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 JUNE 30, 2013

OR

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

SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM             TO
Commission file number 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 August 5, 2013 was 41,380,558.

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	8
		Note 4. Derivative Instruments	10
		Note 5. Fair Value	14
		Note 6. Investments in Equity Investees	15
		Note 7. Earnings Per Share	16
		Note 8. Debt	16
		Note 9. Employee Benefit Plans	18
		Note 10. Income Taxes	18
		Note 11. Commitments and Contingent Liabilities	18
		Note 12. Business Segment and Other Operations Data	20
		Note 13. Related Party Transactions	24
	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	24
	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	48
	ITEM 4.	Controls and Procedures	50
PART II. OTHER INFORMATION
	ITEM 1.	Legal Proceedings	51
	ITEM 1A.	Risk Factors	51
	ITEM 2.	Unregistered Sale of Equity Securities and Use of Proceeds	51
	ITEM 6.	Exhibits	52
		Signatures	53

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 2013 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 2012 Annual Report on Form 10-K and Part II, Item 1A of NJR's Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2013, 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 Basic Gas Supply Service (BGSS) 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 potential downturns in the financial markets, lower discount rates or 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;

• 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 renewable energy projects and our investment in an on-shore wind developer, 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 (including those related to restoration efforts resulting from Post Tropical Cyclone Sandy, commonly referred to as Superstorm Sandy) 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, including a work stoppage;

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

• the possible expiration of the NJNG Conservation Incentive Program (CIP);

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

• environmental-related and other litigation and other uncertainties;

• risks related to cyber-attack or failure of information technology systems; and

• the impact of natural disasters, terrorist activities, and other extreme events on our operations and customers, including any impacts to utility gross margin and restoration costs resulting from Superstorm Sandy.

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					Nine Months Ended
	June 30,					June 30,
(Thousands, except per share data)	2013		2012			2013		2012
OPERATING REVENUES
Utility	$	119,022	$	106,764		$	689,621	$	524,161
Nonutility	648,447		318,357			1,774,752		1,156,292
Total operating revenues	767,469		425,121			2,464,373		1,680,453
OPERATING EXPENSES
Gas purchases:
Utility	55,708		45,916			356,069		209,847
Nonutility	593,534		333,402			1,660,528		1,121,874
Operation and maintenance	43,630		40,857			126,767		118,987
Regulatory rider expenses	6,258		5,835			44,014		36,821
Depreciation and amortization	11,942		10,687			34,966		30,726
Energy and other taxes	9,397		8,335			50,869		39,202
Total operating expenses	720,469		445,032			2,273,213		1,557,457
OPERATING INCOME (LOSS)	47,000		(19,911		)	191,160		122,996
Other income	1,238		551			4,284		1,427
Interest expense, net of capitalized interest	6,008		4,834			17,579		15,266
INCOME (LOSS) BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	42,230		(24,194		)	177,865		109,157
Income tax provision (benefit)	15,297		(11,230		)	51,342		15,901
Equity in earnings of affiliates	2,222		2,644			8,307		8,316
NET INCOME (LOSS)	$	29,155	$	(10,320	)	$	134,830	$	101,572
EARNINGS (LOSS) PER COMMON SHARE
BASIC	$0.70		$(0.25)			$3.23		$2.45
DILUTED	$0.70		$(0.25)			$3.22		$2.44
DIVIDENDS PER COMMON SHARE	$0.40		$0.38			$1.20		$1.14
WEIGHTED AVERAGE SHARES OUTSTANDING
BASIC	41,608		41,560			41,697		41,501
DILUTED	41,732		41,560			41,820		41,643

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Net income (loss)	$	29,155		$	(10,320	)	$	134,830		$	101,572
Other comprehensive income, net of tax
Unrealized gain on available for sale securities, net of tax of $(9), $(79), $(235) and $(104), respectively	$	13		$	114		$	340		$	150
Net unrealized (loss) on derivatives, net of tax of $13, $8, $23 and $49, respectively	(22		)	(14		)	(39		)	(84		)
Adjustment to postemployment benefit obligation, net of tax of $(203), $(149), $(608) and $(448), respectively	296			220			1,005			658
Other comprehensive income	$	287		$	320		$	1,306		$	724
Comprehensive income (loss)	$	29,442		$	(10,000	)	$	136,136		$	102,296

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)

	Nine Months Ended
	June 30,
(Thousands)	2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	134,830		$	101,572
Adjustments to reconcile net income to cash flows from operating activities:
Unrealized (gain) loss on derivative instruments	(23,683		)	17,596
Depreciation and amortization	34,966			30,726
Allowance for equity used during construction	(1,926		)	(317		)
Allowance for bad debt expense	1,829			1,989
Deferred income taxes	23,406			30,588
Manufactured gas plant remediation costs	(5,326		)	(6,125		)
Equity in earnings of affiliates, net of distributions received	(1,050		)	4,209
Cost of removal - asset retirement obligations	(926		)	(912		)
Contributions to postemployment benefit plans	(24,538		)	(24,446		)
Changes in:
Components of working capital	(22,092		)	(110,114		)
Other noncurrent assets	(2,607		)	8,747
Other noncurrent liabilities	12,256			6,404
Cash flows from operating activities	125,139			59,917
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Expenditures for
Utility plant	(73,654		)	(71,916		)
Solar equipment	(39,756		)	(75,243		)
Real estate properties and other	(532		)	(568		)
Cost of removal	(21,186		)	(10,634		)
Distribution from equity investees	2,107			—
Proceeds from sale of available-for-sale securities	482			—
Withdrawal from restricted cash construction fund	—			126
Cash flows (used in) investing activities	(132,539		)	(158,235		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common stock	10,581			10,636
Tax benefit from stock options exercised	110			222
Proceeds from sale-leaseback transaction	7,076			6,522
Proceeds from long-term debt	50,000			—
Payments of long-term debt	(5,808		)	(4,856		)
Purchases of treasury stock	(23,689		)	(8,768		)
Payments of common stock dividends	(50,619		)	(46,466		)
Net proceeds from short-term debt	17,100			140,650
Cash flows from financing activities	4,751			97,940
Change in cash and cash equivalents	(2,649		)	(378		)
Cash and cash equivalents at beginning of period	4,509			7,440
Cash and cash equivalents at end of period	$	1,860		$	7,062
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	(120,719	)	$	36,598
Inventories	(24,792		)	78,601
Recovery of gas costs	4,994			(13,405		)
Gas purchases payable	86,932			(99,173		)
Prepaid and accrued taxes	20,059			(11,375		)
Accounts payable and other	(6,385		)	9,754
Restricted broker margin accounts	26,760			(20,320		)
Customers' credit balances and deposits	(30,899		)	(75,318		)
Other current assets	21,958			(15,476		)
Total	$	(22,092	)	$	(110,114	)
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for:
Interest (net of amounts capitalized)	$	11,121		$	8,918
Income taxes	$	9,539		$	7,536
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING ACTIVITIES
Accrued capital expenditures	$	(9,734	)	$	(108	)

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)	June 30, 2013			September 30, 2012
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	1,637,084		$	1,591,532
Construction work in progress	120,881			102,420
Solar equipment, real estate properties and other, at cost	230,580			192,026
Construction work in progress	5,508			20,558
Total property, plant and equipment	1,994,053			1,906,536
Accumulated depreciation and amortization	(408,746		)	(421,659		)
Property, plant and equipment, net	1,585,307			1,484,877
CURRENT ASSETS
Cash and cash equivalents	1,860			4,509
Customer accounts receivable
Billed	290,364			170,543
Unbilled revenues	6,956			7,017
Allowance for doubtful accounts	(5,667		)	(4,797		)
Regulatory assets	21,013			32,734
Gas in storage, at average cost	280,118			265,193
Materials and supplies, at average cost	17,730			7,863
Prepaid and accrued taxes	25,863			32,029
Asset held for sale	5,421			—
Derivatives, at fair value	65,478			48,021
Restricted broker margin accounts	1,350			21,929
Deferred taxes	22,033			29,074
Other	17,752			33,229
Total current assets	750,271			647,344
NONCURRENT ASSETS
Investments in equity investees	163,430			164,595
Regulatory assets	460,232			441,263
Derivatives, at fair value	1,720			2,328
Other	30,235			29,598
Total noncurrent assets	655,617			637,784
Total assets	$	2,991,195		$	2,770,005

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)	June 30, 2013		September 30, 2012
CAPITALIZATION
Common stock equity	$	892,356	$	813,865
Long-term debt	516,173		525,169
Total capitalization	1,408,529		1,339,034
CURRENT LIABILITIES
Current maturities of long-term debt	68,492		7,760
Short-term debt	296,900		279,800
Gas purchases payable	269,346		182,414
Accounts payable and other	50,395		66,765
Dividends payable	16,579		16,648
Deferred and accrued taxes	15,705		2,072
Regulatory liabilities	1,191		1,169
New Jersey clean energy program	16,953		5,619
Derivatives, at fair value	36,211		42,440
Restricted broker margin accounts	6,181		—
Customers' credit balances and deposits	17,553		48,452
Total current liabilities	795,506		653,139
NONCURRENT LIABILITIES
Deferred income taxes	370,128		355,306
Deferred investment tax credits	5,664		5,905
Deferred revenue	4,943		5,502
Derivatives, at fair value	4,116		3,133
Manufactured gas plant remediation	182,000		182,000
Postemployment employee benefit liability	105,135		124,196
Regulatory liabilities	78,429		67,077
Asset retirement obligation	28,457		27,983
Other	8,288		6,730
Total noncurrent liabilities	787,160		777,832
Commitments and contingent liabilities (Note 11)
Total capitalization and liabilities	$	2,991,195	$	2,770,005

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 497,400 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 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 and on-shore wind investments;

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 Energy Holdings Corporation primarily invests in energy-related ventures through its subsidiaries, NJNR Pipeline Company, 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 Midstream Investments segment (formerly Energy Holdings segment);

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

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 and Accounting Standards Codification (ASC) 270. The September 30, 2012, Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in NJR's 2012 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, 2013.

Intercompany transactions and accounts have been eliminated.

Gas in Storage

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

	June 30, 2013				September 30, 2012
($ in thousands)	Gas in Storage			Bcf (1)	Gas in Storage			Bcf (1)
NJNG		$	63,900	12.3		$	145,379	22.2
NJRES		216,218		56.3		119,814		45.5
Total		$	280,118	68.6		$	265,193	67.7

(1) Billion cubic feet (Bcf).

Available for Sale Securities

Included in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets are certain investments in equity securities of a publicly traded energy company that have a fair value of $11.5 million and $11 million as of June 30, 2013

Page 6

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

and September 30, 2012, respectively. Total unrealized gains associated with these equity securities, which are included as a part of accumulated other comprehensive income, a component of common stock equity, were $8.9 million ($5.3 million, after tax) and $8.3 million ($4.9 million, after tax) as of June 30, 2013 and September 30, 2012, respectively. During the third quarter of fiscal 2013, NJR received proceeds of approximately $482,000 from the sale of available-for-sale securities and realized a pre-tax gain of $380,000, which is included in other income in the Unaudited Condensed Consolidated Statements of Operations. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

Asset Held for Sale

NJR's subsidiary, CR&R, has committed to a plan to sell approximately 25.3 acres of undeveloped land located in Monmouth County with a net book value of $5.4 million. Since it is probable that the sale will be completed within the next 12 months, as of June 30, 2013, the Company has classified the property as held for sale in the Unaudited Condensed Consolidated Balance Sheets.

Disposal of Equipment

In October 2012, certain of NJRCEV's solar assets sustained damage as a result of Post Tropical Cyclone Sandy, commonly referred to as Superstorm Sandy (Superstorm Sandy). To the extent that any of the assets were deemed irreparable, the Company disposed of the damaged assets. As a result, the Company recognized a pre-tax loss of $766,000, which is included in other income on the Unaudited Condensed Consolidated Statements of Operations. During the third quarter of fiscal 2013, the Company received $954,000 from an insurance claim, representing the replacement value of the disposed assets and recorded a gain in the same amount in other income on the Unaudited Condensed Consolidated Statements of Operations.

Recent Updates to the Accounting Standards Codification

In December 2011, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2011-11, 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 generally accepted accounting principles (GAAP) in the United States of America and those prepared on the basis of International Financial Reporting Standards. The amended guidance will become effective for annual periods beginning on or after January 1, 2013, as well as interim periods within those annual periods, 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.

In February 2013, the FASB issued ASU No. 2013-02, an amendment to ASC Topic 220, Comprehensive Income, requiring information about amounts reclassified out of accumulated other comprehensive income as well as income statement line items that are affected by the reclassifications. The new guidance does not change existing requirements for reporting net income or other comprehensive income in the financial statements. ASU 2013-02 became effective for reporting periods beginning after December 15, 2012. There was no impact to the Company's financial position, results of operations or cash flows upon adoption.

NJR applied the provisions of the new guidance prospectively effective January 1, 2013. The information for the six month period ending June 30, 3013 is as follows:

Accumulated Other Comprehensive Income

(Thousands)	Unrealized gain on available for sale securities				Net unrealized gain on derivatives				Adjustment to postemployment benefit obligation				Total
Beginning balance as of January 1, 2013	$	4,601			$	41			$	(15,330	)		$	(10,688	)
Other comprehensive income, excluding reclassifications, net of tax of $(611), $(4), $-, $(615)	885				6				—				891
Amounts reclassified from accumulated other comprehensive income, net of tax of $155, $21 $(405), $(229)	(225		)	(1)	(40		)	(2)	592			(3)	327
Net current-period other comprehensive income, net of tax of $(456), $17, $(405), $(844)	660				(34		)		592				1,218
Ending balance as of June 30, 2013	$	5,261			$	7			$	(14,738	)		$	(9,470	)

(1) Reclassified to other income in the Unaudited Consolidated Statements of Operations.

(2) Reclassified to gas purchases in the Unaudited Consolidated Statements of Operations.

(3) Included in the computation of net periodic pension cost, a component of operations and maintenance expense in the Unaudited Consolidated Statements of Operations.

Page 7

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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.

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

(Thousands)	June 30, 2013		September 30, 2012
Regulatory assets-current
Conservation Incentive Program	$	18,954	$	25,681
Underrecovered gas costs	2,059		7,053
Total current	$	21,013	$	32,734
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	47,405	$	59,745
Liability for future expenditures	182,000		182,000
Deferred income taxes	11,405		11,405
Derivatives at fair value, net	386		—
Energy Efficiency Program	38,759		26,025
New Jersey Clean Energy Program (NJCEP)	16,953		5,619
Postemployment and other benefit costs	135,303		142,495
Deferred Superstorm Sandy costs	14,916		—
Other	13,105		13,974
Total noncurrent	$	460,232	$	441,263
Regulatory liability-current
Derivatives at fair value, net	$	1,191	$	1,169
Total current	$	1,191	$	1,169
Regulatory liabilities-noncurrent
Cost of removal obligation	$	77,581	$	65,994
Derivatives at fair value, net	—		1,000
Other	848		83
Total noncurrent	$	78,429	$	67,077

NJNG's recovery of costs is facilitated through its base tariff rates, Basic Gas Supply Service (BGSS) and other regulatory tariff riders. As recovery of regulatory assets is subject to BPU approval, if there are any changes in regulatory positions that indicate recovery is not probable, the related cost would be charged to income in the period of such determination.

Recent regulatory filings and/or actions include the following:

BGSS and Conservation Incentive Program (CIP)

• In March 2013, NJNG and South Jersey Gas Company filed a joint petition with the BPU requesting the continuation of the CIP with certain modifications. The discovery phase has commenced and, if no Board Order on that petition is issued as of September 30, 2013, the CIP program will continue for up to one additional year or until such an Order is issued, whichever is earlier. The CIP permits NJNG to recover utility gross margin variations related to customer usage resulting from customer conservation efforts and allows NJNG to mitigate the impact of weather on its gross margin. Such utility gross margin variations are recovered in the year following the end of the CIP usage year, without interest, and are subject to additional conditions, including an earnings test and an evaluation of BGSS related savings.

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• In May 2013, the BPU approved NJNG's fiscal 2013 BGSS/CIP rate on a final basis. In addition, NJNG notified the BPU that it was going to reduce its current BGSS rate resulting in a 5.2 percent decrease to an average residential heat customer's bill, effective June 2013 and submitted its fiscal 2014 BGSS/CIP filing, which proposes a 1 percent reduction to an average residential heat customer's bill related to the CIP factor for fiscal 2014.

Infrastructure Programs

• In October 2012, the BPU approved NJNG's Safety Acceleration and Facility Enhancement (SAFE) program, allowing a four-year incremental capital investment program of $130 million, exclusive of allowance for funds used during construction (AFUDC) accruals.

• In November 2012, NJNG submitted a filing requesting a base rate increase of $6.9 million for Accelerated Infrastructure Programs (AIP), related to the initial phase of AIP (AIP I) and the second phase of AIP (AIP II) infrastructure investments installed in NJNG's distribution and transmission systems through October 31, 2012. In May 2013, the BPU approved a $6.5 million base rate increase.

Energy Efficiency Programs (EE)

• In January 2013, the BPU approved a stipulation to extend NJNG's current SAVEGREEN Project^® (SAVEGREEN) through June 30, 2013. In June 2013, the BPU issued an Order approving NJNG's July 2012 request to extend and expand the current SAVEGREEN projects through June 30, 2015, with certain modifications, resulting in a planned investment of more than $85 million and including a weighted average cost of capital of 6.9 percent. In addition, the BPU approved a rate increase of approximately 1.7 percent related to the NJNG EE Tariff Rider to recover prior EE program costs and EE investments related to the SAVEGREEN programs.

Societal Benefits Clause (SBC)

• In November 2012, the BPU approved NJNG's funding obligations for NJCEP for the period from January 1, 2013 to June 30, 2013 of approximately $9.8 million. In June 2013, the BPU approved NJNG's funding obligations for July 1, 2013 to June 30, 2014, of approximately $15.6 million. Accordingly, NJNG recorded the obligation and corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets.

• In March 2013, the BPU approved a February 2012 filing that requested approval of NJNG's Manufactured Gas Plant (MGP) expenditures incurred through June 30, 2011, maintaining the existing overall SBC rate. In July 2013, NJNG filed an SBC petition with the BPU requesting a reduction to the Remediation Adjustment (RA) factor and approval of the related MGP expenditures for the period July 1, 2011 through June 30, 2013, along with an increase to the NJCEP factor.

• In June 2013, NJNG filed its annual Universal Service Fund (USF) petition with the BPU. The USF filing is a statewide filing and includes a proposed reduction to the current USF per therm rate.

Other Regulatory Initiatives

• In November 2012, NJNG filed a petition with the BPU requesting deferral accounting for uninsured incremental operating and maintenance costs associated with Superstorm Sandy, which was subsequently approved in May 2013. In addition, NJNG requested that the review of and the appropriate recovery period for such deferred expenses be addressed in the Company's next base rate case. As of June 30, 2013, NJNG has recorded a regulatory asset in the amount of $14.9 million related to these costs.

In March 2013, the BPU issued an Order establishing a generic proceeding to review the prudency of costs incurred by New Jersey utility companies in response to major storm events in 2011 and 2012. In July 2013, NJNG filed its detailed report including unreimbursed, uninsured incremental storm restoration costs and capital expenditures related to Superstorm Sandy.

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4. DERIVATIVE INSTRUMENTS

The Company is subject to commodity price risk due to fluctuations in the market price of natural gas. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas. In addition, the Company may utilize foreign currency derivatives as cash flow hedges of Canadian dollar denominated gas purchases. These contracts, with a few exceptions as described below, are accounted for as derivatives. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company's fair value measurement policies and level disclosures associated with the NJR's derivative instruments, see Note 5. Fair Value.

Since the Company chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges, changes in the fair value of these derivative instruments are recorded as a component of gas purchases or operating revenues, as appropriate for NJRES, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or (losses). For NJRES at settlement, realized gains and (losses) on all financial derivative instruments are recognized as a component of gas purchases and realized gains and (losses) on all physical derivatives follow the presentation of the related unrealized gains and (losses) as a component of either gas purchases or operating revenues.

NJRES also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the US dollar. NJRES utilizes foreign currency derivatives to lock in the currency translation rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are being used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company has designated these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in other comprehensive income (OCI). When the foreign exchange contracts are settled, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that may ultimately be repaid, based on changes in forward natural gas prices during the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings.

Changes in fair value of NJNG's financial derivative instruments are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets, as NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff.

The Company elects normal purchase/normal sale (NPNS) accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, gains or (losses) are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered.

During fiscal 2012, NJRCEV began economically hedging certain of its expected production of solar renewable energy certificates (SRECs) through forward sale contracts. The Company intends to physically deliver the SRECs upon settlement and, therefore, applies NPNS accounting treatment to the contracts and recognizes related revenue upon transfer of the SRECs.

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Fair Value of Derivatives

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

			Fair Value
			June 30, 2013						September 30, 2012
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	51		$	17		$	116		$	97
	Derivatives - noncurrent		—			23			70			15
Fair value of derivatives designated as hedging instruments			$	51		$	40		$	186		$	112
Derivatives not designated as hedging instruments:
NJNG:
Financial derivative contracts	Derivatives - current		$	4,496		$	3,305		$	6,203		$	5,034
	Derivatives - noncurrent		—			386			1,000			—
NJRES:
Physical forward commodity contracts	Derivatives - current		8,296			10,119			19,590			9,530
	Derivatives - noncurrent		320			16			658			216
Financial derivative contracts	Derivatives - current		52,635			22,770			22,112			27,779
	Derivatives - noncurrent		1,400			3,691			600			2,902
Fair value of derivatives not designated as hedging instruments			$	67,147		$	40,287		$	50,163		$	45,461
Total fair value of derivatives			$	67,198		$	40,327		$	50,349		$	45,573

At June 30, 2013, the gross notional amount of the foreign currency transactions was approximately $3.8 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						Nine Months Ended
		June 30,						June 30,
Derivatives not designated as hedging instruments:		2013			2012			2013			2012
NJRES:
Physical commodity contracts	Operating revenues	$	3,595		$	(2,860	)	$	(4,264	)	$	(6,023	)
Physical commodity contracts	Gas purchases	(8,809		)	8,155			(6,253		)	12,546
Financial derivative contracts	Gas purchases	39,601			(9,717		)	38,134			93,248
Total unrealized and realized gains (losses)		$	34,387		$	(4,422	)	$	27,617		$	99,771

Not included in the previous table, are (losses) gains associated with NJNG's financial derivatives that totaled $(4.7) million and $3.7 million for the three months endedJune 30, 2013 and 2012, respectively, and gains (losses) that totaled $1.4 million and $(31.6) million for the nine months endedJune 30, 2013 and 2012, respectively. These derivatives are part of NJNG's risk

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management activities that relate to its natural gas purchases and BGSS incentive programs. As these transactions are entered into pursuant to and recoverable through regulatory riders, any changes in the value of NJNG's financial derivatives are deferred in regulatory assets or liabilities 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 on the Unaudited Condensed Consolidated Statements of Operations. The following tables reflect the effect of derivative instruments designated as cash flow hedges on OCI as of:

(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
	June 30,					June 30,						June 30,
Derivatives in cash flow hedging relationships:	2013			2012		2013			2012			2013		2012
Foreign currency contracts	$	(14	)	$	12	$	(21	)	$	(35	)	$	—	$	—

(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion) (1)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)					Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Nine Months Ended						Nine Months Ended					Nine Months Ended
	June 30,						June 30,					June 30,
Derivatives in cash flow hedging relationships:	2013			2012			2013		2012			2013		2012
Foreign currency contracts	$	(85	)	$	(63	)	$	23	$	(70	)	$	—	$	—

(1) The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $33,000 from OCI into earnings. The maximum tenor is April 2015.

