Fair Value
			March 31, 2012						September 30, 2011
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	127		$	22		$	153		$	8
	Derivatives - noncurrent		93			43			127			6
Fair value of derivatives designated as hedging instruments			$	220		$	65		$	280		$	14
Derivatives not designated as hedging instruments:
NJNG:
Financial commodity contracts	Derivatives - current		$	6,049		$	49,717		$	5,424		$	13,258
	Derivatives - noncurrent		163			—			2			620
NJRES:
Physical forward commodity contracts	Derivatives - current		21,541			11,150			33,240			10,570
	Derivatives - noncurrent		578			604			4,450			781
Financial commodity contracts	Derivatives - current		75,789			31,139			61,521			44,862
	Derivatives - noncurrent		2,499			3,104			1,936			4,934
Fair value of derivatives not designated as hedging instruments			$	106,619		$	95,714		$	106,573		$	75,025
Total fair value of derivatives			$	106,839		$	95,779		$	106,853		$	75,039

At March 31, 2012, the gross notional amount of the foreign currency transactions was approximately $11.5 million, and ineffectiveness in the hedge relationship is immaterial to the financial results of NJR.

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:		2012		2011			2012			2011
NJRES:
Physical commodity contracts	Operating revenues	$	8,745	$	41,306		$	(3,163	)	$	24,837
Physical commodity contracts	Gas purchases	116		(9,448		)	4,391			(5,739		)
Financial commodity contracts	Gas purchases	40,511		496			102,965			(27,775		)
Total unrealized and realized gains (losses)		$	49,372	$	32,354		$	104,193		$	(8,677	)

Not included in the previous table, are (losses) associated with NJNG's financial derivatives that totaled $(15.4) million and $(2.2) million for the three months endedMarch 31, 2012 and 2011, respectively and $(35.3) million and $(4.9) million for the six months endedMarch 31, 2012 and 2011, respectively. These derivatives are part of its risk management activities that relate to its natural gas purchasing activities 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 and there is 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 in the Unaudited Condensed Consolidated Statements of Operations. The following table reflect the effect of derivative instruments designated as cash flow hedges on OCI as of:

(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:	2012			2011		2012			2011			2012		2011
Foreign currency contracts	$	(25	)	$	42	$	(23	)	$	(50	)	$	—	$	—

(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:	2012			2011		2012			2011			2012		2011
Foreign currency contracts	$	(75	)	$	161	$	(35	)	$	(59	)	$	—	$	—

(1) The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $105,000 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, 2012		September 30, 2011
NJNG	Futures	14.8		23.7
	Swaps	3.3		(1.8	)
	Options	2.4		1.1
NJRES	Futures	(26.0	)	(13.8	)
	Swaps	(0.7	)	(41.9	)
	Options	—		—
	Physical	24.6		58.3

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 broker margin accounts for NJNG and NJRES. The balances by company, are as follows:

(Thousands)	Balance Sheet Location	March 31, 2012			September 30, 2011
NJNG	Broker margin - Current assets	$	46,361		$	11,722
NJRES	Broker margin - Current assets	$	20,154		$	10,873
NJRES	Broker margin - Current (liabilities)	$	(29,671	)	$	—

Wholesale Credit Risk

NJNG and NJRES are exposed to credit risk as a result of their wholesale marketing activities. As a result of the inherent volatility in the prices of natural gas commodities and derivatives, 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 the International Swaps and Derivatives Association (ISDA) and the North American Energy Standards Board (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, 2012. Internally-rated exposure applies to counterparties that are not rated by Standard & Poor's (S&P) or Moody's Investors Service, Inc. (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		$	107,085
Noninvestment grade		21,457
Internally rated investment grade		25,580
Internally rated noninvestment grade		7,451
Total		$	161,573

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, 2012 and September 30, 2011, was $2.6 million and $4.1 million, respectively, for which the Company had not posted any collateral. If all the thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on March 31, 2012 and September 30, 2011, the Company would have been required to post an additional $2.2 million and $1.7 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected in 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.

Liquidation of Clearing Broker

MF Global Inc. (MFGI) and MF Global UK Limited (UKMF), which operated as futures commission merchants and broker/dealer entities of MF Global Holdings Ltd. (collectively with its affiliates, MF Global), were NJRES' clearing brokers through which NJRES held positions in energy futures contracts, options on futures contracts, and swaps cleared on exchanges administered by the Chicago Mercantile Exchange (CME) and the Intercontinental Exchange (ICE). The CME and ICE both require NJRES to maintain adequate margin against NJRES' trading positions, which our former clearing brokers, MFGI and UKMF, were required to hold on our behalf in segregated or secured accounts. MF Global disclosed to the CME that it had a “significant shortfall” in its segregated customer accounts. Shortly thereafter, on October 31, 2011, the Securities Investor Protection Corporation announced that it had initiated the liquidation of MFGI under the Securities Investor Protection Act (SIPA) in the U.S. and the High Court in the U.K. appointed special administrators to conduct the liquidation of UKMF. The SIPA Trustee's latest estimate of the shortfall in commodities customers' segregated account funds is $1.6 billion.