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

			Volume (Bcf)
			June 30, 2013		September 30, 2012
NJNG	Futures		17.0		16.1
	Swaps	(1)	—		3.4
	Options		0.7		—
NJRES	Futures		(50.2	)	(28.6	)
	Swaps	(1)	—		13.2
	Options		—		4.4
	Physical		22.1		(3.5	)

(1) In October 2012, following the implementation of the Dodd-Frank Wall Street Reform and Consumer Protection Act, the Intercontinental Exchange (ICE) converted its cleared energy “swap” contracts to “futures” contracts and the New York Mercantile Exchange (NYMEX) amended their product titles to remove the word “swap” from the titles of their “futures” and “option” contracts.

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

(Thousands)	Balance Sheet Location	June 30, 2013		September 30, 2012
NJNG	Broker margin - Current assets	$	1,350	$	1,713
NJRES	Broker margin - Current assets	$	—	$	20,216
NJRES	Broker margin - Current liabilities	$	6,181	$	—

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 and the North American Energy Standards Board. 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 June 30, 2013. 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		$	199,972
Noninvestment grade		5,679
Internally rated investment grade		34,692
Internally rated noninvestment grade		4,461
Total		$	244,804

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

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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 June 30, 2013 and September 30, 2012, was $1.2 million and $1.6 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 June 30, 2013 and September 30, 2012, the Company would have been required to post an additional $87,000 and $1.2 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted.

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 and excluding capital leases, is as follows:

(Thousands)	June 30, 2013		September 30, 2012
Carrying value	$	529,845	$	479,845
Fair market value	$	558,336	$	530,056

NJR utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific issue and the Company's credit rating. As of June 30, 2013, NJR discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following:

Level 1 Unadjusted quoted prices for identical assets or liabilities in active markets; NJR's Level 1 assets and liabilities include exchange traded futures and options contracts, listed equities, and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX/Chicago Mercantile Exchange (CME) and ICE that NJR refers internally to as basis swaps, fixed swaps, futures and options that are cleared through a Futures Commission Merchant (FCM).

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. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation

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tariff inputs and no market perspective is required. Even if the transportation tariff input was considered to be a “model”, it would still be considered to be a Level 2 input as:

1)     The data is widely accepted and public

2)    The data is non-proprietary and sourced from an independent third party

3)    The data is observable and published

These additional adjustments are generally not considered to be significant to the ultimate recognized values.

Level 3 Inputs derived from a significant amount of unobservable market data; these include NJR's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

Assets and liabilities measured at fair value on a recurring basis are summarized as follows:

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of June 30, 2013:
Assets:
Physical forward commodity contracts		$	—		$	8,616		$	—	$	8,616
Financial derivative contracts - natural gas		58,531			—			—		58,531
Financial derivative contracts - foreign exchange		—			51			—		51
Available for sale equity securities - energy industry (1)		11,482			—			—		11,482
Other (2)		1,096			—			—		1,096
Total assets at fair value		$	71,109		$	8,667		$	—	$	79,776
Liabilities:
Physical forward commodity contracts		$	—		$	10,135		$	—	$	10,135
Financial derivative contracts - natural gas		30,115			37			—		30,152
Financial derivative contracts - foreign exchange		—			40			—		40
Total liabilities at fair value		$	30,115		$	10,212		$	—	$	40,327
As of September 30, 2012:
Assets:
Physical forward commodity contracts		$	—		$	20,248		$	—	$	20,248
Financial derivative contracts - natural gas		14,270			15,645			—		29,915
Financial derivative contracts - foreign exchange		—			186			—		186
Available for sale equity securities - energy industry(1)		11,009			—			—		11,009
Other (2)		30			—			—		30
Total assets at fair value		$	25,309		$	36,079		$	—	$	61,388
Liabilities:
Physical forward commodity contracts		$	—		$	9,746		$	—	$	9,746
Financial derivative contracts - natural gas		16,922			18,793			—		35,715
Financial derivative contracts - foreign exchange		—			112			—		112
Total liabilities at fair value		$	16,922		$	28,651		$	—	$	45,573

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

(2) Includes various money market funds.

6. INVESTMENTS IN EQUITY INVESTEES

Investment in equity investees includes NJR's equity method and cost method investments.

Equity Method Investments

(Thousands)	June 30, 2013		September 30, 2012
Steckman Ridge	$	130,715	$	132,931
Iroquois	23,915		22,864
Total	$	154,630	$	155,795

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As of June 30, 2013, the investment in Steckman Ridge includes loans with a total outstanding principal balance of $70.4 million. The loans accrue interest at a variable rate that resets quarterly and are due 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 intercompany transactions.

Cost Method Investments

During the fourth quarter of fiscal 2012, NJR invested $8.8 million in OwnEnergy, a developer of on-shore wind projects. At that time, the investment represented a 19.9 percent equity interest. Under the terms of the investment agreements, other OwnEnergy investors had the opportunity to invest in the same round of equity financing that NJR participated in. As of June 30, 2013, NJR's ownership interest is 18.7 percentand is accounted for in accordance with the cost method of accounting.

7. EARNINGS PER SHARE

The following table presents the calculation of the Company's basic and diluted earnings per share for:

	Three Months Ended					Nine Months Ended
	June 30,					June 30,
(Thousands, except per share amounts)	2013		2012			2013		2012
Net income (loss), as reported	$	29,155	$	(10,320	)	$	134,830	$	101,572
Basic earnings per share
Weighted average shares of common stock outstanding-basic	41,608		41,560			41,697		41,501
Basic earnings (loss) per common share	$0.70		$(0.25)			$3.23		$2.45
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	41,608		41,560			41,697		41,501
Incremental shares (1)	124		—			123		142
Weighted average shares of common stock outstanding-diluted	41,732		41,560			41,820		41,643
Diluted earnings (loss) per common share (2)	$0.70		$(0.25)			$3.22		$2.44

(1) Incremental shares consist of stock options, stock awards and performance units.

(2) Since there was a net loss for the three months ended June 30, 2012, incremental shares of 140 were not included in the computation of diluted loss per common share, as their effect would have been anti-dilutive. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and nine months endedJune 30, 2013 and the nine months endedJune 30, 2012.

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.

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

(Thousands)	June 30, 2013			September 30, 2012			Maturity Dates
NJNG
Bank credit facility dedicated to EDA Bonds (1) (2) (3)	$	100,000		$	100,000		August 2015
Bank revolving credit facility (1)	$	250,000		$	200,000		August 2014
Amount outstanding at end of period	$	96,000		$	135,000
Weighted average interest rate at end of period	0.15		%	0.18		%
Amount available at end of period	$	154,000		$	65,000
NJR
Bank revolving credit facility(1)	$	325,000		$	325,000		August 2017
Amount outstanding at end of period	$	200,900		$	144,800
Weighted average interest rate at end of period	1.12		%	1.16		%
Amount available at end of period (4)	$	107,710		$	166,339

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

(2) There were no borrowings outstanding as of June 30, 2013 and September 30, 2012, respectively.

(3) New Jersey Economic Development Authority (EDA) Bonds.

(4) Letters of credit outstanding total $16.4 million and $13.9 million as of June 30, 2013 and September 30, 2012, respectively, which reduces amount available.

NJNG

NJNG received $7.1 million and $6.5 million in December 2012 and 2011, respectively, in connection with the sale-leaseback of its natural gas meters. NJNG records a capital lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease.

On October 4, 2012, the BPU approved a petition filed by NJNG requesting authorization over a three-year period to issue medium-term debt with a maturity of not more than 30 years, renew its revolving credit facility expiring August 2014, renew its credit facility supporting NJNG's obligations with respect to bonds issued by the New Jersey Economic Development Authority, enter into interest rate risk management transactions and increase the size of its meter leasing program on a permanent basis.

On November 30, 2012, NJNG utilized the accordion option available under its committed revolving syndicated credit facility to increase the amount of credit available from $200 million to $250 million.

On April 15, 2013, NJNG issued $50 million of 3.15 percent senior secured notes due April 15, 2028 (Notes) in the private placement market pursuant to a note purchase agreement entered into on February 8, 2013. Interest is payable on the Notes semi-annually. The proceeds from the Notes were used to refinance short-term debt and will fund capital expenditure requirements.

NJR

On May 12, 2011, NJR entered into an unsecured, uncommitted $100 million private placement shelf note agreement allowing NJR to issue senior notes during a two-year issuance period, which expired on May 10, 2013. As of June 30, 2013, under the terms of the agreement, NJR has $25 million of 1.94 percent senior notes due September 15, 2015, and $25 million of 2.51 percent senior notes due September 15, 2018 issued and outstanding.

On June 30, 2011, NJR entered into an unsecured, uncommitted $75 million private placement shelf note agreement allowing NJR to issue senior notes during a three-year issuance period ending June 30, 2014. As of June 30, 2013, under the terms of the agreement, NJR has $50 million of 3.25 percent senior notes due September 17, 2022 issued and outstanding and $25 million remaining available for borrowing.

On June 5, 2013, NJR entered into a new agreement permitting the issuance of stand-alone letters of credit for up to $10 million through June 5, 2014. No amounts have been drawn under this arrangement as of June 30, 2013.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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						Nine Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						June 30,						June 30,
(Thousands)	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	1,718		$	1,344		$	5,154		$	4,032		$	1,171		$	896		$	3,513		$	2,688
Interest cost	2,235			2,206			6,705			6,618			1,287			1,283			3,861			3,849
Expected return on plan assets	(3,706		)	(3,171		)	(11,118		)	(9,513		)	(913		)	(687		)	(2,739		)	(2,059		)
Recognized actuarial loss	1,911			1,254			5,733			3,762			964			724			2,892			2,172
Prior service cost amortization	27			11			81			33			(281		)	6			(267		)	18
Recognized net initial obligation	—			—			—			—			199			89			21			267
Net periodic benefit cost	$	2,185		$	1,644		$	6,555		$	4,932		$	2,427		$	2,311		$	7,281		$	6,935

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 discretionary contributions of $20 million to the pension plans in both December 2012 and 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 nine months endedJune 30, 2013 and 2012, 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 nine months endedJune 30, 2013 and 2012, are 27.6 percent and 13.5 percent, respectively. The change in the rate is due primarily to the impact of federal investment tax credits (ITC), net of deferred taxes, recognized in the nine months endedJune 30, 2013 and 2012, of $13.1 million and $27.2 million, respectively, which are generated by solar investments forecasted to be completed before the end of the fiscal year.

To calculate the estimated annual effective tax rate, NJR considers solar projects that are probable of being completed and placed in service during the current fiscal year based on the best information available at each reporting period. The estimate includes an assessment of various factors, such as board of director approval, status of contractual agreements, permitting, regulatory approval and interconnection. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

11. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through August 2030, for the supply, storage and delivery of natural gas. These contracts include current annual fixed charges of approximately $99.7 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 June 30, 2013, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2013		2014		2015		2016		2017		Thereafter
NJRES:
Natural gas purchases	$	247,632	$	126,175	$	31,225	$	16,800	$	—	$	—
Storage demand fees	9,615		26,098		12,005		7,114		5,035		7,318
Pipeline demand fees	18,557		31,851		18,133		9,576		8,225		9,756
Sub-total NJRES	$	275,804	$	184,124	$	61,363	$	33,490	$	13,260	$	17,074
NJNG:
Natural gas purchases	$	37,843	$	94,047	$	103,080	$	8,755	$	113	$	—
Storage demand fees	7,061		28,208		21,283		11,956		9,990		23,247
Pipeline demand fees	15,504		75,442		41,596		34,558		32,753		221,838
Sub-total NJNG	$	60,408	$	197,697	$	165,959	$	55,269	$	42,856	$	245,085
Total (1)	$	336,212	$	381,821	$	227,322	$	88,759	$	56,116	$	262,159

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

NJNG's capital expenditures are estimated at $146.3 million and $119.9 million in fiscal 2013 and 2014, respectively, including estimates of $29.9 million and $43.4 million, respectively, related to SAFE construction costs. Expenditures consist primarily of NJNG's construction program to support customer growth, maintenance of its distribution system, replacement needed under pipeline safety regulations and costs associated with the restoration of damages to NJNG's infrastructure as a result of Superstorm Sandy. Approximately $100 million has been committed or spent on capital expenditures, including accruals, during the nine months endedJune 30, 2013. NJNG has committed or spent $15.7 million related to the SAFE program, $11.5 million related to AIP II program and $24.7 million related to restoration from storm damages during the nine months endedJune 30, 2013.

As of June 30, 2013, total capital expenditures associated with the restoration of the portions of distribution main affected by Superstorm Sandy are estimated to be between $30 million to $40 million. NJNG expects to spend between $26 million to $30 million during fiscal 2013, with the remainder, if any, being spent over the following three fiscal years.

NJRCEV's expenditures include discretionary spending on capital projects that support NJR's goal to promote clean energy. Accordingly, NJRCEV enters into agreements to install solar equipment involving both residential and commercial projects. Total solar-related capital expenditures during the nine months endedJune 30, 2013, were $39.8 million. The Company currently estimates solar-related capital expenditures between $55 million and $60 million during fiscal 2013, of which $51.1 million has been committed or spent. Solar-related capital expenditures in fiscal 2014 are estimated by the Company to be between $70 million and $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, if at all, ability to access capital or allocation of capital to other investments or business opportunities.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of five MGP sites, dating back to gas operations in the late 1800s and early 1900s that contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the 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. On March 20, 2013, the BPU approved the recovery of the remediation expenditures incurred through June 30, 2011, which maintained the expected annual recovery at approximately $20 million. On July 23, 2013, NJNG filed an

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

SBC petition with the BPU requesting a reduction to the RA factor and approval of the related MGP expenditures for the period July 1, 2011 through June 30, 2013. As of June 30, 2013, $47.4 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 2012, 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 $159.6 million to $266.4 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. Accordingly, NJNG has recorded an MGP remediation liability and a corresponding regulatory asset of $182 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 Midstream Investments segment consists of NJR's investments in natural gas transportation and storage facilities; the Retail and Other operations consist of heating, cooling and water appliance installation and services, commercial real estate development, other investments and general corporate activities.

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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						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Operating revenues
Natural Gas Distribution
External customers	$	119,022		$	106,764		$	689,621		$	524,161
Clean Energy Ventures
External customers	2,563			370			7,182			1,277
Energy Services
External customers	632,414			306,273			1,735,411			1,126,435
Intercompany	1,119			(32		)	5,670			2,816
Segment subtotal	755,118			413,375			2,437,884			1,654,689
Retail and Other
External customers	13,470			11,714			32,159			28,580
Intercompany	234			278			683			720
Eliminations	(1,353		)	(246		)	(6,353		)	(3,536		)
Total	$	767,469		$	425,121		$	2,464,373		$	1,680,453
Depreciation and amortization
Natural Gas Distribution	$	9,537		$	8,860		$	28,213		$	26,241
Clean Energy Ventures	2,196			1,632			6,131			3,953
Energy Services	10			16			32			48
Midstream Investments	2			1			5			4
Segment subtotal	11,745			10,509			34,381			30,246
Retail and Other	196			178			586			480
Eliminations	1			—			(1		)	—
Total	$	11,942		$	10,687		$	34,966		$	30,726
Interest income (1)
Natural Gas Distribution	$	146		$	223		$	459		$	683
Energy Services	—			10			—			36
Midstream Investments	265			267			799			800
Segment subtotal	411			500			1,258			1,519
Retail and Other	(1		)	1			1			2
Eliminations	(217		)	(248		)	(667		)	(751		)
Total	$	193		$	253		$	592		$	770

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

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Interest expense, net of capitalized interest
Natural Gas Distribution	$	3,796		$	3,717		$	10,929		$	11,167
Clean Energy Ventures	870			190			2,475			530
Energy Services	615			214			1,823			729
Midstream Investments	466			653			1,533			2,050
Segment subtotal	5,747			4,774			16,760			14,476
Retail and Other	261			60			819			790
Total	$	6,008		$	4,834		$	17,579		$	15,266
Income tax provision (benefit)
Natural Gas Distribution	$	1,788		$	1,114		$	39,089		$	43,726
Clean Energy Ventures	(1,477		)	(3,013		)	(15,703		)	(30,010		)
Energy Services	12,945			(11,511		)	23,906			(2,108		)
Midstream Investments	1,073			1,126			3,935			3,750
Segment subtotal	14,329			(12,284		)	51,227			15,358
Retail and Other	1,378			1,056			349			685
Eliminations	(410		)	(2		)	(234		)	(142		)
Total	$	15,297		$	(11,230	)	$	51,342		$	15,901
Equity in earnings of affiliates
Midstream Investments	$	3,052		$	3,547		$	11,012		$	11,129
Eliminations	(830		)	(903		)	(2,705		)	(2,813		)
Total	$	2,222		$	2,644		$	8,307		$	8,316
Net financial earnings (loss)
Natural Gas Distribution	$	5,528		$	7,545		$	76,937		$	78,455
Clean Energy Ventures	(1,381		)	(1,157		)	9,078			20,802
Energy Services	2,097			(5,425		)	21,479			18,061
Midstream Investments	1,541			1,634			5,600			5,438
Segment subtotal	7,785			2,597			113,094			122,756
Retail and Other	1,944			1,549			813			860
Eliminations	9			(16		)	(12		)	(52		)
Total	$	9,738		$	4,130		$	113,895		$	123,564
Capital expenditures
Natural Gas Distribution	$	29,141		$	33,405		$	94,840		$	82,550
Clean Energy Ventures	14,891			13,457			39,756			75,243
Segment subtotal	44,032			46,862			134,596			157,793
Retail and Other	234			109			532			568
Total	$	44,266		$	46,971		$	135,128		$	158,361

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New Jersey Resources Corporation

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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						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Consolidated net financial earnings	$	9,738		$	4,130		$	113,895		$	123,564
Less:
Unrealized (gain) loss from derivative instruments and related transactions, net of taxes (1) (2)	(27,915		)	20,834			(14,975		)	11,126
Effects of economic hedging related to natural gas inventory, net of taxes (3)	8,498			(6,384		)	(5,960		)	10,866
Consolidated net income (loss)	$	29,155		$	(10,320	)	$	134,830		$	101,572

(1) Excludes unrealized losses (gains) related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $708,000 and $(20,000) for the three months endedand $398,000 and $177,000 for the nine months endedJune 30, 2013 and 2012, respectively.

(2) Amounts are net of taxes of approximately $(17.1) million and $12.1 million, for the three months ended and $(9.2) million and $6.3 million for the nine months endedJune 30, 2013 and 2012, respectively.

(3) Amounts are net of taxes of approximately $4.9 million and $(3.7) million for the three months ended and $(3.5) million and $6.3 million for the nine months endedJune 30, 2013 and 2012, 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)	June 30, 2013			September 30, 2012
Assets at end of period:
Natural Gas Distribution	$	2,062,913		$	2,005,520
Clean Energy Ventures	253,680			223,247
Energy Services	497,941			347,406
Midstream Investments	156,135			157,779
Segment subtotal	2,970,669			2,733,952
Retail and Other	86,920			73,298
Eliminations (1)	(66,394		)	(37,245		)
Total	$	2,991,195		$	2,770,005

(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 June 30, 2013, NJRES has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which expire by June 2014. Additionally, NJRES has transportation capacity with Iroquois Gas Transmission that expires by March 2019. Demand fees, net of eliminations, associated with both Steckman Ridge and Iroquois Gas Transmission were $4.6 million and $5 million during the nine months endedJune 30, 2013 and 2012, respectively. As of June 30, 2013, NJRES had demand fees payable of $157,000 and $392,000 to Steckman Ridge and Iroquois Gas Transmission, respectively, which are included in gas purchases payable. As of September 30, 2012, fees payable to Steckman Ridge and Iroquois Gas Transmission, were $170,000 and $394,000, 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, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG's BGSS mechanism and are included in regulatory assets. Additionally, NJNG has transportation capacity with Iroquois Gas Transmission that expires by January 2019. Demand fees, net of eliminations, associated with both Steckman Ridge and Iroquois Gas Transmission were $4.3 million and $3.9 million during the nine months endedJune 30, 2013 and 2012, respectively. NJNG had demand fees payable to Steckman Ridge in the amount of $775,000 as of both June 30, 2013 and September 30, 2012. NJNG had fees payable to Iroquois Gas Transmission of $61,000 as of both June 30, 2013 and September 30, 2012.

In December 2009, NJNG and NJRES entered into an asset management agreement that began in January 2010 and ends in March 2014. 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 our 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).

NJR Clean Energy Ventures (NJRCEV) invests in renewable energy projects consisting primarily of residential and commercial rooftop and ground mount solar systems. In addition, NJRCEV has an ownership interest in OwnEnergy that will allow NJRCEV to participate in on-shore wind projects. NJRCEV comprises our Clean Energy Ventures segment.

NJRES comprises our 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.

Our Midstream Investments segment (formerly Energy Holdings segment) includes NJR Energy Holdings Corporation (NJREH), which primarily invests in energy-related ventures through its subsidiaries, NJNR Pipeline Company, 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.

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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)

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, which provides support services to the various NJR businesses.

Assets by business segment and operations are as follows:

(Thousands)	June 30, 2013					September 30, 2012
Assets
Natural Gas Distribution	$	2,062,913		69	%	$	2,005,520		72	%
Clean Energy Ventures	253,680			8		223,247			8
Energy Services	497,941			17		347,406			12
Midstream Investments	156,135			5		157,779			6
Retail and Other	86,920			3		73,298			3
Eliminations (1)	(66,394		)	(2	)	(37,245		)	(1	)
Total	$	2,991,195		100	%	$	2,770,005		100	%

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

The increase in assets during the nine months endedJune 30, 2013, was due primarily to higher gas in storage and receivable balances at Energy Services, along with increases in accounts receivable and unbilled revenue in Natural Gas Distribution due to the seasonality of the business along with an increase in property, plant & equipment.

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

	Three Months Ended										Nine Months Ended
	June 30,										June 30,
(Thousands)	2013					2012					2013					2012
Net Income (Loss)
Natural Gas Distribution	$	5,528		19	%	$	7,545		(73	)%	$	76,937		57	%	$	78,455		77	%
Clean Energy Ventures	(1,381		)	(5	)	(1,157		)	11		9,078			7		20,802			20
Energy Services	22,222			76		(19,895		)	193		42,812			32		(3,754		)	(4	)
Midstream Investments	1,541			5		1,634			(16	)	5,600			4		5,438			5
Retail and Other	1,944			7		1,549			(15	)	813			—		860			2
Eliminations (1)	(699		)	(2	)	4			—		(410		)	—		(229		)	—
Total	$	29,155		100	%	$	(10,320	)	100	%	$	134,830		100	%	$	101,572		100	%

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

Included in net income are unrealized gains (losses) in the Energy Services segment of $28.6 million and $(20.9) million, after taxes, for the three months endedJune 30, 2013 and 2012, respectively and realized (losses) gains of $(8.5) million and $6.4 million, after taxes, for the three months endedJune 30, 2013 and 2012, respectively, which are related to financial derivative instruments that have settled and are designed to economically hedge natural gas still in inventory. During the nine months endedJune 30, 2013 and 2012, unrealized gains (losses) were $15.4 million and $(10.9) million, after taxes, respectively, and realized gains (losses) were $6 million and $(10.9) million, after taxes, respectively.

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 revenues and gas purchases, as appropriate, on 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.

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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)

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.

Management of the Company uses a non-Generally Accepted Accounting Principles (non-GAAP) measure, noted as “net financial earnings,” when evaluating the operating results of NJRES. Net financial earnings (NFE) 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 Generally Accepted Accounting Principles (GAAP) earnings associated with the derivative instruments.

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

	Three Months Ended										Nine Months Ended
	June 30,										June 30,
($ in Thousands)	2013					2012					2013					2012
Net Financial Earnings (Loss)
Natural Gas Distribution	$	5,528		57	%	$	7,545		183	%	$	76,937		67	%	$	78,455		63	%
Clean Energy Ventures	(1,381		)	(14	)	(1,157		)	(28	)	9,078			8		20,802			17
Energy Services	2,097			21		(5,425		)	(131	)	21,479			19		18,061			15
Midstream Investments	1,541			16		1,634			39		5,600			5		5,438			4
Retail and Other	1,944			20		1,549			37		813			1		860			1
Eliminations (1)	9			—		(16		)	—		(12		)	—		(52		)	—
Total	$	9,738		100	%	$	4,130		100	%	$	113,895		100	%	$	123,564		100	%

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

Natural Gas Distribution Segment

Our Natural Gas Distribution segment has approximately 497,400 residential and commercial customers in its service territory. 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 and customer conservation efforts, which can impact customer usage, certain regulatory actions, environmental remediation and severe weather conditions. It is often difficult to predict the impact of events or trends associated with these risks. NJNG employs certain strategies to mitigate the challenges it faces, including managing the integrity of its infrastructure, pursuing customer conversions from other fuel sources and monitoring new construction markets through contact with developers, utilizing Basic Gas Supply Service (BGSS) 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.

In October 2012, high winds, heavy rainfall and the related flooding associated with Post Tropical Cyclone Sandy, commonly referred to as Superstorm Sandy (Superstorm Sandy) caused significant damage to portions of NJNG's distribution system. As a result, NJNG shut off the natural gas infrastructure in certain areas of its service territory that were most heavily damaged, affecting approximately 30,100 of NJNG's customers. As of June 30, 2013, total capital expenditures associated with the restoration of the affected portions of distribution main are estimated to be between $30 million to $40 million. NJNG expects to spend between $26 million to $30 million during fiscal 2013, with the remainder being spent over the following three fiscal years. As with normal operations, capital costs will be treated as additions to NJNG's rate base on which recovery will be sought in a future base rate case. In addition, on November 19, 2012, NJNG filed a petition with the BPU requesting deferral accounting for uninsured incremental operating and maintenance (O&M) costs associated with Superstorm Sandy restoration efforts. NJNG requested that the review of and the appropriate recovery period for such deferred expenses be addressed in NJNG's next base rate case. On May 29, 2013, NJNG received approval from the BPU regarding the deferral of Superstorm Sandy O&M costs. As of June 30, 2013, NJNG has approximately $14.9 million of deferred costs in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets related to the restoration of its infrastructure and expects that total incremental O&M costs during fiscal 2013 will approximate between $15 million to $17 million.

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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)

On March 20, 2013, the BPU issued an Order establishing a generic proceeding to review the prudency of costs incurred by New Jersey utility companies in response to major storm events in 2011 and 2012. On July 1, 2013, NJNG filed its detailed report to include unreimbursed, uninsured incremental storm restoration costs and capital expenditures related to Superstorm Sandy.

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. In June 2012, NJNG filed for a decrease in the CIP rate for residential non-heating customers and an increase in the CIP rates for residential heating and commercial customers, which was approved on a provisional basis and went into effect October 12, 2012. On May 29, 2013, NJNG submitted its fiscal 2014 BGSS/CIP petition with the BPU, which proposes a 1 percent reduction to an average residential heat customer's bill related to the CIP factor for fiscal 2014. 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.

On March 1, 2013, NJNG and South Jersey Gas Company filed a joint petition with the BPU requesting the continuation of the CIP with certain modifications. The discovery phase has commenced and, if no Board Order on that petition is issued as of September 30, 2013, the CIP program may continue for up to one additional year or until such an Order is issued, whichever is earlier.

As of June 30, 2013, NJNG has $19 million in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets related to CIP accrued 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.

NJNG added 5,301 and 4,891 new customers and converted 497 and 395 existing customers to natural gas heat and other services during the nine months endedJune 30, 2013 and 2012, respectively. This customer growth represents an estimated annual increase of approximately .6 billion cubic feet (Bcf) in sales to firm customers, which would contribute approximately $2.6 million annually to utility gross margin assuming normal weather and usage. NJNG currently expects to add approximately 13,000 to 15,000 new customers during the two-year period of fiscal 2013 and 2014. This growth rate would increase utility gross margin under NJNG's base rates by approximately $3.7 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 and further discussion 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 $3.02 per MMBtu (Million Metric British thermal unit) to $4.15 per MMBtu and from $2.04 per MMBtu to $3.76 per MMBtu during the nine months endedJune 30, 2013 and 2012, respectively. As of June 30, 2013, forward natural gas prices for the next twelve months on the NYMEX, which serve as a market indicator, averaged $3.76 per MMBtu, 4.2 percenthigher than the average settlement price of $3.61 per MMBtu during the nine months endedJune 30, 2013.

NJNG occasionally adjusts its periodic 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 nine months endedJune 30, 2012, NJNG issued credits of $85.9 million, to residential and small commercial customers. BGSS rates for its large commercial customers are changed monthly based on NYMEX prices. There were no bill credits issued during the nine months endedJune 30, 2013.

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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)

On May 20, 2013, the BPU approved NJNG's fiscal 2013 BGSS/CIP rate on a final basis. On May 24, 2013, NJNG notified the BPU that it was going to reduce its then current BGSS rate by 5.2 percent, effective June 1, 2013. On May 29, 2013, NJNG submitted its fiscal 2014 BGSS/CIP filing with the BPU. The BGSS/CIP filing includes the reduced BGSS rate that went into effect on June 1, 2013.

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.

BGSS 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 $6 million and $7.9 million during the nine months endedJune 30, 2013 and 2012, 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 remediation 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 June 30, 2013, NJNG has recognized a regulatory asset and an obligation of $182 million, a decrease of $900,000, or .5 percent, compared with the prior period.

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. On March 20, 2013, the BPU approved a February 2012 filing that requested approval of NJNG's MGP expenditures incurred through June 30, 2011, maintaining the existing overall social benefit clause (SBC) rate and recovery. On July 23, 2013, NJNG filed an SBC petition with the BPU requesting an overall increase of 1.7 percent to the SBC as a result of a reduction to the Remediation Adjustment factor and approval of the related MGP expenditures for the period from July 1, 2011 through June 30, 2013, along with an increase to the NJCEP factor.

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.

NJNG implemented its Accelerated Infrastructure Program (AIP), as approved by the BPU in 2009, to enhance the reliability of NJNG's gas distribution system and to support economic development and job growth in New Jersey. Since inception of the program, the BPU has approved total infrastructure investments of $131 million as of May 29, 2013. The approved projects included $70.8 million related to the initial phase of construction projects (AIP I) and $60.2 million related to the second phase of construction projects (AIP II), exclusive of AFUDC.

On October 23, 2012, NJNG received BPU approval to implement a Safety Acceleration and Facility Enhancement (SAFE) program, whereby NJNG would invest up to $130 million over a four-year period to replace portions of NJNG's gas distribution bare steel and cast iron infrastructure, exclusive of allowance for funds used during construction (AFUDC) accruals.

Other

NJNG administers The SAVEGREEN Project^® (SAVEGREEN), a BPU-approved program, which facilitates home energy audits and provides financing alternatives including rebates and other incentives designed to encourage the installation of high

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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)

efficiency heating and cooling equipment. Depending on the specific initiative, NJNG recovers costs associated with the programs over a two to ten-year period.

On January 18, 2012, the BPU approved the extension of the program through January 18, 2013, with an additional $10.4 million of investments in customer incentives and rebates, earning a weighted average return of 7.1 percent, including a cost of equity of 10.3 percent. On January 23, 2013, the BPU approved a stipulation to extend NJNG's current SAVEGREEN through June 30, 2013. On June 21, 2013, the BPU approved an extension of the program through June 2015, with an additional $17.3 million of investments, earning a weighted average return of 6.9 percent. The approved SAVEGREEN projects include residential grants and incentives as well as on-bill financing options for both residential and commercial customers. The BPU also approved a rate increase of 1.7 percent related to the NJNG Energy Efficiency (EE) Tariff Rider. As of June 30, 2013, the BPU approved total EE expenditures of $56.4 million, of which NJNG has spent $37.6 million.

On June 18, 2012, the BPU approved a pilot program for NJNG to invest up to $10 million to build compressed natural gas (CNG) vehicle refueling stations in Monmouth, Ocean and Morris counties. During fiscal 2013, NJNG entered into agreements to build the infrastructure for three CNG stations at host facilities. NJNG expects to invest between $6 million to $8 million to construct these three CNG stations starting in the summer of 2013 and submit a cost recovery filing to the BPU in the spring of 2014, requesting a base rate change to be effective in the fall of 2014, earning an overall weighted average cost of capital of 7.1 percent, including a cost of equity of 10.3 percent. A portion of the proceeds from the utilization of the CNG equipment, along with any available federal and state incentives, will be credited back to customers to help offset the cost of this investment.

On March 6, 2013, the BPU directed its Staff to convene a generic proceeding for all interested parties to review issues associated with consolidated tax adjustments (CTA) as applied in utility base rate proceedings. NJNG responded to the initial data request on May 3, 2013.

Interest Rate Risk

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.

Clean Energy Ventures Segment

Our Clean Energy Ventures segment 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 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.

In October 2012, certain NJRCEV solar assets sustained damage as a result of Superstorm Sandy, including a minor portion of a 1.5 Megawatts (MW) rooftop commercial solar array. To the extent that any of the assets were deemed irreparable, the Company disposed of the damaged equipment. Accordingly, NJRCEV recognized a pre-tax loss of $766,000 in the first quarter of fiscal 2013, which is included in other income on the Unaudited Condensed Consolidated Statements of Operations. During the third quarter of fiscal 2013, the Company received $954,000 from an insurance claim, representing replacement value of the disposed assets.

NJRCEV's investments 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, 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, economic trends, unforeseen events and the ability to access capital or allocation of capital to other investments or business opportunities. 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 significant adverse impact on earnings. 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.

Page 29

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Energy Services Segment

Our Energy Services segment 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. Despite these ongoing market challenges, NJRES has been able recover value that had been stranded due to these factors. This allowed NJRES to reduce its overall transportation and storage costs while allowing strategic additions to its portfolio. NJRES continues to explore and recognize opportunities to provide asset management services to exploration and production companies working on the development of these natural gas resources.

Page 30

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.

Midstream Investments Segment

Our Midstream Investment segment (formerly Energy Holdings segment) consists of NJR's subsidiary, NJREH, which invests in natural gas assets, such as natural gas transportation and storage facilities. NJR believes that acquiring, owning and developing these midstream investments, 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 pursuing other potential opportunities that meet its investment and development criteria.

As of June 30, 2013, NJR's investments in Steckman Ridge and Iroquois, including capitalized costs and equity in earnings, net of cash distributions received, were $130.7 million and $23.9 million, respectively.

Retail and Other Operations

Our Retail and Other operations financial results have consisted primarily of the operating results of NJRHS, CR&R, and NJR Energy. NJRHS provides service, sales and installation of appliances to approximately 129,800 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 buildings. 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, 2012. NJR's critical accounting policies have not changed from those reported in the 2012 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.

Page 31

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							Nine Months Ended
	June 30,							June 30,
(Thousands)	2013		2012			% change		2013		2012		% change
Operating revenues	$	767,469	$	425,121		80.5	%	$	2,464,373	$	1,680,453	46.6	%
Gas purchases	$	649,242	$	379,318		71.2	%	$	2,016,597	$	1,331,721	51.4	%
Net income (loss)	$	29,155	$	(10,320	)	382.5	%	$	134,830	$	101,572	32.7	%

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 increased during the three and nine months endedJune 30, 2013, compared with the three and nine months endedJune 30, 2012, due primarily to:

• higher average commodity prices at NJRES, which correlate to the higher average price levels on the NYMEX, coupled with increased volumes; and

• bill credits of $85.9 million issued to NJNG customers during the nine months endedJune 30, 2012, that did not recur during the the same period in fiscal 2013, along with higher sales due primarily to weather being colder than the prior period and increased off-system sales, partially offset by decreases in firm sales to customers impacted by Superstorm Sandy.

Earnings for the three months endedJune 30, 2013, were $0.70 per both basic and diluted shares, compared with $(0.25) per both basic and diluted shares for the three months endedJune 30, 2012.

Changes in net income for the three months endedJune 30, 2013, were primarily driven by:

• an increase at NJRES due primarily to changes in realized and unrealized derivative gains, partially offset by

• a decrease at NJNG due primarily to increasedoperating expense, partially offset by increased margin.

Earnings for the nine months endedJune 30, 2013, were $3.23 per basic share and $3.22 per diluted share, compared with $2.45 per basic share and $2.44 per diluted share for the nine months endedJune 30, 2012.

Changes in net income for the three and nine months endedJune 30, 2013, were primarily driven by:

• an increase at NJRES due primarily to changes in realized and unrealized derivative gains, partially offset by

• a decrease in investment tax credits associated with solar projects at Clean Energy Ventures, and

• a decrease at NJNG due primarily to increasedoperation and maintenance and depreciation expenses and lower utility gross margin.

Page 32

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

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.

Operating Results

NJNG's financial results are as follows:

	Three Months Ended				Nine Months Ended
	June 30,				June 30,
(Thousands)	2013		2012		2013		2012
Utility gross margin
Operating revenues	$	119,022	$	106,764	$	689,621	$	524,161
Less:
Gas purchases	56,559		46,780		363,646		214,934
Energy and other taxes	6,852		6,255		43,619		32,491
Regulatory rider expense	6,258		5,835		44,014		36,821
Total utility gross margin	49,353		47,894		238,342		239,915
Operation and maintenance expenses	28,414		26,200		82,310		78,386
Depreciation and amortization	9,537		8,860		28,213		26,241
Other taxes not reflected in utility gross margin	1,063		894		3,381		3,035
Operating income	10,339		11,940		124,438		132,253
Other income	773		436		2,517		1,095
Interest expense, net of capitalized interest	3,796		3,717		10,929		11,167
Income tax provision	1,788		1,114		39,089		43,726
Net income	$	5,528	$	7,545	$	76,937	$	78,455

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 revenues 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 BGSS incentive programs. Any underrecoveries or overrecoveries from the projected amounts are deferred and reflected in the BGSS tariff rate in subsequent years.

TEFA, which is included in energy and other taxes on the Unaudited Condensed Consolidated Statements of Operations, is calculated on a per-therm basis and excludes sales to cogeneration facilities, other utilities and off-system sales. TEFA represents a regulatory allowed assessment imposed on all energy providers in the State of New Jersey. TEFA replaced the previously used utility gross receipts and franchise tax formula. As of January 1, 2012, TEFA is being phased out over a three-year period.

Regulatory rider expenses consist of recovery of state-mandated programs, the Remediation Adjustment (RA) and energy efficiency costs. These expenses are offset by corresponding revenues and are calculated on a per-therm basis.

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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's operating revenues and gas purchases increased by $12.3 million, or 11.5 percent, and by $9.8 million, or 20.9 percent, respectively, during the three months endedJune 30, 2013, compared with the three months endedJune 30, 2012, as a result of:

• an increase in operating revenues and gas purchases related to firm sales in the amount of $7.3 million and $3.2 million, respectively, as a result of higher sales due primarily to weather being 34.3 percentcolder than the prior year, partially offset by a decrease in operating revenues of $2.6 million, as a result of lower CIP accruals, along with a decrease of $1.1 million in operating revenues and $500,000 in gas purchases resulting from lower usage by customers that were impacted by Superstorm Sandy;

• an increase in operating revenues and gas purchases related to off-system sales in the amount of $6.1 million and $6.2 million, respectively, due primarily to a 73.5 percentincrease in the average cost of natural gas sold, partially offset by a 20.7 percentreduction in volumes of natural gas sold. Variations in sales volumes and revenues are the result of opportunities in the wholesale energy market that occur around NJNG's portfolio of capacity on a day-to-day basis; and

• an increase in operating revenues and gas purchases related to firm sales in the amount of $2.5 million and $2.4 million, respectively, as a result of an increase in the average BGSS rate per therm.

NJNG's operating revenues and gas purchases increased by $165.5 million, or 31.6 percent, and by $148.7 million, or 69.2 percent, respectively, during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012, as a result of:

• an increase in operating revenues and gas purchases related to firm sales in the amount of $90.3 million and $44 million, respectively, as a result of higher sales due primarily to weather being 25.3 percentcolder than the prior year, partially offset by a decrease in operating revenues of $28.8 million, as a result of lower CIP accruals, along with a decrease of $8.2 million in operating revenues and $4.1 million in gas purchases resulting from lower usage by customers that were impacted by Superstorm Sandy;

• an increase in operating revenues and gas purchases in the amount of $85.9 million and $80.2 million, respectively, due to bill credits, inclusive of sales tax refunds of $5.7 million, during the nine months endedJune 30, 2012, that did not recur during the nine months endedJune 30, 2013;

• an increase in operating revenues and gas purchases related to off-system sales in the amount of $30.3 million and $31.3 million, respectively, due primarily to a 22 percentincrease in the average cost of natural gas sold, coupled with an 8.7 percentincrease in volumes of natural gas sold. Variations in sales volumes and revenues are the result of opportunities in the wholesale energy market that occur around NJNG's portfolio of capacity on a day-to-day basis; partially offset by

• a decrease in operating revenues and gas purchases related to firm sales in the amount of $4.1 million and $3.9 million, respectively, as a result of a decrease in the average BGSS rate per therm.

Sales tax and TEFA, which are presented as both components of operating revenues and energy and other taxes on the Unaudited Condensed Consolidated Statements of Operations, totaled $6.9 million and $6.3 million during the three months endedJune 30, 2013 and 2012, respectively and $43.6 million and $32.5 million during the nine months endedJune 30, 2013 and 2012, respectively. The increase in sales tax of $786,000 and $12 million during the three and nine months endedJune 30, 2013, respectively, correlates directly to the changes in operating revenues from firm sales. TEFA, which is calculated on a per-therm basis, decreased$189,000 and $832,000 during the three and nine months endedJune 30, 2013, respectively, primarily due to the phasing in of the TEFA tax reductions.

Regulatory rider expenses increased$423,000 and $7.2 million during the three and nine months endedJune 30, 2013, respectively, due primarily to a 11.4 percent and 20.8 percentincrease in sales, respectively, partially offset by a 3.6 percent and .9 percentdecrease in rates, compared with the three and nine months endedJune 30, 2012, respectively. Regulatory rider expenses are offset by a corresponding increase in operating revenues.

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.

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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)

• BGSS 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.

The following table summarizes Utility Gross Margin and Throughput in Bcf of natural gas by type:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
	2013			2012			2013			2012
($ in thousands)	Margin		Bcf	Margin		Bcf	Margin		Bcf	Margin		Bcf
Utility gross margin/throughput
Residential	$	28,277	5.0	$	28,752	4.5	$	147,398	35.7	$	153,478	30.3
Commercial, industrial and other	8,460		1.0	8,363		0.9	38,112		6.9	38,874		5.9
Firm transportation	10,555		2.3	8,810		1.9	46,450		13.7	39,341		10.0
Total utility firm gross margin/throughput	47,292		8.3	45,925		7.3	231,960		56.3	231,693		46.2
BGSS incentive programs	1,896		31.4	1,839		22.4	6,014		103.7	7,898		71.2
Interruptible	165		2.4	130		2.4	368		7.3	324		5.5
Total utility gross margin/throughput	$	49,353	42.1	$	47,894	32.1	$	238,342	167.3	$	239,915	122.9

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$1.4 million and $267,000 during the three and nine months endedJune 30, 2013, compared with the three and nine months endedJune 30, 2012, respectively. The increase in utility firm gross margin was due primarily to customer growth and accelerated infrastructure investments, partially offset by the temporary suspension of service to the areas within NJNG's distribution territory that were affected by Superstorm Sandy.

Utility firm gross margin from residential sales decreased$475,000 and $6.1 million, respectively, during the three and nine months endedJune 30, 2013, compared with the three and nine months endedJune 30, 2012, due primarily to the transfers of residential sales customers into the transportation service. The decrease from residential sales was also impacted by Superstorm Sandy, which contributed $395,000 and $2.7 million of the overall decrease, during the three and nine months endedJune 30, 2013, respectively.

Utility firm gross margin from transportation service increased$1.7 million and $7.1 million, during the three and nine months endedJune 30, 2013, compared with the three and nine months endedJune 30, 2012, respectively. The improvement was due primarily to an increase in customers that transferred to transportation from residential sales, as discussed above, along with customers that transferred from commercial sales. These customer transfers are caused by increased marketing activity by third party natural gas providers in NJNG's distribution territory. The transfer of customers from residential and commercial sales to transportation services has no impact on NJNG's total utility firm gross margin. NJNG had 53,307 and 37,717 residential customers and 10,214 and 9,087 commercial customers using its transportation service at June 30, 2013 and 2012, respectively.

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

	Three Months Ended				Nine Months Ended
	June 30,				June 30,
(Thousands)	2013		2012		2013		2012
Weather (1)	$	841	$	4,270	$	4,463	$	30,243
Usage	3,065		2,190		9,451		12,430
Total	$	3,906	$	6,460	$	13,914	$	42,673

(1) Compared with the twenty-year average, weather was 3.2 percent and .9 percentwarmer-than-normal during the three and nine months endedJune 30, 2013, respectively and 28.6 percent and 22.2 percentwarmer-than-normal during the three and nine months endedJune 30, 2012, respectively.

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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)

BGSS Incentive Programs

Utility gross margin generated by NJNG's BGSS incentive programs remained relatively flat for the three months endedJune 30, 2013, compared with the three months endedJune 30, 2012. Utility gross margin generated by NJNG's BGSS incentive programs decreased$1.9 million during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012. The decrease during the current nine-month period was due primarily to lower gross margin related to off-system sales and storage incentive described further as follows:

• an increase in gas supply in the northeast resulting in lower volatility contributed to the decrease in transport capacity values and reduced margins in off-system sales; and

• a combination of timing of natural gas storage injections and reduction in volume factored into the decrease in margins from our storage incentive program.

Operating Expenses

Operation and maintenance expenses increased$2.2 million and $3.9 million during the three and nine months endedJune 30, 2013, respectively, due primarily to increased labor costs, timing of pipeline integrity costs and donations. Depreciation expense during the three and nine months endedJune 30, 2013, increased$677,000 and $2 million, respectively, compared with the three and nine months endedJune 30, 2012, as a result of additional utility plant being placed into service.

Operating Income

Operating income decreased$1.6 million during the three months endedJune 30, 2013 compared with the three months endedJune 30, 2012, due primarily to the increases in operation and maintenance and depreciation expenses, as previously discussed, offset by the increase in total utility gross margin of $1.5 million.

Operating income decreased$7.8 million, during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012, due primarily to the decrease in total utility gross margin of $1.6 million and increases in operation and maintenance and depreciation expense, as previously discussed.

Net Income

Net income decreased$2 million, or 26.7 percent, to $5.5 million during the three months endedJune 30, 2013, compared with the three months endedJune 30, 2012, due primarily to the decrease in operating income as previously discussed along with certain state tax refunds that were recognized in the three months endedJune 30, 2012 and did not recur in the three months endedJune 30, 2013.