As of the close of business on November 3, 2011, the market value of NJRES' MF Global account was $27.8 million, of which $10.6 million related to CME positions and $17.2 million related to ICE positions. To date, NJRES has received distributions from the SIPA Trustee totaling$7.6 million related to its CME positions. Accordingly, the remaining exposure as of March 31, 2012, is $20.2 million.

NJRES has filed claims in both the MFGI and UKMF liquidation proceedings and intends to vigorously prosecute those claims to recover all of its funds, but it cannot estimate at this time, either how much of those funds will be recovered or when they will be recovered.

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DEBT (Tables)

6 Months Ended

Mar. 31, 2012

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities [Table Text Block]

A summary of NJR's and NJNG's debt shelf and credit facilities are as follows:

(Thousands)	March 31, 2012			September 30, 2011			Maturity Dates
NJR
Debt shelf facilities (1) (2) (3)	$	175,000		$	175,000		Various (3)
Bank credit facilities(4)	$	325,000		$	325,000		December 2012
Notes payable outstanding at end of period	$	157,300		$	132,850
Weighted average interest rate at end of period	0.53		%	0.54		%
Amount available at end of period	$	155,453		$	157,853
NJNG
Bank credit facility dedicated to EDA Bonds (2) (4)	$	100,000		$	100,000		August 2015
Bank credit facilities (4)	$	200,000		$	200,000		August 2014
Commercial paper outstanding at end of period	$	34,000		$	26,500
Weighted average interest rate at end of period	0.16		%	0.24		%
Amount available at end of period	$	166,000		$	173,500

(1) Uncommitted, long-term debt shelf facilities, which require no commitment fees on the unused amounts.

(2) There were no borrowings outstanding as of March 31, 2012 and September 30, 2011, respectively.

(3) $100 million debt shelf expires May 2013 and $75 million debt shelf expires June 2014.

(4) Committed credit facilities, which require commitment fees on the unused amounts.

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DERIVATIVE INSTRUMENTS, VOLUME (Details)	Mar. 31, 2012 MMcf	Sep. 30, 2011 MMcf
NJNG [Member] | Future [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	14,800	23,700
NJNG [Member] | Swap [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	3,300
NJNG [Member] | Swap [Member] | Short Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount		1,800
NJNG [Member] | Options Held [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	2,400	1,100
NJRES [Member] | Future [Member] | Short Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	26,000	13,800
NJRES [Member] | Swap [Member] | Short Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700	41,900
NJRES [Member] | Options Held [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0	0
NJRES [Member] | Physical [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	24,600	58,300

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Mar. 31, 2012

Accounting Policies [Abstract]

Derivatives, Policy [Text Block]

The Company and certain of its subsidiaries are subject to commodity price risk due to fluctuations in the market price of natural gas. To manage this risk, the Company and certain of its subsidiaries enter 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. 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 in 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, changes in the fair value of these derivative instruments are recorded as a component of gas purchases or operating revenues, as appropriate for NJRES, in 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. 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 other comprehensive income (OCI). When the foreign exchange contracts are settled, realized gains and (losses) are recognized in gas purchases in 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 potential 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 in 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 in 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.

The Company elects normal purchase/normal sale 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 earnings when the contract settles and the natural gas is delivered.

Marketable Securities, Available-for-sale Securities, Policy [Policy Text Block]

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 $10.4 million and $10.3 million as of March 31, 2012 and September 30, 2011, 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 $7.7 million ($4.6 million, after tax) and $7.7 million ($4.5 million, after tax) as of March 31, 2012 and September 30, 2011, respectively.

Fair Value of Financial Instruments, Policy [Policy Text Block]

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 contracts, listed equities, and money market funds.

Level 2 Price data, which includes both commodity and basis price data other than Level 1 quotes, 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. These additional adjustments are not considered 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.

NJNG's and NJRES' financial derivatives portfolios consist mainly of futures, options and swaps. NJR primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market, therefore, the primary source for its price inputs is the New York Mercantile (NYMEX) exchange. NJRES also uses Natural Gas Exchange (NGX) for Canadian delivery points and Platts and NYMEX ClearPort for certain over-the-counter physical forward commodity contracts. However, NJRES also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the cost to transport to the final delivery location is not significant to the overall valuation. If required, NJRES' policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or pricing services.

NJR also has available for sale securities and other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When NJR determines fair values, measurements are adjusted, as needed, for credit risk associated with its counterparties, as well as its own credit risk. NJR determines these adjustments by using historical default probabilities that correspond to the applicable Standard and Poor's issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.