Net income decreased$1.5 million, or 1.9 percent, to $76.9 million during the nine months endedJune 30, 2013 compared with the nine months endedJune 30, 2012, due primarily to the decrease in operating income as previously discussed, partially offset bya decrease in the income tax provision corresponding to the lower operating income. In addition, the decrease in the income tax provision is partially due to a lower effective tax rate for the nine months endedJune 30, 2013. The lower rate is due primarily to an increase in the forecasted cost of removal for fiscal 2013 related to equipment that was placed into service prior to 1981, for which there is a higher tax benefit.

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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)

Clean Energy Ventures Segment

Operating Results

The financial results of NJRCEV are summarized as follows:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Operating revenues	$	2,563		$	370		$	7,182		$	1,277
Operation and maintenance expenses	$	2,302		$	2,652		$	6,276		$	5,794
Depreciation and amortization	$	2,196		$	1,632		$	6,131		$	3,953
Income tax (benefit)	$	(1,477	)	$	(3,013	)	$	(15,703	)	$	(30,010	)
Net (loss) income	$	(1,381	)	$	(1,157	)	$	9,078		$	20,802

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 endedJune 30, 2013 and 2012. During the nine months endedJune 30, 2013, NJRCEV placed into service two commercial projects totaling approximately 9.1 MW of solar capacity. There were four commercial projects totaling 20.2 MW placed into service during the nine months endedJune 30, 2012.

In addition, during the three months endedJune 30, 2013, NJRCEV's residential solar leasing program installed approximately 2.7 MW of capacity on 304 homes, compared with 2 MW of capacity on 264 homes during the three months endedJune 30, 2012. During the nine months endedJune 30, 2013, NJRCEV's residential solar leasing program installed approximately 5.1 MW of capacity on 598 homes compared with 4 MW of capacity on 536 homes during the nine months endedJune 30, 2012.

Operating revenues generated during the three and nine months endedJune 30, 2013, consisted primarily of the sale of SRECs. During the three months endedJune 30, 2013, NJRCEV sold 13,861 SRECs compared with zero during the three months endedJune 30, 2012, and sold 46,223 SRECs during the nine months endedJune 30, 2013, compared with 3,433 during the nine months endedJune 30, 2012.

As of June 30, 2013, NJRCEV has 19,288 SRECs available for sale compared with 17,327 as of June 30, 2012. In addition, NJRCEV hedges a portion of its expected SREC production through forward sale contracts. As of June 30, 2013, NJRCEV has hedged the expected output of approximately 37 percent of its existing commercial assets for energy years 2014 through 2016.

Operating revenues consist of the following:

	Three Months Ended				Nine Months Ended
	June 30,				June 30,
(Thousands)	2013		2012		2013		2012
SREC sales	$	1,793	$	—	$	5,652	$	645
Energy sales and other	770		370		1,530		632
Total operating revenues	$	2,563	$	370	$	7,182	$	1,277

Operation and maintenance expenses decreased by $350,000 and increased by $482,000 during the three and nine months endedJune 30, 2013, respectively, as compared with the three and nine months endedJune 30, 2012, due primarily to increased labor and shared corporate services costs and decreased legal and consulting costs.

Depreciation expense increased$564,000 during the three months endedJune 30, 2013, as compared with the three months endedJune 30, 2012, and increased$2.2 million during the nine months endedJune 30, 2013, as compared with the nine months endedJune 30, 2012, as a result of additional solar projects being placed into service.

The net income tax benefit related to ITCs during the three months endedJune 30, 2013 and 2012, was $313,000 and $1.4 million, respectively. During the nine months endedJune 30, 2013 and 2012, income tax benefit related to ITCs was $13.1 million and $27.2 million, respectively.

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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 three and nine months endedJune 30, 2013, NJRCEV had solar projects with a cost of $9.2 million and $43.8 million, respectively, placed into service compared with $6.6 million and $107.1 million placed into service during the three and nine months endedJune 30, 2012, respectively.

Net income remained relatively flat during the three months ended June 30, 2013 compared with the three months endedJune 30, 2012. Net income decreased$11.7 million during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012, due primarily to decreased ITCs coupled with increased interest and depreciation expenses, partially offset by an increase in revenue and other income. Other income includes $1 million related to the settlement of a legal claim, as well as an insurance recovery of $954,000, which represents the replacement value of solar assets that were damaged by Superstorm Sandy.

Energy Services Segment

Operating Results

NJRES' financial results are summarized as follows:

	Three Months Ended					Nine Months Ended
	June 30,					June 30,
(Thousands)	2013		2012			2013		2012
Operating revenues	$	633,533	$	306,241		$	1,741,081	$	1,129,251
Gas purchases (including demand charges) (1)	593,730		333,689			1,661,362		1,122,884
Gross margin	39,803		(27,448		)	79,719		6,367
Operation and maintenance expenses	3,595		3,558			10,190		10,654
Depreciation and amortization	10		16			32		48
Other taxes	416		179			956		833
Operating income (loss)	35,782		(31,201		)	68,541		(5,168		)
Other income	—		9			—		35
Interest expense, net	615		214			1,823		729
Income tax provision (benefit)	12,945		(11,511		)	23,906		(2,108		)
Net income (loss)	$	22,222	$	(19,895	)	$	42,812	$	(3,754	)

(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.

As of June 30, 2013, NJRES' portfolio of financial derivative instruments was comprised of:

• 50.2Bcf of net short futures contracts

As of June 30, 2012, NJRES' portfolio of financial derivative instruments was comprised of:

• 38.8Bcf of net short futures contracts and fixed swap positions; and

• 6.0Bcf 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 nine months endedJune 30, 2013, operating revenues increased$327.3 million and $611.8 million respectively, and gas purchases increased$260 million and $538.5 million, respectively, due primarily to increases in volume, as well as higher average prices, which correlate to the higher price levels on the NYMEX. NYMEX prices averaged $4.09 per MMBtu during the three months endedJune 30, 2013 compared with $2.22per MMBtu during the three months endedJune 30, 2012, and averaged $3.61 per MMBtu during the nine months endedJune 30, 2013, compared with $2.84per MMBtu during the nine months endedJune 30, 2012.

Page 38

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Gross margin

Gross margin during the three and nine months endedJune 30, 2013, was higher by approximately $67.3 million and $73.4 million, respectively, compared with the three and nine months endedJune 30, 2012, due primarily to an increase of $78.2 million and $41.6 million in unrealized gains during the three and nine months endedJune 30, 2013, respectively, partially offset by a decrease of $23.5 million in realized gains during the three months endedJune 30, 2013, and an increase of $26.6 million during the nine months endedJune 30, 2013, as a result of timing differences in the settlement of certain economic hedges, which are described further below.

NJRES recognizes unrealized gains (losses) associated with its 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 incurs realized gains (losses) relating to the effects of economic hedging related to natural gas inventory. These realized amounts 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.

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 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.

Page 39

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

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

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Operating revenues	$	633,533		$	306,241		$	1,741,081		$	1,129,251
Less: Gas purchases	593,730			333,689			1,661,362			1,122,884
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(45,267		)	32,981			(24,312		)	17,316
Effects of economic hedging related to natural gas inventory	13,440			(10,096		)	(9,425		)	17,184
Financial margin	$	7,976		$	(4,563	)	$	45,982		$	40,867

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

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Operating income (loss)	$	35,782		$	(31,201	)	$	68,541		$	(5,168	)
Add:
Operation and maintenance expenses	3,595			3,558			10,190			10,654
Depreciation and amortization	10			16			32			48
Other taxes	416			179			956			833
Subtotal - Gross margin	39,803			(27,448		)	79,719			6,367
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(45,267		)	32,981			(24,312		)	17,316
Effects of economic hedging related to natural gas inventory	13,440			(10,096		)	(9,425		)	17,184
Financial margin	$	7,976		$	(4,563	)	$	45,982		$	40,867

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

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Net income (loss)	$	22,222		$	(19,895	)	$	42,812		$	(3,754	)
Add:
Unrealized (gain) loss on derivative instruments and related transactions, net of taxes	(28,623		)	20,854			(15,373		)	10,949
Effects of economic hedging related to natural gas inventory, net of taxes	8,498			(6,384		)	(5,960		)	10,866
Net financial earnings	$	2,097		$	(5,425	)	$	21,479		$	18,061

Financial margin increased$12.5 million and $5.1 million during the three and nine months endedJune 30, 2013, compared with the three and nine months endedJune 30, 2012, due primarily to higher financial margin from storage assets, offset by the timing of certain transactions related to storage and narrower price spreads resulting in lower financial margin from transportation assets. A general decrease in opportunities to generate financial margin from the optimization of transportation and storage assets in NJRES' market area remains in the current market climate. 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. Despite these ongoing market challenges, NJRES was able recover value that had been stranded due to these factors. This allowed NJRES to reduce its overall transportation and storage costs while allowing strategic additions to its portfolio.

Page 40

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Operating Expenses

Operation and maintenance expenses remained relatively flat during the three months endedJune 30, 2013, compared with the three months endedJune 30, 2012 and decreased$464,000 during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012. The decrease was due primarily to decreases in shared corporate services costs and legal expenses, partially offset by increases in labor costs.

Net Financial Earnings

NFE increased$7.5 million during the three months endedJune 30, 2013, compared with the three months endedJune 30, 2012, due primarily to higher financial margin from storage assets. During the nine months endedJune 30, 2013, NFE increased$3.4 million during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012, due primarily to higher financial margin from storage assets and a favorable tax audit adjustment during the current year, partially offset by lower financial margin from transportation assets.

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.

Midstream Investments Segment

Operating Results

The financial results of Midstream Investments are summarized as follows:

	Three Months Ended				Nine Months Ended
	June 30,				June 30,
(Thousands)	2013		2012		2013		2012
Equity in earnings of affiliates	$	3,052	$	3,547	$	11,012	$	11,129
Operation and maintenance expenses	$	143	$	400	$	561	$	673
Interest expense, net	$	201	$	386	$	734	$	1,250
Net income	$	1,541	$	1,634	$	5,600	$	5,438

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				Nine Months Ended
	June 30,				June 30,
(Thousands)	2013		2012		2013		2012
Iroquois	$	1,011	$	1,196	$	4,369	$	4,033
Steckman Ridge	2,041		2,351		6,643		7,096
Total equity in earnings	$	3,052	$	3,547	$	11,012	$	11,129

Page 41

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Retail and Other Operations

Operating Results

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

	Three Months Ended				Nine Months Ended
	June 30,				June 30,
(Thousands)	2013		2012		2013		2012
Operating revenues	$	13,704	$	11,992	$	32,842	$	29,300
Operation and maintenance expenses	$	9,421	$	8,297	$	28,099	$	24,110
Net income	$	1,944	$	1,549	$	813	$	860

Operating revenues increased$1.7 million and $3.5 million, during the three and nine months endedJune 30, 2013, respectively, compared with the three and nine months endedJune 30, 2012, due primarily to increased Home Services installations following Superstorm Sandy, which caused an increase in demand for generators and other equipment.

Operation and maintenance expenses increased$1.1 million during the three months endedJune 30, 2013, compared with the three months endedJune 30, 2012 and increased$4 million during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012, due primarily to higher equipment and labor costs corresponding to the increase in installations as discussed above.

Net income increased$395,000 during the three months endedJune 30, 2013 compared to the three months endedJune 30, 2012 due primarily to increased revenues, partially offset by higher equipment and labor costs. Net income remained relatively flat during the nine months endedJune 30, 2013, compared with the nine months endedJune 30, 2012.

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:

	June 30, 2013		September 30, 2012
Common stock equity	50	%	50	%
Long-term debt	29		32
Short-term debt	21		18
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 Direct Stock Purchase and Dividend Reinvestment Plan (DRP), which was amended and restated on January 25, 2013, 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. On January 25, 2013, NJR registered 2 million shares of NJR common stock for issuance under the DRP.

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. On July 10, 2013, the Board approved an increase in the number of shares authorized for repurchase under NJR's Share Repurchase Plan by 1 million shares to a total of 9.75 million shares. As of June 30, 2013, the Company repurchased a total of approximately 8 million of the authorized shares.

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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)

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 the issuance of long-term debt.

NJR believes that as of June 30, 2013, 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.

On May 12, 2011, NJR entered into an unsecured, uncommitted $100 million private placement shelf note agreement (the MetLife Facility) with Metropolitan Life Insurance Company (MetLife). The MetLife Facility allowed NJR to issue senior notes to MetLife or certain of MetLife's affiliates from time to time during a two-year issuance period that expired on May 10, 2013. As of June 30, 2013, under the terms of the agreement, NJR has $25 million of 1.94 percent senior notes due September 15, 2015, and $25 million of 2.51 percent senior notes due September 15, 2018 issued and outstanding under the MetLife Facility.

On June 30, 2011, NJR entered into an unsecured, uncommitted $75 million private placement shelf note agreement (the Prudential Facility) with Prudential Investment Management, Inc. (Prudential). The Prudential Facility, subject to the terms and conditions set forth therein, allows NJR to issue senior notes to Prudential or certain of Prudential's affiliates from time to time during a three-year issuance period ending June 30, 2014, the terms and conditions, including interest rates and maturity dates, to be agreed upon in connection with each note issuance. NJR has issued $50 million of 3.25 percent senior notes due September 17, 2022 under the Prudential Facility. As of June 30, 2013, $25 million remains available for borrowing under the Prudential Facility.

As of June 30, 2013, NJNG's long-term debt, including current maturities, consisted of a $60 million, 4.77 percent unsecured senior note maturing in March 2014, $222.8 million in secured fixed rate debt with maturities ranging from 2018 to 2040 , $97 million in secured variable rate debt with maturities ranging from 2027 to 2041 and $54.6 million in capital leases with various maturities ranging from 2013 to 2021.

On April 15, 2013, NJNG issued $50 million of 3.15 percent senior secured notes (3.15 percent notes) due April 15, 2028, in the private placement market pursuant to a note purchase agreement entered into on February 8, 2013. The 3.15 percent notes are secured by an equal principal amount of NJNG's First Mortgage Bonds (Series PP) issued under NJNG's Indenture of Mortgage and Deed of Trust dated April 1, 1952, between NJNG and The Bank of New York Mellon Trust Company, N.A. (as successor to BNY Midwest Trust Company) in its capacity as Trustee, as amended and supplemented to date and from time to time, including by the Thirty-Fourth Supplemental Indenture dated as of April 1, 2013, (Mortgage Indenture), until the Release Date (which as defined in the note purchase agreement is the date at which the security provided by the pledge under the Mortgage Indenture would no longer be available to holders of any outstanding series of NJNG's senior secured notes and such indebtedness would become senior unsecured indebtedness). The proceeds from the 3.15 percent notes were used to refinance short-term debt and will fund capital expenditure requirements.

The 3.15 percent notes are subject to required prepayments upon the occurrence of certain events and NJNG may at any time prepay all or a portion of the 3.15 percent notes at a make-whole prepayment price. The note purchase agreement contains customary representations and warranties of NJNG and the purchasers and also contains customary events of default and certain covenants which will limit NJNG's ability beyond agreed upon thresholds, to, among other things: (i) incur additional debt (including a covenant which limits the amount of Consolidated Total Debt of the Company at the end of a fiscal quarter to 65 percent of the Consolidated Total Capitalization of the Company, as those terms are defined in the Note Purchase Agreement and a covenant limiting Priority Debt to 20 percent of the Company's Consolidated Total Capitalization, as those terms are defined in the Note Purchase Agreement); (ii) incur liens; (iii) make dispositions of assets; (iv) enter into transactions with affiliates; and (v) merge,

Page 43

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

consolidate, transfer, sell or lease all or substantially all of NJNG's assets. These covenants are subject to a number of important exceptions and qualifications set forth in the Note Purchase Agreement.

NJR is not obligated directly or contingently with respect to the 3.15 percent notes or the First Mortgage Bonds.

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 (NJR Credit Facility), which expires on August 22, 2017. 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, PNC Bank, N.A.'s Prime Rate, 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 (NJNG Credit Facility), which expires in August 2014. 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. On November 30, 2012, NJNG utilized the accordion option available under its committed revolving syndicated credit facility to increase the amount of credit available from $200 million to $250 million.

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.

Short-term borrowings were as follows:

	Three Months Ended			Nine Months Ended
(Thousands)	June 30, 2013
NJR
Notes Payable to banks:
Balance at end of period	$	200,900		$	200,900
Weighted average interest rate at end of period	1.12		%	1.12		%
Average balance for the period	$	179,079		$	182,812
Weighted average interest rate for average balance	1.13		%	1.13		%
Month end maximum for the period	$	200,900		$	200,900
NJNG
Commercial Paper and Notes Payable to banks:
Balance at end of period	$	96,000		$	96,000
Weighted average interest rate at end of period	0.15		%	0.15		%
Average balance for the period	$	63,953		$	128,398
Weighted average interest rate for average balance	0.15		%	0.17		%
Month end maximum for the period	$	96,000		$	204,800

Page 44

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

NJR

As noted above, based on its average borrowings during the nine months endedJune 30, 2013, NJR's average interest rate was 1.13 percent, resulting in interest expense of $1.6 million. Based on average borrowings under the NJR Credit Facility of $182.8 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 $1.4 million during the nine months endedJune 30, 2013.

As of June 30, 2013, NJR has four letters of credit outstanding totaling $16.4 million, which reduces the amount available under the NJR Credit Facility by the same amount.

On June 5, 2013, NJR entered into a new agreement allowing issuances of stand-alone letters of credit through June 5, 2014, up to a total of $10 million. No amounts have been drawn under this arrangement as of June 30, 2013.

NJNG

During the nine months endedJune 30, 2013, based on its average borrowings NJNG's weighted average interest rate under the NJNG Credit Facility was .17 percent, resulting in interest expense of $172,000. Based on average borrowings under the facility of $128.4 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 $972,000 during nine months endedJune 30, 2013.

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

On October 4, 2012, the BPU approved a petition filed by NJNG requesting authorization over a three-year period to issue debt, renew its revolving credit facility expiring August 2014, renew its credit facility supporting NJNG's obligations with respect to bonds issued by the New Jersey Economic Development Authority, enter into interest rate risk management transactions and increase the size of its meter leasing program on a permanent basis.

Sale-Leaseback

NJNG received $7.1 million and $6.5 million in December 2012 and 2011, respectively, in connection with the sale-leaseback of its natural gas meters. NJNG expects to continue this sale-leaseback program on an annual basis, subject to market conditions.

Contractual Obligations

In conjunction with NJR's goal to promote clean energy, NJRCEV has entered into various agreements to install solar equipment involving both residential and commercial projects. 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. Total solar-related capital expenditures during the nine months endedJune 30, 2013 were $39.8 million. The Company currently estimates solar-related capital expenditures between $55 million and $60 million during fiscal 2013, of which $51.1 million has been committed or spent. Solar-related capital expenditures in fiscal 2014 are estimated by the Company to be between $70 million and $90 million.

In October 2012, Superstorm Sandy caused significant damage to portions of NJNG's distribution infrastructure. As of June 30, 2013, total capital expenditures associated with the restoration of the affected portions of distribution main are estimated to be between $30 million to $40 million. NJNG expects to spend between $26 million to $30 million during fiscal 2013, with the remainder being spent over the following three fiscal years. As with normal operations, capital costs will be treated as additions to NJNG's rate base on which recovery will be sought in a future base rate case. In addition, on November 19, 2012, NJNG filed a petition with the BPU requesting deferral accounting for uninsured incremental operating and maintenance costs associated with Superstorm Sandy. On May 29, 2013, NJNG received approval from the BPU regarding the deferral of Superstorm Sandy related to O&M costs. NJNG also requested the review of and the appropriate amortization period for such deferred expenses be addressed in the Company's next base rate case. However, there can be no assurances that such recovery mechanisms will be available or, if available, no assurances can be given relative to the timing or amount of such recovery. As of June 30, 2013, NJNG has approximately $14.9 million of deferred costs in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets

Page 45

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

related to the restoration of its infrastructure and expects that total incremental operating and maintenance costs during fiscal 2013 will approximate between $15 million to $17 million.

On March 20, 2013, the BPU issued an order establishing a generic proceeding to review the prudency of costs incurred by New Jersey utility companies in response to Major Storm Events in 2011 and 2012. On July 1, 2013, NJNG filed its detailed report including unreimbursed, uninsured incremental storm restoration costs and capital expenditures related to Superstorm Sandy.

NJNG's total capital expenditures are estimated at $146.3 million and $119.9 million in fiscal 2013 and 2014, respectively, and consist primarily of Superstorm Sandy related costs and 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 2013 and 2014, include an estimated $29.9 million and $43.4 million, respectively, related to SAFE construction costs. As of June 30, 2013, NJNG's capital expenditures spent or committed were $100 million, of which, $11.5 million was related to AIP II, $15.7 million was related to SAFE and approximately $24.7 million was related to restoration from storm damages.

In November 2012, the BPU approved new state utilities' funding obligations for New Jersey Clean Energy Program (NJCEP) for the period from January 1, 2013 to June 30, 2013. NJNG's share of the total funding requirement was approximately $9.8 million. On June 21, 2013, the BPU approved NJNG's funding obligations for July 1, 2013 to June 30, 2014, of approximately $15.6 million. Accordingly, NJNG recorded the obligation and a corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets.

NJNG has sufficient liquidity to meet our current obligations and to fund restoration efforts from a combination of cash on hand and available capacity under revolving credit facilities.

Off-Balance-Sheet Arrangements

The Company does not have any off-balance-sheet arrangements, with the exception of guarantees covering approximately $381.5 million of natural gas purchases and demand fee commitments and outstanding letters of credit totaling $16.4 million, as noted above.

Cash Flow

Operating Activities

As presented on the Unaudited Condensed Consolidated Statements of Cash Flows, cash flow from operating activities totaled $125.1 million during the nine months endedJune 30, 2013, compared with $59.9 million during the nine months endedJune 30, 2012. 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;

•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.

Page 46

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

In addition to the factors noted above, the increase of $65.2 million in cash generated from operations during the nine months endedJune 30, 2013 as compared with the nine months endedJune 30, 2012, was impacted by:

• credits of $85.9 million issued to NJNG's customers during fiscal 2012 for overrecovered gas costs that did not recur in fiscal 2013;

• cash received totaling $17.9 million due to the sale of NJRES' MF Global bankruptcy claim; partially offset by

• additional expenditures of approximately $14.9 million related to Superstorm Sandy restoration efforts at NJNG that have been deferred as a regulatory asset;

Investing Activities

Cash flow used in investing activities totaled $132.5 million during the nine months endedJune 30, 2013, compared with $158.2 million during the nine months endedJune 30, 2012. The decrease was due primarily to lower capital expenditures related to solar projects at NJRCEV partially offset by higher utility plant expenditures and cost of removal as a result of Superstorm Sandy.

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 needs of the gas management and marketing functions at NJRES and renewable energy investments at NJRCEV.

Cash flow used in financing activities totaled $4.8 million during the nine months endedJune 30, 2013, compared with $97.9 million generated from financing activities during the nine months endedJune 30, 2012. The decrease is due primarily to lower short-term borrowings at NJNG partially offset by proceeds from the issuance of $50 million in long-term debt at NJNG.

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 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.

Page 47

New Jersey Resources Corporation

Part I

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

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/Chicago Mercantile Exchange (CME), the Intercontinental Exchange (ICE) 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. Financial derivatives have historically been transacted on an exchange and cleared through a Futures Commission Merchant (FCM), thus requiring daily cash margining for a majority of NJRES' and NJNG's positions. As a result of the Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank), certain of NJRES' and NJNG's other transactions that were previously executed in the over-the-counter markets are now cleared through an FCM, resulting in increased margin requirements. The related cash flow impact from the increased requirements is expected to be minimal. Non-financial (physical) derivatives utilized by the Company have received statutory exclusion from similar Dodd-Frank provisions due to the element of physical settlement.

The following table reflects the changes in the fair market value of financial derivatives related to natural gas purchases and sales from September 30, 2012 to June 30, 2013:

	Balance				Increase			Less				Balance
(Thousands)	September 30, 2012				(Decrease) in Fair Market Value			Amounts Settled				June 30, 2013
NJNG		$	2,169			$	363		$	1,727			$	805
NJRES		(7,969		)		34,761			(782		)		27,574
Total		$	(5,800	)		$	35,124		$	945			$	28,379

There were no changes in methods of valuations during the nine months endedJune 30, 2013.

The following is a summary of fair market value of financial derivatives at June 30, 2013, excluding foreign exchange contracts discussed below, by method of valuation and by maturity for each fiscal year period:

(Thousands)	2013		2014		2015 - 2017				After 2017			Total Fair Value
Price based on NYMEX/CME	$	9,313	$	6,243		$	269			$	—		$	15,825
Price based on ICE	10,065		4,021			(1,532		)		—			12,554
Total	$	19,378	$	10,264		$	(1,263	)		$	—		$	28,379

The following is a summary of financial derivatives by type as of June 30, 2013:

		Volume Bcf		Price per MMBtu	Amounts included in Derivatives (Thousands)
NJNG	Futures	17.0		$2.90 - $4.29		$	914
	Options	0.7		$0.24 - $0.33		(109		)
NJRES	Futures	(50.2	)	$2.91 - $5.03		27,574
Total						$	28,379

Page 48

New Jersey Resources Corporation

Part I

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

The following table reflects the changes in the fair market value of physical commodity contracts from September 30, 2012 to June 30, 2013:

	Balance			Increase			Less			Balance
(Thousands)	September 30, 2012			(Decrease) in Fair Market Value			Amounts Settled			June 30, 2013
NJRES - Prices based on other external data		$	10,502		(15,682	)		(3,661	)		$	(1,519	)

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 $20.5 million. This analysis does not include potential changes to reported credit adjustments embedded in the $26.5 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	0%		5%			10%			15%			20%
Estimated change in derivative fair value	$	—	$	(10,269	)	$	(20,539	)	$	(30,808	)	$	(41,077	)
Ending derivative fair value	$	26,453	$	16,184		$	5,914		$	(4,355	)	$	(14,624	)
Percent decrease in NYMEX natural gas futures prices	0%		(5)%			(10)%			(15)%			(20)%
Estimated change in derivative fair value	$	—	$	10,269		$	20,539		$	30,808		$	41,077
Ending derivative fair value	$	26,453	$	36,722		$	46,992		$	57,261		$	67,530

Wholesale Credit Risk

The following is a summary of gross and net credit exposures, grouped by investment and noninvestment grade counterparties, as of June 30, 2013. 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 June 30, 2013, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	189,500		$	134,489
Noninvestment grade		5,416			48
Internally rated investment grade		34,420			17,011
Internally rated noninvestment grade		4,335			3
Total		$	233,671		$	151,551

Page 49

New Jersey Resources Corporation

Part I

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

NJNG's counterparty credit exposure as of June 30, 2013, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	10,472		$	10,224
Noninvestment grade		263			—
Internally rated investment grade		272			224
Internally rated noninvestment grade		126			76
Total		$	11,133		$	10,524

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.

Information regarding NJR's interest rate risk can be found in Item 7A. Quantitative and Qualitative Disclosures About Market Risks and the Liquidity and Capital Resources - Debt section of Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operationsof its Annual Report on Form 10-K for the period ended September 30, 2012.

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.

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 Securities and Exchange Commission'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 June 30, 2013, that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

Page 50

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, 2012, and is set forth in Part I, Item 1, Note 11.Commitment and Contingent Liabilities-Legal Proceedings on the Unaudited Condensed Consolidated Financial Statements. No legal proceedings became reportable during the quarter ended June 30, 2013, 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 2012 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. There have been no material changes in our risk factors from those previously disclosed in Part I, Item 1A, of our 2012 Annual Report on Form 10-K and in Part II, Item 1A of our Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2013.

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

The following table sets forth NJR's repurchase activity for the quarter ended June 30, 2013:

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
04/01/13 - 04/30/13	72,400	$	45.43	72,400	1,138,069
05/01/13 - 05/31/13	257,600	$	46.07	257,600	880,469
06/01/13 - 06/30/13	162,100	$	44.54	162,100	718,369
Total	492,100	$	45.47	492,100	718,369

The stock repurchase plan, which was authorized by our Board of Directors, became effective in September 1996 and as of June 30, 2013, included 8.75 million shares of common stock for repurchase, of which, approximately 718,000 shares remained available 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.

On July 10, 2013, the Board approved an increase in the number of shares authorized for repurchase under NJR's Share Repurchase Plan by 1 million shares to a total of 9.75 million shares. The Share Repurchase Plan allows the Company to purchase its shares on the open market or in negotiated transactions, based on market and other conditions. The Company is not required to purchase any specific number of shares, and may discontinue or suspend the program at any time.

Page 51

New Jersey Resources Corporation

Part II

ITEM 6. EXHIBITS                                                                                                                                                                         

Exhibit Number Exhibit Description

3.1	Restated Articles of Incorporation of New Jersey Resources Corporation, as amended through July 10, 2013 (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K, as filed on July 16, 2013)
3.2	Bylaws of New Jersey Resources Corporation, as amended through July 10, 2013 (incorporated by reference to Exhibit 3.2 to the Current Report on Form 8-K, as filed on July 16, 2013)
4.2(e)	Thirty-Fourth Supplemental Indenture dated as of April 1, 2013 (incorporated by reference to Exhibit 4.2(e) to the Quarterly Report on Form 10-Q, as filed on May 3, 2013)
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 June 30, 2013, 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.

Page 52

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:	August 7, 2013
		By:/s/ Glenn C. Lockwood
		Glenn C. Lockwood
		Executive Vice President and
		Chief Financial Officer

Page 53

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:	August 7, 2013	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:	August 7, 2013	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 June 30, 2013, 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:	August 7, 2013	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 June 30, 2013, 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:	August 7, 2013	By:	/s/ Glenn C. Lockwood
			Glenn C. Lockwood
			Executive Vice President and Chief Financial Officer

XML

COMMITMENTS AND CONTINGENT LIABILITIES

9 Months Ended

Jun. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENT LIABILITIES

COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through August 2030, for the supply, storage and delivery of natural gas. These contracts include current annual fixed charges of approximately $99.7 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 June 30, 2013, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2013		2014		2015		2016		2017		Thereafter
NJRES:
Natural gas purchases	$	247,632	$	126,175	$	31,225	$	16,800	$	—	$	—
Storage demand fees	9,615		26,098		12,005		7,114		5,035		7,318
Pipeline demand fees	18,557		31,851		18,133		9,576		8,225		9,756
Sub-total NJRES	$	275,804	$	184,124	$	61,363	$	33,490	$	13,260	$	17,074
NJNG:
Natural gas purchases	$	37,843	$	94,047	$	103,080	$	8,755	$	113	$	—
Storage demand fees	7,061		28,208		21,283		11,956		9,990		23,247
Pipeline demand fees	15,504		75,442		41,596		34,558		32,753		221,838
Sub-total NJNG	$	60,408	$	197,697	$	165,959	$	55,269	$	42,856	$	245,085
Total (1)	$	336,212	$	381,821	$	227,322	$	88,759	$	56,116	$	262,159

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

NJNG's capital expenditures are estimated at $146.3 million and $119.9 million in fiscal 2013 and 2014, respectively, including estimates of $29.9 million and $43.4 million, respectively, related to SAFE construction costs. Expenditures consist primarily of NJNG's construction program to support customer growth, maintenance of its distribution system, replacement needed under pipeline safety regulations and costs associated with the restoration of damages to NJNG's infrastructure as a result of Superstorm Sandy. Approximately $100 million has been committed or spent on capital expenditures, including accruals, during the nine months endedJune 30, 2013. NJNG has committed or spent $15.7 million related to the SAFE program, $11.5 million related to AIP II program and $24.7 million related to restoration from storm damages during the nine months endedJune 30, 2013.

As of June 30, 2013, total capital expenditures associated with the restoration of the portions of distribution main affected by Superstorm Sandy are estimated to be between $30 million to $40 million. NJNG expects to spend between $26 million to $30 million during fiscal 2013, with the remainder, if any, being spent over the following three fiscal years.

NJRCEV's expenditures include discretionary spending on capital projects that support NJR's goal to promote clean energy. Accordingly, NJRCEV enters into agreements to install solar equipment involving both residential and commercial projects. Total solar-related capital expenditures during the nine months endedJune 30, 2013, were $39.8 million. The Company currently estimates solar-related capital expenditures between $55 million and $60 million during fiscal 2013, of which $51.1 million has been committed or spent. Solar-related capital expenditures in fiscal 2014 are estimated by the Company to be between $70 million and $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, if at all, ability to access capital or allocation of capital to other investments or business opportunities.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of five MGP sites, dating back to gas operations in the late 1800s and early 1900s that contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the 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. On March 20, 2013, the BPU approved the recovery of the remediation expenditures incurred through June 30, 2011, which maintained the expected annual recovery at approximately $20 million. On July 23, 2013, NJNG filed an SBC petition with the BPU requesting a reduction to the RA factor and approval of the related MGP expenditures for the period July 1, 2011 through June 30, 2013. As of June 30, 2013, $47.4 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 2012, 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 $159.6 million to $266.4 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. Accordingly, NJNG has recorded an MGP remediation liability and a corresponding regulatory asset of $182 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.

XML

COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) (USD $)	9 Months Ended
	Jun. 30, 2013
Long-term Purchase Commitment [Line Items]
Current charges recoverable through BGSS	$ 99,700,000
Natural Gas Purchases [Member] | NJRES [Member]
Long-term Purchase Commitment [Line Items]
2013	247,632,000
2014	126,175,000
2015	31,225,000
2016	16,800,000
2017	0
Thereafter	0
Natural Gas Purchases [Member] | NJNG [Member]
Long-term Purchase Commitment [Line Items]
2013	37,843,000
2014	94,047,000
2015	103,080,000
2016	8,755,000
2017	113,000
Thereafter	0
Storage Demand Fees [Member] | NJRES [Member]
Long-term Purchase Commitment [Line Items]
2013	9,615,000
2014	26,098,000
2015	12,005,000
2016	7,114,000
2017	5,035,000
Thereafter	7,318,000
Storage Demand Fees [Member] | NJNG [Member]
Long-term Purchase Commitment [Line Items]
2013	7,061,000
2014	28,208,000
2015	21,283,000
2016	11,956,000
2017	9,990,000
Thereafter	23,247,000
Pipeline Demand Fees [Member] | NJRES [Member]
Long-term Purchase Commitment [Line Items]
2013	18,557,000
2014	31,851,000
2015	18,133,000
2016	9,576,000
2017	8,225,000
Thereafter	9,756,000
Pipeline Demand Fees [Member] | NJNG [Member]
Long-term Purchase Commitment [Line Items]
2013	15,504,000
2014	75,442,000
2015	41,596,000
2016	34,558,000
2017	32,753,000
Thereafter	221,838,000
Natural Gas Purchases and Future Demand Fees [Member]
Long-term Purchase Commitment [Line Items]
2013	336,212,000	[1]
2014	381,821,000	[1]
2015	227,322,000	[1]
2016	88,759,000	[1]
2017	56,116,000	[1]
Thereafter	262,159,000	[1]
Natural Gas Purchases and Future Demand Fees [Member] | NJRES [Member]
Long-term Purchase Commitment [Line Items]
2013	275,804,000
2014	184,124,000
2015	61,363,000
2016	33,490,000
2017	13,260,000
Thereafter	17,074,000
Natural Gas Purchases and Future Demand Fees [Member] | NJNG [Member]
Long-term Purchase Commitment [Line Items]
2013	60,408,000
2014	197,697,000
2015	165,959,000
2016	55,269,000
2017	42,856,000
Thereafter	$ 245,085,000

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

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parentheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Tax on Unrealized gain (loss) on available for sale securities	$ (9)	$ (79)	$ (235)	$ (104)
Tax on Net unrealized (loss) on derivatives	13	8	23	49
Tax on adjustment for postemployment benefit obligation	$ (203)	$ (149)	$ (608)	$ (448)

XML

DERIVATIVE INSTRUMENTS

9 Months Ended

Jun. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS

The Company is subject to commodity price risk due to fluctuations in the market price of natural gas. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas. In addition, the Company may utilize foreign currency derivatives as cash flow hedges of Canadian dollar denominated gas purchases. These contracts, with a few exceptions as described below, are accounted for as derivatives. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company's fair value measurement policies and level disclosures associated with the NJR's derivative instruments, see Note 5. Fair Value.

Since the Company chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges, changes in the fair value of these derivative instruments are recorded as a component of gas purchases or operating revenues, as appropriate for NJRES, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or (losses). For NJRES at settlement, realized gains and (losses) on all financial derivative instruments are recognized as a component of gas purchases and realized gains and (losses) on all physical derivatives follow the presentation of the related unrealized gains and (losses) as a component of either gas purchases or operating revenues.

NJRES also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the US dollar. NJRES utilizes foreign currency derivatives to lock in the currency translation rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are being used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company has designated these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in other comprehensive income (OCI). When the foreign exchange contracts are settled, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that may ultimately be repaid, based on changes in forward natural gas prices during the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings.

Changes in fair value of NJNG's financial derivative instruments are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets, as NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff.

The Company elects normal purchase/normal sale (NPNS) accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, gains or (losses) are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered.

During fiscal 2012, NJRCEV began economically hedging certain of its expected production of solar renewable energy certificates (SRECs) through forward sale contracts. The Company intends to physically deliver the SRECs upon settlement and, therefore, applies NPNS accounting treatment to the contracts and recognizes related revenue upon transfer of the SRECs.

Fair Value of Derivatives

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

			Fair Value
			June 30, 2013						September 30, 2012
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	51		$	17		$	116		$	97
	Derivatives - noncurrent		—			23			70			15
Fair value of derivatives designated as hedging instruments			$	51		$	40		$	186		$	112
Derivatives not designated as hedging instruments:
NJNG:
Financial derivative contracts	Derivatives - current		$	4,496		$	3,305		$	6,203		$	5,034
	Derivatives - noncurrent		—			386			1,000			—
NJRES:
Physical forward commodity contracts	Derivatives - current		8,296			10,119			19,590			9,530
	Derivatives - noncurrent		320			16			658			216
Financial derivative contracts	Derivatives - current		52,635			22,770			22,112			27,779
	Derivatives - noncurrent		1,400			3,691			600			2,902
Fair value of derivatives not designated as hedging instruments			$	67,147		$	40,287		$	50,163		$	45,461
Total fair value of derivatives			$	67,198		$	40,327		$	50,349		$	45,573

At June 30, 2013, the gross notional amount of the foreign currency transactions was approximately $3.8 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						Nine Months Ended
		June 30,						June 30,
Derivatives not designated as hedging instruments:		2013			2012			2013			2012
NJRES:
Physical commodity contracts	Operating revenues	$	3,595		$	(2,860	)	$	(4,264	)	$	(6,023	)
Physical commodity contracts	Gas purchases	(8,809		)	8,155			(6,253		)	12,546
Financial derivative contracts	Gas purchases	39,601			(9,717		)	38,134			93,248
Total unrealized and realized gains (losses)		$	34,387		$	(4,422	)	$	27,617		$	99,771

Not included in the previous table, are (losses) gains associated with NJNG's financial derivatives that totaled $(4.7) million and $3.7 million for the three months endedJune 30, 2013 and 2012, respectively, and gains (losses) that totaled $1.4 million and $(31.6) million for the nine months endedJune 30, 2013 and 2012, respectively. These derivatives are part of NJNG's risk management activities that relate to its natural gas purchases and BGSS incentive programs. As these transactions are entered into pursuant to and recoverable through regulatory riders, any changes in the value of NJNG's financial derivatives are deferred in regulatory assets or liabilities 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 on the Unaudited Condensed Consolidated Statements of Operations. The following tables reflect the effect of derivative instruments designated as cash flow hedges on OCI as of:

(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
	June 30,					June 30,						June 30,
Derivatives in cash flow hedging relationships:	2013			2012		2013			2012			2013		2012
Foreign currency contracts	$	(14	)	$	12	$	(21	)	$	(35	)	$	—	$	—

(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion) (1)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)					Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Nine Months Ended						Nine Months Ended					Nine Months Ended
	June 30,						June 30,					June 30,
Derivatives in cash flow hedging relationships:	2013			2012			2013		2012			2013		2012
Foreign currency contracts	$	(85	)	$	(63	)	$	23	$	(70	)	$	—	$	—

(1) The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $33,000 from OCI into earnings. The maximum tenor is April 2015.

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

			Volume (Bcf)
			June 30, 2013		September 30, 2012
NJNG	Futures		17.0		16.1
	Swaps	(1)	—		3.4
	Options		0.7		—
NJRES	Futures		(50.2	)	(28.6	)
	Swaps	(1)	—		13.2
	Options		—		4.4
	Physical		22.1		(3.5	)

(1) In October 2012, following the implementation of the Dodd-Frank Wall Street Reform and Consumer Protection Act, the Intercontinental Exchange (ICE) converted its cleared energy “swap” contracts to “futures” contracts and the New York Mercantile Exchange (NYMEX) amended their product titles to remove the word “swap” from the titles of their “futures” and “option” contracts.

Broker Margin

Generally, exchange-traded futures contracts require posted collateral, referred to as margin, usually in the form of cash. The amount of margin required is comprised of a fixed initial amount based on the contract and a variable amount based on market price movements from the initial trade price. The Company maintains separate broker margin accounts for NJNG and NJRES. The balances by company, are as follows:

(Thousands)	Balance Sheet Location	June 30, 2013		September 30, 2012
NJNG	Broker margin - Current assets	$	1,350	$	1,713
NJRES	Broker margin - Current assets	$	—	$	20,216
NJRES	Broker margin - Current liabilities	$	6,181	$	—

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 and the North American Energy Standards Board. 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 June 30, 2013. 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		$	199,972
Noninvestment grade		5,679
Internally rated investment grade		34,692
Internally rated noninvestment grade		4,461
Total		$	244,804

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 June 30, 2013 and September 30, 2012, was $1.2 million and $1.6 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 June 30, 2013 and September 30, 2012, the Company would have been required to post an additional $87,000 and $1.2 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted.

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FAIR VALUE (Tables)

9 Months Ended

Jun. 30, 2013

Fair Value Disclosures [Abstract]

Fair Value, by Balance Sheet Grouping

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

(Thousands)	June 30, 2013		September 30, 2012
Carrying value	$	529,845	$	479,845
Fair market value	$	558,336	$	530,056

Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis

Assets and liabilities measured at fair value on a recurring basis are summarized as follows:

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of June 30, 2013:
Assets:
Physical forward commodity contracts		$	—		$	8,616		$	—	$	8,616
Financial derivative contracts - natural gas		58,531			—			—		58,531
Financial derivative contracts - foreign exchange		—			51			—		51
Available for sale equity securities - energy industry (1)		11,482			—			—		11,482
Other (2)		1,096			—			—		1,096
Total assets at fair value		$	71,109		$	8,667		$	—	$	79,776
Liabilities:
Physical forward commodity contracts		$	—		$	10,135		$	—	$	10,135
Financial derivative contracts - natural gas		30,115			37			—		30,152
Financial derivative contracts - foreign exchange		—			40			—		40
Total liabilities at fair value		$	30,115		$	10,212		$	—	$	40,327
As of September 30, 2012:
Assets:
Physical forward commodity contracts		$	—		$	20,248		$	—	$	20,248
Financial derivative contracts - natural gas		14,270			15,645			—		29,915
Financial derivative contracts - foreign exchange		—			186			—		186
Available for sale equity securities - energy industry(1)		11,009			—			—		11,009
Other (2)		30			—			—		30
Total assets at fair value		$	25,309		$	36,079		$	—	$	61,388
Liabilities:
Physical forward commodity contracts		$	—		$	9,746		$	—	$	9,746
Financial derivative contracts - natural gas		16,922			18,793			—		35,715
Financial derivative contracts - foreign exchange		—			112			—		112
Total liabilities at fair value		$	16,922		$	28,651		$	—	$	45,573

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

(2) Includes various money market funds.

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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				9 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
Segment Reporting Information [Line Items]
Utility	$ 119,022		$ 106,764		$ 689,621		$ 524,161
Nonutility	648,447		318,357		1,774,752		1,156,292
Total operating revenues	767,469		425,121		2,464,373		1,680,453
Depreciation and amortization	11,942		10,687		34,966		30,726
Interest income	193	[1]	253	[1]	592	[1]	770	[1]
Interest expense, net of capitalized interest	6,008		4,834		17,579		15,266
Income tax provision (benefit)	15,297		(11,230)		51,342		15,901
Equity in earnings of affiliates	2,222		2,644		8,307		8,316
Net financial earnings (loss)	9,738		4,130		113,895		123,564
Capital expenditures	44,266		46,971		135,128		158,361
Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	9,537		8,860		28,213		26,241
Interest income	146	[1]	223	[1]	459	[1]	683	[1]
Interest expense, net of capitalized interest	3,796		3,717		10,929		11,167
Income tax provision (benefit)	1,788		1,114		39,089		43,726
Net financial earnings (loss)	5,528		7,545		76,937		78,455
Capital expenditures	29,141		33,405		94,840		82,550
Natural Gas Distribution [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Utility	119,022		106,764		689,621		524,161
Clean Energy Ventures [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	2,196		1,632		6,131		3,953
Interest expense, net of capitalized interest	870		190		2,475		530
Income tax provision (benefit)	(1,477)		(3,013)		(15,703)		(30,010)
Net financial earnings (loss)	(1,381)		(1,157)		9,078		20,802
Capital expenditures	14,891		13,457		39,756		75,243
Clean Energy Ventures [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility	2,563		370		7,182		1,277
Energy Services [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	10		16		32		48
Interest income	0	[1]	10	[1]	0	[1]	36	[1]
Interest expense, net of capitalized interest	615		214		1,823		729
Income tax provision (benefit)	12,945		(11,511)		23,906		(2,108)
Net financial earnings (loss)	2,097		(5,425)		21,479		18,061
Energy Services [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility	632,414		306,273		1,735,411		1,126,435
Energy Services [Member] | Intercompany/Eliminations [Member]
Segment Reporting Information [Line Items]
Nonutility	1,119		(32)		5,670		2,816
Midstream Investments [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	2		1		5		4
Interest income	265	[1]	267	[1]	799	[1]	800	[1]
Interest expense, net of capitalized interest	466		653		1,533		2,050
Income tax provision (benefit)	1,073		1,126		3,935		3,750
Equity in earnings of affiliates	3,052		3,547		11,012		11,129
Net financial earnings (loss)	1,541		1,634		5,600		5,438
Reportable Segment [Member]
Segment Reporting Information [Line Items]
Total operating revenues	755,118		413,375		2,437,884		1,654,689
Depreciation and amortization	11,745		10,509		34,381		30,246
Interest income	411	[1]	500	[1]	1,258	[1]	1,519	[1]
Interest expense, net of capitalized interest	5,747		4,774		16,760		14,476
Income tax provision (benefit)	14,329		(12,284)		51,227		15,358
Net financial earnings (loss)	7,785		2,597		113,094		122,756
Capital expenditures	44,032		46,862		134,596		157,793
Retail and Other [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	196		178		586		480
Interest income	(1)	[1]	1	[1]	1	[1]	2	[1]
Interest expense, net of capitalized interest	261		60		819		790
Income tax provision (benefit)	1,378		1,056		349		685
Net financial earnings (loss)	1,944		1,549		813		860
Capital expenditures	234		109		532		568
Retail and Other [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility	13,470		11,714		32,159		28,580
Retail and Other [Member] | Intercompany/Eliminations [Member]
Segment Reporting Information [Line Items]
Nonutility	234		278		683		720
Intercompany/Eliminations [Member]
Segment Reporting Information [Line Items]
Nonutility	(1,353)		(246)		(6,353)		(3,536)
Depreciation and amortization	1		0		(1)		0
Interest income	(217)	[1]	(248)	[1]	(667)	[1]	(751)	[1]
Income tax provision (benefit)	(410)		(2)		(234)		(142)
Equity in earnings of affiliates	(830)		(903)		(2,705)		(2,813)
Net financial earnings (loss)	$ 9		$ (16)		$ (12)		$ (52)

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

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA

9 Months Ended

Jun. 30, 2013

Segment Reporting [Abstract]

BUSINESS SEGMENT AND OTHER OPERATIONS DATA

BUSINESS SEGMENT AND OTHER OPERATIONS DATA

NJR organizes its businesses based on its products and services as well as regulatory environment. As a result, the Company manages the businesses through the following reportable segments and other operations: the Natural Gas Distribution segment consists of regulated energy and off-system, capacity and storage management operations; the Energy Services segment consists of unregulated wholesale energy operations; the Clean Energy Ventures segment consist of capital investments in renewable energy projects; the Midstream Investments segment consists of NJR's investments in natural gas transportation and storage facilities; the Retail and Other operations consist of heating, cooling and water appliance installation and services, commercial real estate development, other investments and general corporate activities.

Information related to the Company's various business segments and other operations is detailed below:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Operating revenues
Natural Gas Distribution
External customers	$	119,022		$	106,764		$	689,621		$	524,161
Clean Energy Ventures
External customers	2,563			370			7,182			1,277
Energy Services
External customers	632,414			306,273			1,735,411			1,126,435
Intercompany	1,119			(32		)	5,670			2,816
Segment subtotal	755,118			413,375			2,437,884			1,654,689
Retail and Other
External customers	13,470			11,714			32,159			28,580
Intercompany	234			278			683			720
Eliminations	(1,353		)	(246		)	(6,353		)	(3,536		)
Total	$	767,469		$	425,121		$	2,464,373		$	1,680,453
Depreciation and amortization
Natural Gas Distribution	$	9,537		$	8,860		$	28,213		$	26,241
Clean Energy Ventures	2,196			1,632			6,131			3,953
Energy Services	10			16			32			48
Midstream Investments	2			1			5			4
Segment subtotal	11,745			10,509			34,381			30,246
Retail and Other	196			178			586			480
Eliminations	1			—			(1		)	—
Total	$	11,942		$	10,687		$	34,966		$	30,726
Interest income (1)
Natural Gas Distribution	$	146		$	223		$	459		$	683
Energy Services	—			10			—			36
Midstream Investments	265			267			799			800
Segment subtotal	411			500			1,258			1,519
Retail and Other	(1		)	1			1			2
Eliminations	(217		)	(248		)	(667		)	(751		)
Total	$	193		$	253		$	592		$	770

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

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Interest expense, net of capitalized interest
Natural Gas Distribution	$	3,796		$	3,717		$	10,929		$	11,167
Clean Energy Ventures	870			190			2,475			530
Energy Services	615			214			1,823			729
Midstream Investments	466			653			1,533			2,050
Segment subtotal	5,747			4,774			16,760			14,476
Retail and Other	261			60			819			790
Total	$	6,008		$	4,834		$	17,579		$	15,266
Income tax provision (benefit)
Natural Gas Distribution	$	1,788		$	1,114		$	39,089		$	43,726
Clean Energy Ventures	(1,477		)	(3,013		)	(15,703		)	(30,010		)
Energy Services	12,945			(11,511		)	23,906			(2,108		)
Midstream Investments	1,073			1,126			3,935			3,750
Segment subtotal	14,329			(12,284		)	51,227			15,358
Retail and Other	1,378			1,056			349			685
Eliminations	(410		)	(2		)	(234		)	(142		)
Total	$	15,297		$	(11,230	)	$	51,342		$	15,901
Equity in earnings of affiliates
Midstream Investments	$	3,052		$	3,547		$	11,012		$	11,129
Eliminations	(830		)	(903		)	(2,705		)	(2,813		)
Total	$	2,222		$	2,644		$	8,307		$	8,316
Net financial earnings (loss)
Natural Gas Distribution	$	5,528		$	7,545		$	76,937		$	78,455
Clean Energy Ventures	(1,381		)	(1,157		)	9,078			20,802
Energy Services	2,097			(5,425		)	21,479			18,061
Midstream Investments	1,541			1,634			5,600			5,438
Segment subtotal	7,785			2,597			113,094			122,756
Retail and Other	1,944			1,549			813			860
Eliminations	9			(16		)	(12		)	(52		)
Total	$	9,738		$	4,130		$	113,895		$	123,564
Capital expenditures
Natural Gas Distribution	$	29,141		$	33,405		$	94,840		$	82,550
Clean Energy Ventures	14,891			13,457			39,756			75,243
Segment subtotal	44,032			46,862			134,596			157,793
Retail and Other	234			109			532			568
Total	$	44,266		$	46,971		$	135,128		$	158,361

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						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Consolidated net financial earnings	$	9,738		$	4,130		$	113,895		$	123,564
Less:
Unrealized (gain) loss from derivative instruments and related transactions, net of taxes (1) (2)	(27,915		)	20,834			(14,975		)	11,126
Effects of economic hedging related to natural gas inventory, net of taxes (3)	8,498			(6,384		)	(5,960		)	10,866
Consolidated net income (loss)	$	29,155		$	(10,320	)	$	134,830		$	101,572

(1) Excludes unrealized losses (gains) related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $708,000 and $(20,000) for the three months endedand $398,000 and $177,000 for the nine months endedJune 30, 2013 and 2012, respectively.

(2) Amounts are net of taxes of approximately $(17.1) million and $12.1 million, for the three months ended and $(9.2) million and $6.3 million for the nine months endedJune 30, 2013 and 2012, respectively.

(3) Amounts are net of taxes of approximately $4.9 million and $(3.7) million for the three months ended and $(3.5) million and $6.3 million for the nine months endedJune 30, 2013 and 2012, 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)	June 30, 2013			September 30, 2012
Assets at end of period:
Natural Gas Distribution	$	2,062,913		$	2,005,520
Clean Energy Ventures	253,680			223,247
Energy Services	497,941			347,406
Midstream Investments	156,135			157,779
Segment subtotal	2,970,669			2,733,952
Retail and Other	86,920			73,298
Eliminations (1)	(66,394		)	(37,245		)
Total	$	2,991,195		$	2,770,005

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

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EARNINGS PER SHARE (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended				9 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
Earnings Per Share [Abstract]
Net income (loss)	$ 29,155		$ (10,320)		$ 134,830		$ 101,572
Basic earnings per share
Weighted average shares of common stock outstanding-basic (in shares)	41,608		41,560		41,697		41,501
Basic earnings (loss) per common share	$ 0.70		$ (0.25)		$ 3.23		$ 2.45
Diluted earnings per share
Incremental shares	124	[1]	0	[1]	123	[1]	142	[1]
Weighted average shares of common stock outstanding-diluted (in shares)	41,732		41,560		41,820		41,643
Diluted earnings (loss) per common share	$ 0.70	[2]	$ (0.25)	[2]	$ 3.22	[2]	$ 2.44	[2]
Anti-dilutive shares excluded from the calculation of diluted earnings per share (in shares)	0		140		0		0

[1] Incremental shares consist of stock options, stock awards and performance units.

[2] Since there was a net loss for the three months ended June 30, 2012, incremental shares of 140 were not included in the computation of diluted loss per common share, as their effect would have been anti-dilutive. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and nine months ended June 30, 2013 and the nine months ended June 30, 2012.

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS LOSS RECONCILIATION (Details) (USD $)	3 Months Ended				9 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
Net financial earnings (loss)	$ 9,738,000		$ 4,130,000		$ 113,895,000		$ 123,564,000
Unrealized (gain) loss from derivative instruments and related transactions, net of taxes	(27,915,000)	[1],[2]	20,834,000	[1],[2]	(14,975,000)	[1],[2]	11,126,000	[1],[2]
Effects of economic hedging related to natural gas inventory, net of taxes	8,498,000	[3]	(6,384,000)	[3]	(5,960,000)	[3]	10,866,000	[3]
Net income (loss)	29,155,000		(10,320,000)		134,830,000		101,572,000
Taxes related to unrealized loss (gain) from derivative instruments and related transactions	(17,100,000)		12,100,000		(9,200,000)		6,300,000
Taxes related to effects of economic hedging related to natural gas inventory	4,900,000		(3,700,000)		(3,500,000)		6,300,000
Transactions Between NJNG and NJRES [Member]
Unrealized (gain) loss from derivative instruments and related transactions, net of taxes	$ 708,000		$ (20,000)		$ 398,000		$ 177,000

[1] Amounts are net of taxes of approximately $(17.1) million and $12.1 million, for the three months ended and $(9.2) million and $6.3 million for the nine months ended June 30, 2013 and 2012, respectively.

[2] Excludes unrealized losses (gains) related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $708,000 and $(20,000) for the three months ended and $398,000 and $177,000 for the nine months ended June 30, 2013 and 2012, respectively.

[3] Amounts are net of taxes of approximately $4.9 million and $(3.7) million for the three months ended and $(3.5) million and $6.3 million for the nine months ended June 30, 2013 and 2012, respectively.

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REGULATION - REGULATORY FILINGS (Details) (USD $)			9 Months Ended					6 Months Ended	9 Months Ended
	Jun. 30, 2013	Sep. 30, 2012	Jun. 30, 2013 BGSS [Member]	Jun. 30, 2013 CIP [Member]	Jun. 30, 2013 SAFE-Safety Acceleration and Facility Enhancement Program [Member]	Jun. 30, 2013 AIP I and AIP II [Member]	Jun. 30, 2013 EE-Rebates and Incentives [Member]	Jun. 30, 2013 SBC [Member]	Jun. 30, 2013 SBC [Member]	Jun. 30, 2013 Deferred Superstorm Sandy Costs [Member]	Sep. 30, 2012 Deferred Superstorm Sandy Costs [Member]
Schedule of Regulatory [Line Items]
Capital investments approved by the board of public utilities					$ 130,000,000		$ 85,000,000
Weighted average cost of capital							6.90%
Annual recovery amount increase (decrease) proposed to the board of public utilities						6,900,000
Annual recovery amount increase approved by the Board of Public Utilities						6,500,000
Rate increase approved by the Board of Public Utilities			(5.20%)	(1.00%)			1.70%
Increase (decrease) in regulatory assets and liabilities								9,800,000	15,600,000
Regulatory assets	$ 460,232,000	$ 441,263,000								$ 14,916,000	$ 0

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DEBT (Tables)

9 Months Ended

Jun. 30, 2013

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

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

(Thousands)	June 30, 2013			September 30, 2012			Maturity Dates
NJNG
Bank credit facility dedicated to EDA Bonds (1) (2) (3)	$	100,000		$	100,000		August 2015
Bank revolving credit facility (1)	$	250,000		$	200,000		August 2014
Amount outstanding at end of period	$	96,000		$	135,000
Weighted average interest rate at end of period	0.15		%	0.18		%
Amount available at end of period	$	154,000		$	65,000
NJR
Bank revolving credit facility(1)	$	325,000		$	325,000		August 2017
Amount outstanding at end of period	$	200,900		$	144,800
Weighted average interest rate at end of period	1.12		%	1.16		%
Amount available at end of period (4)	$	107,710		$	166,339

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

(2) There were no borrowings outstanding as of June 30, 2013 and September 30, 2012, respectively.

(3) New Jersey Economic Development Authority (EDA) Bonds.

(4) Letters of credit outstanding total $16.4 million and $13.9 million as of June 30, 2013 and September 30, 2012, respectively, which reduces amount available.

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EARNINGS PER SHARE (Tables)

9 Months Ended

Jun. 30, 2013

Earnings Per Share [Abstract]

Schedule of Earnings Per Share Basic and Diluted Table

The following table presents the calculation of the Company's basic and diluted earnings per share for:

	Three Months Ended					Nine Months Ended
	June 30,					June 30,
(Thousands, except per share amounts)	2013		2012			2013		2012
Net income (loss), as reported	$	29,155	$	(10,320	)	$	134,830	$	101,572
Basic earnings per share
Weighted average shares of common stock outstanding-basic	41,608		41,560			41,697		41,501
Basic earnings (loss) per common share	$0.70		$(0.25)			$3.23		$2.45
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	41,608		41,560			41,697		41,501
Incremental shares (1)	124		—			123		142
Weighted average shares of common stock outstanding-diluted	41,732		41,560			41,820		41,643
Diluted earnings (loss) per common share (2)	$0.70		$(0.25)			$3.22		$2.44

(1) Incremental shares consist of stock options, stock awards and performance units.

(2) Since there was a net loss for the three months ended June 30, 2012, incremental shares of 140 were not included in the computation of diluted loss per common share, as their effect would have been anti-dilutive. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and nine months endedJune 30, 2013 and the nine months endedJune 30, 2012.

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INVESTMENTS IN EQUITY INVESTEES - SCHEDULE OF EQUITY METHOD INVESTMENTS (Details) (USD $)	Jun. 30, 2013	Sep. 30, 2012
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 154,630,000	$ 155,795,000
Steckman Ridge [Member]
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	130,715,000	132,931,000
Steckman Ridge [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Outstanding principal balance	70,400,000
Iroquois [Member]
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 23,915,000	$ 22,864,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ASSET HELD FOR SALE (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013 acre	Sep. 30, 2012
Property, Plant and Equipment [Abstract]
Number of acres of undeveloped land	25.3
Asset held for sale	$ 5,421	$ 0

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DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) (USD $)	3 Months Ended				9 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Expected reclassification from OCI into earnings	$ 33,000				$ 33,000
Maximum tenor					April 2015
Foreign Exchange Contract [Member] | Gas Purchases [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Foreign currency contracts, Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)	(14,000)	[1]	12,000	[1]	(85,000)	[1]	(63,000)	[1]
Foreign currency contracts, Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)	(21,000)		(35,000)		23,000		(70,000)
Foreign currency contracts, Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0		0		0		0
NJRES [Member] | Nondesignated [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments, gain (loss) recognized in income, net	34,387,000		(4,422,000)		27,617,000		99,771,000
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	3,595,000		(2,860,000)		(4,264,000)		(6,023,000)
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	(8,809,000)		8,155,000		(6,253,000)		12,546,000
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	39,601,000		(9,717,000)		38,134,000		93,248,000
NJNG [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments, gain (loss) recognized in regulatory assets and liabilities net	$ (4,700,000)		$ 3,700,000		$ 1,400,000		$ (31,600,000)

[1] The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $33,000 from OCI into earnings. The maximum tenor is April 2015

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DEBT - CREDIT FACILITIES (Details) (USD $)																				24 Months Ended		24 Months Ended
	Jun. 30, 2013 Commercial Paper [Member] NJNG [Member]	Sep. 30, 2012 Commercial Paper [Member] NJNG [Member]	Jun. 30, 2013 Notes Payable to Banks [Member] NJR [Member]	Sep. 30, 2012 Notes Payable to Banks [Member] NJR [Member]	Jun. 30, 2013 Letter of Credit [Member] NJR [Member]	Sep. 30, 2012 Letter of Credit [Member] NJR [Member]	Jun. 30, 2013 Letter of Credit [Member] NJR [Member]	Jun. 30, 2013 Bank Credit Facility Dedicated to EDA Bonds [Member] NJNG [Member]		Sep. 30, 2012 Bank Credit Facility Dedicated to EDA Bonds [Member] NJNG [Member]		Jun. 30, 2013 Bank Revolving Credit Facility [Member] NJNG [Member]		Sep. 30, 2012 Bank Revolving Credit Facility [Member] NJNG [Member]		Jun. 30, 2013 Bank Revolving Credit Facility [Member] NJR [Member]		Sep. 30, 2012 Bank Revolving Credit Facility [Member] NJR [Member]		May 10, 2013 Debt Shelf Facility Metlife [Member] NJR [Member]	Jun. 30, 2013 Debt Shelf Facility Metlife [Member] Unsecured senior note 1.94% [Member] NJR [Member]	Jun. 30, 2013 Debt Shelf Facility Prudential [Member] NJR [Member]
Line of Credit Facility [Line Items]
Bank credit facilities							$ 10,000,000	$ 100,000,000	[1],[2],[3]	$ 100,000,000	[1],[2],[3]	$ 250,000,000	[3]	$ 200,000,000	[3]	$ 325,000,000	[3]	$ 325,000,000	[3]			$ 75,000,000
Issuance period																				2 years		3 years
Amount outstanding at end of period	96,000,000	135,000,000	200,900,000	144,800,000																	25,000,000
Weighted average interest rate at end of period	0.15%	0.18%	1.12%	1.16%
Amount available at end of period												154,000,000		65,000,000		107,710,000	[4]	166,339,000	[4]			25,000,000
Letters of credit outstanding, amount					$ 16,400,000	$ 13,900,000

[1] There were no borrowings outstanding as of June 30, 2013 and September 30, 2012, respectively.

[2] New Jersey Economic Development Authority (EDA) Bonds.

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

[4] Letters of credit outstanding total $16.4 million and $13.9 million as of June 30, 2013 and September 30, 2012, respectively, which reduces amount available.

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NATURE OF THE BUSINESS (Details)	9 Months Ended
	Jun. 30, 2013 Customers
Iroquois [Member]
Equity method investment, ownership percentage	5.53%
Steckman Ridge [Member]
Equity method investment, ownership percentage	50.00%
NJNG [Member]
Total retail customers	497,400

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DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) (USD $)	9 Months Ended
	Jun. 30, 2013	Sep. 30, 2012
Credit Risk Exposure [Line Items]
Gross credit exposure	$ 244,804,000
Derivative, net liability position, aggregate fair value	1,200,000	1,600,000
Additional collateral, aggregate fair value	87,000	1,200,000
Investment Grade [Member]
Credit Risk Exposure [Line Items]
Gross credit exposure	199,972,000
Noninvestment Grade [Member]
Credit Risk Exposure [Line Items]
Gross credit exposure	5,679,000
Internally Rated Investment Grade [Member]
Credit Risk Exposure [Line Items]
Gross credit exposure	34,692,000
Internally Rated Noninvestment Grade [Member]
Credit Risk Exposure [Line Items]
Gross credit exposure	$ 4,461,000

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INVESTMENTS IN EQUITY INVESTEES (Tables)

9 Months Ended

Jun. 30, 2013

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Equity Method Investments

Equity Method Investments

(Thousands)	June 30, 2013		September 30, 2012
Steckman Ridge	$	130,715	$	132,931
Iroquois	23,915		22,864
Total	$	154,630	$	155,795

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Sep. 30, 2012
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 1,637,084	$ 1,591,532
Construction work in progress	120,881	102,420
Solar equipment, real estate properties and other, at cost	230,580	192,026
Construction work in progress	5,508	20,558
Total property, plant and equipment	1,994,053	1,906,536
Accumulated depreciation and amortization	(408,746)	(421,659)
Property, plant and equipment, net	1,585,307	1,484,877
CURRENT ASSETS
Cash and cash equivalents	1,860	4,509
Customer accounts receivable
Billed	290,364	170,543
Unbilled revenues	6,956	7,017
Allowance for doubtful accounts	(5,667)	(4,797)
Regulatory assets	21,013	32,734
Gas in storage, at average cost	280,118	265,193
Materials and supplies, at average cost	17,730	7,863
Prepaid and accrued taxes	25,863	32,029
Asset held for sale	5,421	0
Derivatives, at fair value	65,478	48,021
Restricted broker margin accounts	1,350	21,929
Deferred taxes	22,033	29,074
Other	17,752	33,229
Total current assets	750,271	647,344
NONCURRENT ASSETS
Investments in equity investees	163,430	164,595
Regulatory assets	460,232	441,263
Derivatives, at fair value	1,720	2,328
Other	30,235	29,598
Total noncurrent assets	655,617	637,784
Total assets	2,991,195	2,770,005
CAPITALIZATION
Common stock equity	892,356	813,865
Long-term debt	516,173	525,169
Total capitalization	1,408,529	1,339,034
CURRENT LIABILITIES
Current maturities of long-term debt	68,492	7,760
Short-term debt	296,900	279,800
Gas purchases payable	269,346	182,414
Accounts payable and other	50,395	66,765
Dividends payable	16,579	16,648
Deferred and accrued taxes	15,705	2,072
Regulatory liabilities	1,191	1,169
New Jersey clean energy program	16,953	5,619
Derivatives, at fair value	36,211	42,440
Restricted broker margin accounts	6,181	0
Customers' credit balances and deposits	17,553	48,452
Total current liabilities	795,506	653,139
NONCURRENT LIABILITIES
Deferred income taxes	370,128	355,306
Deferred investment tax credits	5,664	5,905
Deferred revenue	4,943	5,502
Derivatives, at fair value	4,116	3,133
Manufactured gas plant remediation	182,000	182,000
Postemployment employee benefit liability	105,135	124,196
Regulatory liabilities	78,429	67,077
Asset retirement obligation	28,457	27,983
Other	8,288	6,730
Total noncurrent liabilities	787,160	777,832
Commitments and contingent liabilities (Note 11)
Total capitalization and liabilities	$ 2,991,195	$ 2,770,005

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Jun. 30, 2013

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by NJR in accordance with the rules and regulations of the Securities and Exchange Commission and Accounting Standards Codification (ASC) 270. The September 30, 2012, Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in NJR's 2012 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, 2013.

Intercompany transactions and accounts have been eliminated.

Gas in Storage

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

	June 30, 2013				September 30, 2012
($ in thousands)	Gas in Storage			Bcf (1)	Gas in Storage			Bcf (1)
NJNG		$	63,900	12.3		$	145,379	22.2
NJRES		216,218		56.3		119,814		45.5
Total		$	280,118	68.6		$	265,193	67.7

(1) Billion cubic feet (Bcf).

Available for Sale Securities

Included in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets are certain investments in equity securities of a publicly traded energy company that have a fair value of $11.5 million and $11 million as of June 30, 2013 and September 30, 2012, respectively. Total unrealized gains associated with these equity securities, which are included as a part of accumulated other comprehensive income, a component of common stock equity, were $8.9 million ($5.3 million, after tax) and $8.3 million ($4.9 million, after tax) as of June 30, 2013 and September 30, 2012, respectively. During the third quarter of fiscal 2013, NJR received proceeds of approximately $482,000 from the sale of available-for-sale securities and realized a pre-tax gain of $380,000, which is included in other income in the Unaudited Condensed Consolidated Statements of Operations. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

Asset Held for Sale

NJR's subsidiary, CR&R, has committed to a plan to sell approximately 25.3 acres of undeveloped land located in Monmouth County with a net book value of $5.4 million. Since it is probable that the sale will be completed within the next 12 months, as of June 30, 2013, the Company has classified the property as held for sale in the Unaudited Condensed Consolidated Balance Sheets.

Disposal of Equipment

In October 2012, certain of NJRCEV's solar assets sustained damage as a result of Post Tropical Cyclone Sandy, commonly referred to as Superstorm Sandy (Superstorm Sandy). To the extent that any of the assets were deemed irreparable, the Company disposed of the damaged assets. As a result, the Company recognized a pre-tax loss of $766,000, which is included in other income on the Unaudited Condensed Consolidated Statements of Operations. During the third quarter of fiscal 2013, the Company received $954,000 from an insurance claim, representing the replacement value of the disposed assets and recorded a gain in the same amount in other income on the Unaudited Condensed Consolidated Statements of Operations.

Recent Updates to the Accounting Standards Codification

In December 2011, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2011-11, 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 generally accepted accounting principles (GAAP) in the United States of America and those prepared on the basis of International Financial Reporting Standards. The amended guidance will become effective for annual periods beginning on or after January 1, 2013, as well as interim periods within those annual periods, 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.

In February 2013, the FASB issued ASU No. 2013-02, an amendment to ASC Topic 220, Comprehensive Income, requiring information about amounts reclassified out of accumulated other comprehensive income as well as income statement line items that are affected by the reclassifications. The new guidance does not change existing requirements for reporting net income or other comprehensive income in the financial statements. ASU 2013-02 became effective for reporting periods beginning after December 15, 2012. There was no impact to the Company's financial position, results of operations or cash flows upon adoption.

NJR applied the provisions of the new guidance prospectively effective January 1, 2013. The information for the six month period ending June 30, 3013 is as follows:

Accumulated Other Comprehensive Income

(Thousands)	Unrealized gain on available for sale securities				Net unrealized gain on derivatives				Adjustment to postemployment benefit obligation				Total
Beginning balance as of January 1, 2013	$	4,601			$	41			$	(15,330	)		$	(10,688	)
Other comprehensive income, excluding reclassifications, net of tax of $(611), $(4), $-, $(615)	885				6				—				891
Amounts reclassified from accumulated other comprehensive income, net of tax of $155, $21 $(405), $(229)	(225		)	(1)	(40		)	(2)	592			(3)	327
Net current-period other comprehensive income, net of tax of $(456), $17, $(405), $(844)	660				(34		)		592				1,218
Ending balance as of June 30, 2013	$	5,261			$	7			$	(14,738	)		$	(9,470	)

(1) Reclassified to other income in the Unaudited Consolidated Statements of Operations.

(2) Reclassified to gas purchases in the Unaudited Consolidated Statements of Operations.

(3) Included in the computation of net periodic pension cost, a component of operations and maintenance expense in the Unaudited Consolidated Statements of Operations.

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FAIR VALUE

9 Months Ended

Jun. 30, 2013

Fair Value Disclosures [Abstract]

FAIR VALUE

FAIR VALUE

Fair Value of Assets and Liabilities

The fair value of cash and temporary investments, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. The estimated fair value of long-term debt, including current maturities and excluding capital leases, is as follows:

(Thousands)	June 30, 2013		September 30, 2012
Carrying value	$	529,845	$	479,845
Fair market value	$	558,336	$	530,056

NJR utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific issue and the Company's credit rating. As of June 30, 2013, NJR discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following:

Level 1 Unadjusted quoted prices for identical assets or liabilities in active markets; NJR's Level 1 assets and liabilities include exchange traded futures and options contracts, listed equities, and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX/Chicago Mercantile Exchange (CME) and ICE that NJR refers internally to as basis swaps, fixed swaps, futures and options that are cleared through a Futures Commission Merchant (FCM).

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. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input was considered to be a “model”, it would still be considered to be a Level 2 input as:

1)     The data is widely accepted and public

2)    The data is non-proprietary and sourced from an independent third party

3)    The data is observable and published

These additional adjustments are generally not considered to be significant to the ultimate recognized values.

Level 3 Inputs derived from a significant amount of unobservable market data; these include NJR's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

Assets and liabilities measured at fair value on a recurring basis are summarized as follows:

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of June 30, 2013:
Assets:
Physical forward commodity contracts		$	—		$	8,616		$	—	$	8,616
Financial derivative contracts - natural gas		58,531			—			—		58,531
Financial derivative contracts - foreign exchange		—			51			—		51
Available for sale equity securities - energy industry (1)		11,482			—			—		11,482
Other (2)		1,096			—			—		1,096
Total assets at fair value		$	71,109		$	8,667		$	—	$	79,776
Liabilities:
Physical forward commodity contracts		$	—		$	10,135		$	—	$	10,135
Financial derivative contracts - natural gas		30,115			37			—		30,152
Financial derivative contracts - foreign exchange		—			40			—		40
Total liabilities at fair value		$	30,115		$	10,212		$	—	$	40,327
As of September 30, 2012:
Assets:
Physical forward commodity contracts		$	—		$	20,248		$	—	$	20,248
Financial derivative contracts - natural gas		14,270			15,645			—		29,915
Financial derivative contracts - foreign exchange		—			186			—		186
Available for sale equity securities - energy industry(1)		11,009			—			—		11,009
Other (2)		30			—			—		30
Total assets at fair value		$	25,309		$	36,079		$	—	$	61,388
Liabilities:
Physical forward commodity contracts		$	—		$	9,746		$	—	$	9,746
Financial derivative contracts - natural gas		16,922			18,793			—		35,715
Financial derivative contracts - foreign exchange		—			112			—		112
Total liabilities at fair value		$	16,922		$	28,651		$	—	$	45,573

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

(2) Includes various money market funds.

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REGULATION

9 Months Ended

Jun. 30, 2013

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)	June 30, 2013		September 30, 2012
Regulatory assets-current
Conservation Incentive Program	$	18,954	$	25,681
Underrecovered gas costs	2,059		7,053
Total current	$	21,013	$	32,734
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	47,405	$	59,745
Liability for future expenditures	182,000		182,000
Deferred income taxes	11,405		11,405
Derivatives at fair value, net	386		—
Energy Efficiency Program	38,759		26,025
New Jersey Clean Energy Program (NJCEP)	16,953		5,619
Postemployment and other benefit costs	135,303		142,495
Deferred Superstorm Sandy costs	14,916		—
Other	13,105		13,974
Total noncurrent	$	460,232	$	441,263
Regulatory liability-current
Derivatives at fair value, net	$	1,191	$	1,169
Total current	$	1,191	$	1,169
Regulatory liabilities-noncurrent
Cost of removal obligation	$	77,581	$	65,994
Derivatives at fair value, net	—		1,000
Other	848		83
Total noncurrent	$	78,429	$	67,077

NJNG's recovery of costs is facilitated through its base tariff rates, Basic Gas Supply Service (BGSS) and other regulatory tariff riders. As recovery of regulatory assets is subject to BPU approval, if there are any changes in regulatory positions that indicate recovery is not probable, the related cost would be charged to income in the period of such determination.

Recent regulatory filings and/or actions include the following:

BGSS and Conservation Incentive Program (CIP)

• In March 2013, NJNG and South Jersey Gas Company filed a joint petition with the BPU requesting the continuation of the CIP with certain modifications. The discovery phase has commenced and, if no Board Order on that petition is issued as of September 30, 2013, the CIP program will continue for up to one additional year or until such an Order is issued, whichever is earlier. The CIP permits NJNG to recover utility gross margin variations related to customer usage resulting from customer conservation efforts and allows NJNG to mitigate the impact of weather on its gross margin. Such utility gross margin variations are recovered in the year following the end of the CIP usage year, without interest, and are subject to additional conditions, including an earnings test and an evaluation of BGSS related savings.

• In May 2013, the BPU approved NJNG's fiscal 2013 BGSS/CIP rate on a final basis. In addition, NJNG notified the BPU that it was going to reduce its current BGSS rate resulting in a 5.2 percent decrease to an average residential heat customer's bill, effective June 2013 and submitted its fiscal 2014 BGSS/CIP filing, which proposes a 1 percent reduction to an average residential heat customer's bill related to the CIP factor for fiscal 2014.

Infrastructure Programs

• In October 2012, the BPU approved NJNG's Safety Acceleration and Facility Enhancement (SAFE) program, allowing a four-year incremental capital investment program of $130 million, exclusive of allowance for funds used during construction (AFUDC) accruals.

• In November 2012, NJNG submitted a filing requesting a base rate increase of $6.9 million for Accelerated Infrastructure Programs (AIP), related to the initial phase of AIP (AIP I) and the second phase of AIP (AIP II) infrastructure investments installed in NJNG's distribution and transmission systems through October 31, 2012. In May 2013, the BPU approved a $6.5 million base rate increase.

Energy Efficiency Programs (EE)

• In January 2013, the BPU approved a stipulation to extend NJNG's current SAVEGREEN Project^® (SAVEGREEN) through June 30, 2013. In June 2013, the BPU issued an Order approving NJNG's July 2012 request to extend and expand the current SAVEGREEN projects through June 30, 2015, with certain modifications, resulting in a planned investment of more than $85 million and including a weighted average cost of capital of 6.9 percent. In addition, the BPU approved a rate increase of approximately 1.7 percent related to the NJNG EE Tariff Rider to recover prior EE program costs and EE investments related to the SAVEGREEN programs.

Societal Benefits Clause (SBC)

• In November 2012, the BPU approved NJNG's funding obligations for NJCEP for the period from January 1, 2013 to June 30, 2013 of approximately $9.8 million. In June 2013, the BPU approved NJNG's funding obligations for July 1, 2013 to June 30, 2014, of approximately $15.6 million. Accordingly, NJNG recorded the obligation and corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets.

• In March 2013, the BPU approved a February 2012 filing that requested approval of NJNG's Manufactured Gas Plant (MGP) expenditures incurred through June 30, 2011, maintaining the existing overall SBC rate. In July 2013, NJNG filed an SBC petition with the BPU requesting a reduction to the Remediation Adjustment (RA) factor and approval of the related MGP expenditures for the period July 1, 2011 through June 30, 2013, along with an increase to the NJCEP factor.

• In June 2013, NJNG filed its annual Universal Service Fund (USF) petition with the BPU. The USF filing is a statewide filing and includes a proposed reduction to the current USF per therm rate.

Other Regulatory Initiatives

• In November 2012, NJNG filed a petition with the BPU requesting deferral accounting for uninsured incremental operating and maintenance costs associated with Superstorm Sandy, which was subsequently approved in May 2013. In addition, NJNG requested that the review of and the appropriate recovery period for such deferred expenses be addressed in the Company's next base rate case. As of June 30, 2013, NJNG has recorded a regulatory asset in the amount of $14.9 million related to these costs.

In March 2013, the BPU issued an Order establishing a generic proceeding to review the prudency of costs incurred by New Jersey utility companies in response to major storm events in 2011 and 2012. In July 2013, NJNG filed its detailed report including unreimbursed, uninsured incremental storm restoration costs and capital expenditures related to Superstorm Sandy.

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DERIVATIVE INSTRUMENTS - VOLUME (Details)	Jun. 30, 2013 MMcf		Sep. 30, 2012 MMcf
NJNG [Member] | Futures [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	17,000		16,100
NJNG [Member] | Swaps [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	0	[1]	3,400	[1]
NJNG [Member] | Options [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	700		0
NJRES [Member] | Futures [Member] | Short Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	(50,200)		(28,600)
NJRES [Member] | Swaps [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	0	[1]	13,200	[1]
NJRES [Member] | Options [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	0		4,400
NJRES [Member] | Physical [Member] | Long Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	22,100
NJRES [Member] | Physical [Member] | Short Position [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount			(3,500)

[1] In October 2012, following the implementation of the Dodd-Frank Wall Street Reform and Consumer Protection Act, the Intercontinental Exchange (ICE) converted its cleared energy “swap” contracts to “futures” contracts and the New York Mercantile Exchange (NYMEX) amended their product titles to remove the word “swap” from the titles of their “futures” and “option” contracts.

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EMPLOYEE BENEFIT PLANS (Tables)

9 Months Ended

Jun. 30, 2013

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Benefit Costs

The components of the net periodic cost for pension benefits, including the Company's Pension Equalization Plan, and OPEB costs (principally health care and life insurance) for employees and covered dependents were as follows:

	Pension												OPEB
	Three Months Ended						Nine Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						June 30,						June 30,
(Thousands)	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	1,718		$	1,344		$	5,154		$	4,032		$	1,171		$	896		$	3,513		$	2,688
Interest cost	2,235			2,206			6,705			6,618			1,287			1,283			3,861			3,849
Expected return on plan assets	(3,706		)	(3,171		)	(11,118		)	(9,513		)	(913		)	(687		)	(2,739		)	(2,059		)
Recognized actuarial loss	1,911			1,254			5,733			3,762			964			724			2,892			2,172
Prior service cost amortization	27			11			81			33			(281		)	6			(267		)	18
Recognized net initial obligation	—			—			—			—			199			89			21			267
Net periodic benefit cost	$	2,185		$	1,644		$	6,555		$	4,932		$	2,427		$	2,311		$	7,281		$	6,935

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - GAS IN STORAGE (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013 MMcf	Sep. 30, 2012 MMcf
Public Utilities, Inventory [Line Items]
Gas in storage	$ 280,118	$ 265,193
Gas in storage (BCF)	68,600	67,700
NJNG [Member]
Public Utilities, Inventory [Line Items]
Gas in storage	63,900	145,379
Gas in storage (BCF)	12,300	22,200
NJRES [Member]
Public Utilities, Inventory [Line Items]
Gas in storage	$ 216,218	$ 119,814
Gas in storage (BCF)	56,300	45,500

XML

REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Sep. 30, 2012
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	$ 21,013	$ 32,734
Regulatory assets-noncurrent	460,232	441,263
Regulatory liability-current	1,191	1,169
Regulatory liabilities-noncurrent	78,429	67,077
Derivatives at Fair Value, Net [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liability-current	1,191	1,169
Cost of Removal Obligation [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	77,581	65,994
Derivatives at Fair Valu, Net [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	0	1,000
Other [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	848	83
Conservation Incentive Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	18,954	25,681
Underrecovered Gas Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	2,059	7,053
Environmental Remediation Costs Expended, Net of Recoveries [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	47,405	59,745
Environmental Remediation Costs Liability for Future Expenditures [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	182,000	182,000
Deferred Income Taxes [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	11,405	11,405
Derivatives at Fair Value, Net [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	386	0
Energy Efficiency Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	38,759	26,025
New Jersey Clean Energy Program (NJCEP) [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	16,953	5,619
Postemployment and Other Benefit Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	135,303	142,495
Deferred Superstorm Sandy Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	14,916	0
Other [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	$ 13,105	$ 13,974

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COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details) (USD $)	0 Months Ended			9 Months Ended
	Mar. 20, 2013	Jun. 30, 2013	Sep. 30, 2012	Jun. 30, 2013 Minimum [Member]	Jun. 30, 2013 Maximum [Member]	Jun. 30, 2013 Environmental Remediation Costs Expended, Net of Recoveries [Member]	Sep. 30, 2012 Environmental Remediation Costs Expended, Net of Recoveries [Member]	Jun. 30, 2013 Environmental Remediation Costs Liability for Future Expenditures [Member]	Sep. 30, 2012 Environmental Remediation Costs Liability for Future Expenditures [Member]
Site Contingency [Line Items]
Site contingency, recovery from third party of environmental remediation cost	$ 20,000,000
Regulatory assets		460,232,000	441,263,000			47,405,000	59,745,000	182,000,000	182,000,000
Litigation settlement, gross				$ 159,600,000	$ 266,400,000

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DEBT - SCHEDULE OF LONG TERM DEBT (Details) (USD $)	9 Months Ended	12 Months Ended
	Jun. 30, 2013 NJNG [Member]	Sep. 30, 2012 NJNG [Member]	Jun. 30, 2013 NJNG [Member] Bank Revolving Credit Facility [Member]		Sep. 30, 2012 NJNG [Member] Bank Revolving Credit Facility [Member]		Jun. 30, 2013 NJR [Member] Bank Revolving Credit Facility [Member]		Sep. 30, 2012 NJR [Member] Bank Revolving Credit Facility [Member]		Mar. 31, 2013 NJR [Member] Debt Shelf Facility Metlife [Member]	Jun. 30, 2013 Debt Shelf Facility Prudential [Member] NJR [Member]	Jun. 30, 2013 Unsecured senior note 1.94% [Member] Debt Shelf Facility Metlife [Member] NJR [Member]	Jun. 30, 2013 Unsecured senior note 2.51% [Member] Debt Shelf Facility Metlife [Member] NJR [Member]	Jun. 30, 2013 Unsecured senior note 3.25% [Member] Debt Shelf Facility Prudential [Member] NJR [Member]
Debt Instrument [Line Items]
Remaining borrowing capacity			$ 154,000,000		$ 65,000,000		$ 107,710,000	[1]	$ 166,339,000	[1]		$ 25,000,000
Sale leaseback transaction, gross proceeds	7,100,000	6,500,000
Line of credit facility, maximum borrowing capacity			250,000,000	[2]	200,000,000	[2]	325,000,000	[2]	325,000,000	[2]	100,000,000	75,000,000
Amount issued and outstanding													25,000,000	25,000,000	50,000,000
Proceeds from issuance of long-term debt	$ 50,000,000
Interest rate, stated percentage	3.15%												1.94%	2.51%	3.25%

[1] Letters of credit outstanding total $16.4 million and $13.9 million as of June 30, 2013 and September 30, 2012, respectively, which reduces amount available.

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

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FAIR VALUE - HIERARCHY (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013		Sep. 30, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 67,198		$ 50,349
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	11,482	[1]	11,009	[1]
Other	1,096	[2]	30	[2]
Total assets at fair value	79,776		61,388
Total liabilities at fair value	40,327		45,573
Fair Value, Measurements, Recurring [Member] | Physical Forward Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	8,616		20,248
Liabilities	10,135		9,746
Fair Value, Measurements, Recurring [Member] | Financial Derivative Contracts - Natural Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	58,531		29,915
Liabilities	30,152		35,715
Fair Value, Measurements, Recurring [Member] | Financial Derivative Contracts - Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	51		186
Liabilities	40		112
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	11,482	[1]	11,009	[1]
Other	1,096	[2]	30	[2]
Total assets at fair value	71,109		25,309
Total liabilities at fair value	30,115		16,922
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Physical Forward Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Financial Derivative Contracts - Natural Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	58,531		14,270
Liabilities	30,115		16,922
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Financial Derivative Contracts - Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	0	[1]	0	[1]
Other	0	[2]	0	[2]
Total assets at fair value	8,667		36,079
Total liabilities at fair value	10,212		28,651
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Physical Forward Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	8,616		20,248
Liabilities	10,135		9,746
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Financial Derivative Contracts - Natural Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0		15,645
Liabilities	37		18,793
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Financial Derivative Contracts - Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	51		186
Liabilities	40		112
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	0	[1]	0	[1]
Other	0	[2]	0	[2]
Total assets at fair value	0		0
Total liabilities at fair value	0		0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Physical Forward Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Financial Derivative Contracts - Natural Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0		0
Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Financial Derivative Contracts - Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0		0
Liabilities	$ 0		$ 0

[1] Included in Other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets

[2] Includes various money market funds.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Net income (loss)	$ 29,155	$ (10,320)	$ 134,830	$ 101,572
Other comprehensive income, net of tax
Unrealized gain on available for sale securities, net of tax of $(9), $(79), $(235) and $(104), respectively	13	114	340	150
Net unrealized (loss) on derivatives, net of tax of $13, $8, $23 and $49, respectively	(22)	(14)	(39)	(84)
Adjustment to postemployment benefit obligation, net of tax of $(203), $(149), $(608) and $(448), respectively	296	220	1,005	658
Other comprehensive income	287	320	1,306	724
Comprehensive income (loss)	$ 29,442	$ (10,000)	$ 136,136	$ 102,296

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DEBT

9 Months Ended

Jun. 30, 2013

Debt Disclosure [Abstract]

DEBT

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 credit facilities are as follows:

(Thousands)	June 30, 2013			September 30, 2012			Maturity Dates
NJNG
Bank credit facility dedicated to EDA Bonds (1) (2) (3)	$	100,000		$	100,000		August 2015
Bank revolving credit facility (1)	$	250,000		$	200,000		August 2014
Amount outstanding at end of period	$	96,000		$	135,000
Weighted average interest rate at end of period	0.15		%	0.18		%
Amount available at end of period	$	154,000		$	65,000
NJR
Bank revolving credit facility(1)	$	325,000		$	325,000		August 2017
Amount outstanding at end of period	$	200,900		$	144,800
Weighted average interest rate at end of period	1.12		%	1.16		%
Amount available at end of period (4)	$	107,710		$	166,339

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

(2) There were no borrowings outstanding as of June 30, 2013 and September 30, 2012, respectively.

(3) New Jersey Economic Development Authority (EDA) Bonds.

(4) Letters of credit outstanding total $16.4 million and $13.9 million as of June 30, 2013 and September 30, 2012, respectively, which reduces amount available.

NJNG

NJNG received $7.1 million and $6.5 million in December 2012 and 2011, respectively, in connection with the sale-leaseback of its natural gas meters. NJNG records a capital lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease.

On October 4, 2012, the BPU approved a petition filed by NJNG requesting authorization over a three-year period to issue medium-term debt with a maturity of not more than 30 years, renew its revolving credit facility expiring August 2014, renew its credit facility supporting NJNG's obligations with respect to bonds issued by the New Jersey Economic Development Authority, enter into interest rate risk management transactions and increase the size of its meter leasing program on a permanent basis.

On November 30, 2012, NJNG utilized the accordion option available under its committed revolving syndicated credit facility to increase the amount of credit available from $200 million to $250 million.

On April 15, 2013, NJNG issued $50 million of 3.15 percent senior secured notes due April 15, 2028 (Notes) in the private placement market pursuant to a note purchase agreement entered into on February 8, 2013. Interest is payable on the Notes semi-annually. The proceeds from the Notes were used to refinance short-term debt and will fund capital expenditure requirements.

NJR

On May 12, 2011, NJR entered into an unsecured, uncommitted $100 million private placement shelf note agreement allowing NJR to issue senior notes during a two-year issuance period, which expired on May 10, 2013. As of June 30, 2013, under the terms of the agreement, NJR has $25 million of 1.94 percent senior notes due September 15, 2015, and $25 million of 2.51 percent senior notes due September 15, 2018 issued and outstanding.

On June 30, 2011, NJR entered into an unsecured, uncommitted $75 million private placement shelf note agreement allowing NJR to issue senior notes during a three-year issuance period ending June 30, 2014. As of June 30, 2013, under the terms of the agreement, NJR has $50 million of 3.25 percent senior notes due September 17, 2022 issued and outstanding and $25 million remaining available for borrowing.

On June 5, 2013, NJR entered into a new agreement permitting the issuance of stand-alone letters of credit for up to $10 million through June 5, 2014. No amounts have been drawn under this arrangement as of June 30, 2013.

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CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 134,830	$ 101,572
Adjustments to reconcile net income to cash flows from operating activities:
Unrealized (gain) loss on derivative instruments	(23,683)	17,596
Depreciation and amortization	34,966	30,726
Allowance for equity used during construction	(1,926)	(317)
Allowance for bad debt expense	1,829	1,989
Deferred income taxes	23,406	30,588
Manufactured gas plant remediation costs	(5,326)	(6,125)
Equity in earnings of affiliates, net of distributions received	(1,050)	4,209
Cost of removal - asset retirement obligations	(926)	(912)
Contributions to postemployment benefit plans	(24,538)	(24,446)
Changes in:
Components of working capital	(22,092)	(110,114)
Other noncurrent assets	(2,607)	8,747
Other noncurrent liabilities	12,256	6,404
Cash flows from operating activities	125,139	59,917
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Utility plant expenditures	(73,654)	(71,916)
Solar equipment expenditures	(39,756)	(75,243)
Real estate properties and other expenditures	(532)	(568)
Cost of removal expenditures	(21,186)	(10,634)
Distribution from equity investees	2,107	0
Proceeds from sale of available-for-sale securities	482	0
Withdrawal from restricted cash construction fund	0	126
Cash flows (used in) investing activities	(132,539)	(158,235)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common stock	10,581	10,636
Tax benefit from stock options exercised	110	222
Proceeds from sale-leaseback transaction	7,076	6,522
Proceeds from long-term debt	50,000	0
Payments of long-term debt	(5,808)	(4,856)
Purchases of treasury stock	(23,689)	(8,768)
Payments of common stock dividends	(50,619)	(46,466)
Net proceeds from short-term debt	17,100	140,650
Cash flows from financing activities	4,751	97,940
Change in cash and cash equivalents	(2,649)	(378)
Cash and cash equivalents at beginning of period	4,509	7,440
Cash and cash equivalents at end of period	1,860	7,062
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	(120,719)	36,598
Inventories	(24,792)	78,601
Recovery of gas costs	4,994	(13,405)
Gas purchases payable	86,932	(99,173)
Prepaid and accrued taxes	20,059	(11,375)
Accounts payable and other	(6,385)	9,754
Restricted broker margin accounts	26,760	(20,320)
Customers' credit balances and deposits	(30,899)	(75,318)
Other current assets	21,958	(15,476)
Components of working capital	(22,092)	(110,114)
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for Interest (net of amounts capitalized)	11,121	8,918
Cash paid for Income taxes	9,539	7,536
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING ACTIVITIES
Accrued capital expenditures	$ (9,734)	$ (108)

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013		Sep. 30, 2012
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ 2,991,195		$ 2,770,005
Natural Gas Distribution [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	2,062,913		2,005,520
Clean Energy Ventures [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	253,680		223,247
Energy Services [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	497,941		347,406
Midstream Investments [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	156,135		157,779
Categorized Business Segments [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	2,970,669		2,733,952
Retail and Other [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	86,920		73,298
Eliminations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ (66,394)	[1]	$ (37,245)	[1]

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

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended				9 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
OPERATING REVENUES
Utility	$ 119,022		$ 106,764		$ 689,621		$ 524,161
Nonutility	648,447		318,357		1,774,752		1,156,292
Total operating revenues	767,469		425,121		2,464,373		1,680,453
OPERATING EXPENSES
Gas Purchases - Utility	55,708		45,916		356,069		209,847
Gas Purchases - Nonutility	593,534		333,402		1,660,528		1,121,874
Operation and maintenance	43,630		40,857		126,767		118,987
Regulatory rider expenses	6,258		5,835		44,014		36,821
Depreciation and amortization	11,942		10,687		34,966		30,726
Energy and other taxes	9,397		8,335		50,869		39,202
Total operating expenses	720,469		445,032		2,273,213		1,557,457
OPERATING INCOME (LOSS)	47,000		(19,911)		191,160		122,996
Other income	1,238		551		4,284		1,427
Interest expense, net of capitalized interest	6,008		4,834		17,579		15,266
INCOME (LOSS) BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	42,230		(24,194)		177,865		109,157
Income tax provision (benefit)	15,297		(11,230)		51,342		15,901
Equity in earnings of affiliates	2,222		2,644		8,307		8,316
NET INCOME (LOSS)	$ 29,155		$ (10,320)		$ 134,830		$ 101,572
EARNINGS (LOSS) PER COMMON SHARE
BASIC (usd per share)	$ 0.70		$ (0.25)		$ 3.23		$ 2.45
DILUTED (usd per share)	$ 0.70	[1]	$ (0.25)	[1]	$ 3.22	[1]	$ 2.44	[1]
DIVIDENDS PER COMMON SHARE (usd per share)	$ 0.40		$ 0.38		$ 1.20		$ 1.14
WEIGHTED AVERAGE SHARES OUTSTANDING
BASIC (in shares)	41,608		41,560		41,697		41,501
DILUTED (in shares)	41,732		41,560		41,820		41,643

[1] Since there was a net loss for the three months ended June 30, 2012, incremental shares of 140 were not included in the computation of diluted loss per common share, as their effect would have been anti-dilutive. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and nine months ended June 30, 2013 and the nine months ended June 30, 2012.

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EMPLOYEE BENEFIT PLANS - DEFINED BENEFIT PLANS (Details) (USD $)	3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended
	Jun. 30, 2013 Pension [Member]	Jun. 30, 2012 Pension [Member]	Jun. 30, 2013 Pension [Member]	Jun. 30, 2012 Pension [Member]	Jun. 30, 2013 OPEB [Member]	Jun. 30, 2012 OPEB [Member]	Jun. 30, 2013 OPEB [Member]	Jun. 30, 2012 OPEB [Member]	Dec. 31, 2012 Pension Plans Excluding Pension Equalization Plan, Defined Benefit [Member]	Dec. 31, 2011 Pension Plans Excluding Pension Equalization Plan, Defined Benefit [Member]
Components of net periodic cost
Service cost	$ 1,718,000	$ 1,344,000	$ 5,154,000	$ 4,032,000	$ 1,171,000	$ 896,000	$ 3,513,000	$ 2,688,000
Interest cost	2,235,000	2,206,000	6,705,000	6,618,000	1,287,000	1,283,000	3,861,000	3,849,000
Expected return on plan assets	(3,706,000)	(3,171,000)	(11,118,000)	(9,513,000)	(913,000)	(687,000)	(2,739,000)	(2,059,000)
Recognized actuarial loss	1,911,000	1,254,000	5,733,000	3,762,000	964,000	724,000	2,892,000	2,172,000
Prior service cost amortization	27,000	11,000	81,000	33,000	(281,000)	6,000	(267,000)	18,000
Recognized net initial obligation	0	0	0	0	199,000	89,000	21,000	267,000
Net periodic cost	2,185,000	1,644,000	6,555,000	4,932,000	2,427,000	2,311,000	7,281,000	6,935,000
Defined benefit plan, contributions by employer									$ 20,000,000	$ 20,000,000

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COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

9 Months Ended

Jun. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment

Commitments as of June 30, 2013, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2013		2014		2015		2016		2017		Thereafter
NJRES:
Natural gas purchases	$	247,632	$	126,175	$	31,225	$	16,800	$	—	$	—
Storage demand fees	9,615		26,098		12,005		7,114		5,035		7,318
Pipeline demand fees	18,557		31,851		18,133		9,576		8,225		9,756
Sub-total NJRES	$	275,804	$	184,124	$	61,363	$	33,490	$	13,260	$	17,074
NJNG:
Natural gas purchases	$	37,843	$	94,047	$	103,080	$	8,755	$	113	$	—
Storage demand fees	7,061		28,208		21,283		11,956		9,990		23,247
Pipeline demand fees	15,504		75,442		41,596		34,558		32,753		221,838
Sub-total NJNG	$	60,408	$	197,697	$	165,959	$	55,269	$	42,856	$	245,085
Total (1)	$	336,212	$	381,821	$	227,322	$	88,759	$	56,116	$	262,159

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

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DERIVATIVE INSTRUMENTS (Tables)

9 Months Ended

Jun. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

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

			Fair Value
			June 30, 2013						September 30, 2012
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	51		$	17		$	116		$	97
	Derivatives - noncurrent		—			23			70			15
Fair value of derivatives designated as hedging instruments			$	51		$	40		$	186		$	112
Derivatives not designated as hedging instruments:
NJNG:
Financial derivative contracts	Derivatives - current		$	4,496		$	3,305		$	6,203		$	5,034
	Derivatives - noncurrent		—			386			1,000			—
NJRES:
Physical forward commodity contracts	Derivatives - current		8,296			10,119			19,590			9,530
	Derivatives - noncurrent		320			16			658			216
Financial derivative contracts	Derivatives - current		52,635			22,770			22,112			27,779
	Derivatives - noncurrent		1,400			3,691			600			2,902
Fair value of derivatives not designated as hedging instruments			$	67,147		$	40,287		$	50,163		$	45,461
Total fair value of derivatives			$	67,198		$	40,327		$	50,349		$	45,573

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location

The following table reflects the effect of derivative instruments on the Unaudited Condensed Consolidated Statements of Operations as of:

(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
Derivatives not designated as hedging instruments:		2013			2012			2013			2012
NJRES:
Physical commodity contracts	Operating revenues	$	3,595		$	(2,860	)	$	(4,264	)	$	(6,023	)
Physical commodity contracts	Gas purchases	(8,809		)	8,155			(6,253		)	12,546
Financial derivative contracts	Gas purchases	39,601			(9,717		)	38,134			93,248
Total unrealized and realized gains (losses)		$	34,387		$	(4,422	)	$	27,617		$	99,771

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance

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

(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
	June 30,					June 30,						June 30,
Derivatives in cash flow hedging relationships:	2013			2012		2013			2012			2013		2012
Foreign currency contracts	$	(14	)	$	12	$	(21	)	$	(35	)	$	—	$	—

(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion) (1)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)					Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Nine Months Ended						Nine Months Ended					Nine Months Ended
	June 30,						June 30,					June 30,
Derivatives in cash flow hedging relationships:	2013			2012			2013		2012			2013		2012
Foreign currency contracts	$	(85	)	$	(63	)	$	23	$	(70	)	$	—	$	—

(1) The settlement of foreign currency transactions over the next twelve months is expected to result in the reclassification of $33,000 from OCI into earnings. The maximum tenor is April 2015

Schedule of Derivative Instruments

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

			Volume (Bcf)
			June 30, 2013		September 30, 2012
NJNG	Futures		17.0		16.1
	Swaps	(1)	—		3.4
	Options		0.7		—
NJRES	Futures		(50.2	)	(28.6	)
	Swaps	(1)	—		13.2
	Options		—		4.4
	Physical		22.1		(3.5	)

(1) In October 2012, following the implementation of the Dodd-Frank Wall Street Reform and Consumer Protection Act, the Intercontinental Exchange (ICE) converted its cleared energy “swap” contracts to “futures” contracts and the New York Mercantile Exchange (NYMEX) amended their product titles to remove the word “swap” from the titles of their “futures” and “option” contracts.

Schedule of Due to (from) Broker-Dealers and Clearing Organizations

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

(Thousands)	Balance Sheet Location	June 30, 2013		September 30, 2012
NJNG	Broker margin - Current assets	$	1,350	$	1,713
NJRES	Broker margin - Current assets	$	—	$	20,216
NJRES	Broker margin - Current liabilities	$	6,181	$	—

Schedules of Concentration of Risk, by Risk Factor

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		$	199,972
Noninvestment grade		5,679
Internally rated investment grade		34,692
Internally rated noninvestment grade		4,461
Total		$	244,804

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FAIR VALUE - DEBT (Details) (Level 2 [Member], USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Sep. 30, 2012
Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 529,845	$ 479,845
Fair Market Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 558,336	$ 530,056

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COMMITMENTS AND CONTINGENT LIABILITIES - CAPITAL EXPENDITURES (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Jun. 30, 2013
Gas Distribution [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures	$ 146.3
Estimated capital expenditures subsequent fiscal year	119.9
Capital expenditures paid and accrued	100.0
SAFE Related Expenditures [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures	29.9
Estimated capital expenditures subsequent fiscal year	43.4
Capital expenditures paid and accrued	15.7
AIP II Construction Costs [Member]
Long-term Purchase Commitment [Line Items]
Capital expenditures paid and accrued	11.5
Natural Disasters and Other Casualty Events [Member]
Long-term Purchase Commitment [Line Items]
Capital expenditures paid and accrued	24.7
Natural Disasters and Other Casualty Events [Member] | Minimum [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures	26.0
Estimated capital expenditures subsequent fiscal year	30.0
Natural Disasters and Other Casualty Events [Member] | Maximum [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures	30.0
Estimated capital expenditures subsequent fiscal year	40.0
Solar Related Expenditures [Member]
Long-term Purchase Commitment [Line Items]
Capital expenditures paid and accrued	51.1
Payments to acquire productive assets	39.8
Solar Related Expenditures [Member] | Minimum [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures	55.0
Solar Related Expenditures [Member] | Maximum [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures	60.0
Solar Related Expenditures Land Only [Member] | Minimum [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures subsequent fiscal year	70.0
Solar Related Expenditures Land Only [Member] | Maximum [Member]
Long-term Purchase Commitment [Line Items]
Estimated capital expenditures subsequent fiscal year	$ 90.0

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DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) (USD $)	Jun. 30, 2013	Sep. 30, 2012
Derivatives, Fair Value [Line Items]
Derivative assets, current	$ 65,478,000	$ 48,021,000
Derivative liabilities, current	36,211,000	42,440,000
Derivative assets, noncurrent	1,720,000	2,328,000
Derivative liabilities, noncurrent	4,116,000	3,133,000
Derivative assets	67,198,000	50,349,000
Derivative liabilities	40,327,000	45,573,000
Notional amount of foreign currency derivatives	3,800,000
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	67,147,000	50,163,000
Derivative liabilities	40,287,000	45,461,000
Foreign Exchange Contract [Member] | NJRES [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, current	51,000	116,000
Derivative liabilities, current	17,000	97,000
Derivative assets, noncurrent	0	70,000
Derivative liabilities, noncurrent	23,000	15,000
Derivative assets	51,000	186,000
Derivative liabilities	40,000	112,000
Financial Commodity Contracts [Member] | NJRES [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, current	52,635,000	22,112,000
Derivative liabilities, current	22,770,000	27,779,000
Derivative assets, noncurrent	1,400,000	600,000
Derivative liabilities, noncurrent	3,691,000	2,902,000
Financial Commodity Contracts [Member] | NJNG [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, current	4,496,000	6,203,000
Derivative liabilities, current	3,305,000	5,034,000
Derivative assets, noncurrent	0	1,000,000
Derivative liabilities, noncurrent	386,000	0
Physical Commodity Contracts [Member] | NJRES [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, current	8,296,000	19,590,000
Derivative liabilities, current	10,119,000	9,530,000
Derivative assets, noncurrent	320,000	658,000
Derivative liabilities, noncurrent	$ 16,000	$ 216,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - DISPOSAL OF EQUIPMENT (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Jun. 30, 2013
Accounting Policies [Abstract]
Loss on disposal of asset	$ 766
Unusual or infrequent item, insurance proceeds	$ 954

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended		9 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013		Jun. 30, 2013	Jun. 30, 2012
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance as of January 1, 2013			$ (10,688)
Other comprehensive income, excluding reclassifications, net of tax of $(611), $(4), $-, $(615)			891
Amounts reclassified from accumulated other comprehensive income, net of tax of $155, $21 $(405), $(229)			327
Other comprehensive income	287	320	1,218		1,306	724
Ending balance as of March 31, 2013	(9,470)		(9,470)		(9,470)
Other comprehensive income, excluding reclassifications, tax			(615)
Amounts reclassified from accumulated other comprehensive income, tax			(229)
Net current-period other comprehensive income, tax			(844)
Unrealized Gain on Available for Sale Securities [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance as of January 1, 2013			4,601
Other comprehensive income, excluding reclassifications, net of tax of $(611), $(4), $-, $(615)			885
Amounts reclassified from accumulated other comprehensive income, net of tax of $155, $21 $(405), $(229)			(225)	[1]
Other comprehensive income			660
Ending balance as of March 31, 2013	5,261		5,261		5,261
Other comprehensive income, excluding reclassifications, tax			(611)
Amounts reclassified from accumulated other comprehensive income, tax			155
Net current-period other comprehensive income, tax			(456)
Net Unrealized Gain on Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance as of January 1, 2013			41
Other comprehensive income, excluding reclassifications, net of tax of $(611), $(4), $-, $(615)			6
Amounts reclassified from accumulated other comprehensive income, net of tax of $155, $21 $(405), $(229)			(40)	[2]
Other comprehensive income			(34)
Ending balance as of March 31, 2013	7		7		7
Other comprehensive income, excluding reclassifications, tax			(4)
Amounts reclassified from accumulated other comprehensive income, tax			21
Net current-period other comprehensive income, tax			17
Adjustment to Postemployment Benefit Obligation [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance as of January 1, 2013			(15,330)
Other comprehensive income, excluding reclassifications, net of tax of $(611), $(4), $-, $(615)			0
Amounts reclassified from accumulated other comprehensive income, net of tax of $155, $21 $(405), $(229)			592	[3]
Other comprehensive income			592
Ending balance as of March 31, 2013	(14,738)		(14,738)		(14,738)
Other comprehensive income, excluding reclassifications, tax			0
Amounts reclassified from accumulated other comprehensive income, tax			(405)
Net current-period other comprehensive income, tax			$ (405)

[1] Reclassified to other income in the Unaudited Consolidated Statements of Operations.

[2] Reclassified to gas purchases in the Unaudited Consolidated Statements of Operations.

[3] Included in the computation of net periodic pension cost, a component of operations and maintenance expense in the Unaudited Consolidated Statements of Operations.

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EARNINGS PER SHARE

9 Months Ended

Jun. 30, 2013

Earnings Per Share [Abstract]

EARNINGS PER SHARE

EARNINGS PER SHARE

The following table presents the calculation of the Company's basic and diluted earnings per share for:

	Three Months Ended					Nine Months Ended
	June 30,					June 30,
(Thousands, except per share amounts)	2013		2012			2013		2012
Net income (loss), as reported	$	29,155	$	(10,320	)	$	134,830	$	101,572
Basic earnings per share
Weighted average shares of common stock outstanding-basic	41,608		41,560			41,697		41,501
Basic earnings (loss) per common share	$0.70		$(0.25)			$3.23		$2.45
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	41,608		41,560			41,697		41,501
Incremental shares (1)	124		—			123		142
Weighted average shares of common stock outstanding-diluted	41,732		41,560			41,820		41,643
Diluted earnings (loss) per common share (2)	$0.70		$(0.25)			$3.22		$2.44

(1) Incremental shares consist of stock options, stock awards and performance units.

(2) Since there was a net loss for the three months ended June 30, 2012, incremental shares of 140 were not included in the computation of diluted loss per common share, as their effect would have been anti-dilutive. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and nine months endedJune 30, 2013 and the nine months endedJune 30, 2012.

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA (Tables)

9 Months Ended

Jun. 30, 2013

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

Information related to the Company's various business segments and other operations is detailed below:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Operating revenues
Natural Gas Distribution
External customers	$	119,022		$	106,764		$	689,621		$	524,161
Clean Energy Ventures
External customers	2,563			370			7,182			1,277
Energy Services
External customers	632,414			306,273			1,735,411			1,126,435
Intercompany	1,119			(32		)	5,670			2,816
Segment subtotal	755,118			413,375			2,437,884			1,654,689
Retail and Other
External customers	13,470			11,714			32,159			28,580
Intercompany	234			278			683			720
Eliminations	(1,353		)	(246		)	(6,353		)	(3,536		)
Total	$	767,469		$	425,121		$	2,464,373		$	1,680,453
Depreciation and amortization
Natural Gas Distribution	$	9,537		$	8,860		$	28,213		$	26,241
Clean Energy Ventures	2,196			1,632			6,131			3,953
Energy Services	10			16			32			48
Midstream Investments	2			1			5			4
Segment subtotal	11,745			10,509			34,381			30,246
Retail and Other	196			178			586			480
Eliminations	1			—			(1		)	—
Total	$	11,942		$	10,687		$	34,966		$	30,726
Interest income (1)
Natural Gas Distribution	$	146		$	223		$	459		$	683
Energy Services	—			10			—			36
Midstream Investments	265			267			799			800
Segment subtotal	411			500			1,258			1,519
Retail and Other	(1		)	1			1			2
Eliminations	(217		)	(248		)	(667		)	(751		)
Total	$	193		$	253		$	592		$	770

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

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Interest expense, net of capitalized interest
Natural Gas Distribution	$	3,796		$	3,717		$	10,929		$	11,167
Clean Energy Ventures	870			190			2,475			530
Energy Services	615			214			1,823			729
Midstream Investments	466			653			1,533			2,050
Segment subtotal	5,747			4,774			16,760			14,476
Retail and Other	261			60			819			790
Total	$	6,008		$	4,834		$	17,579		$	15,266
Income tax provision (benefit)
Natural Gas Distribution	$	1,788		$	1,114		$	39,089		$	43,726
Clean Energy Ventures	(1,477		)	(3,013		)	(15,703		)	(30,010		)
Energy Services	12,945			(11,511		)	23,906			(2,108		)
Midstream Investments	1,073			1,126			3,935			3,750
Segment subtotal	14,329			(12,284		)	51,227			15,358
Retail and Other	1,378			1,056			349			685
Eliminations	(410		)	(2		)	(234		)	(142		)
Total	$	15,297		$	(11,230	)	$	51,342		$	15,901
Equity in earnings of affiliates
Midstream Investments	$	3,052		$	3,547		$	11,012		$	11,129
Eliminations	(830		)	(903		)	(2,705		)	(2,813		)
Total	$	2,222		$	2,644		$	8,307		$	8,316
Net financial earnings (loss)
Natural Gas Distribution	$	5,528		$	7,545		$	76,937		$	78,455
Clean Energy Ventures	(1,381		)	(1,157		)	9,078			20,802
Energy Services	2,097			(5,425		)	21,479			18,061
Midstream Investments	1,541			1,634			5,600			5,438
Segment subtotal	7,785			2,597			113,094			122,756
Retail and Other	1,944			1,549			813			860
Eliminations	9			(16		)	(12		)	(52		)
Total	$	9,738		$	4,130		$	113,895		$	123,564
Capital expenditures
Natural Gas Distribution	$	29,141		$	33,405		$	94,840		$	82,550
Clean Energy Ventures	14,891			13,457			39,756			75,243
Segment subtotal	44,032			46,862			134,596			157,793
Retail and Other	234			109			532			568
Total	$	44,266		$	46,971		$	135,128		$	158,361

Reconciliation of Consolidated Net Financial Earnings to Consolidated Net Income

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

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2013			2012			2013			2012
Consolidated net financial earnings	$	9,738		$	4,130		$	113,895		$	123,564
Less:
Unrealized (gain) loss from derivative instruments and related transactions, net of taxes (1) (2)	(27,915		)	20,834			(14,975		)	11,126
Effects of economic hedging related to natural gas inventory, net of taxes (3)	8,498			(6,384		)	(5,960		)	10,866
Consolidated net income (loss)	$	29,155		$	(10,320	)	$	134,830		$	101,572

(1) Excludes unrealized losses (gains) related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $708,000 and $(20,000) for the three months endedand $398,000 and $177,000 for the nine months endedJune 30, 2013 and 2012, respectively.

(2) Amounts are net of taxes of approximately $(17.1) million and $12.1 million, for the three months ended and $(9.2) million and $6.3 million for the nine months endedJune 30, 2013 and 2012, respectively.

(3) Amounts are net of taxes of approximately $4.9 million and $(3.7) million for the three months ended and $(3.5) million and $6.3 million for the nine months endedJune 30, 2013 and 2012, respectively.

Reconciliation of Assets from Segment to Consolidated

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

(Thousands)	June 30, 2013			September 30, 2012
Assets at end of period:
Natural Gas Distribution	$	2,062,913		$	2,005,520
Clean Energy Ventures	253,680			223,247
Energy Services	497,941			347,406
Midstream Investments	156,135			157,779
Segment subtotal	2,970,669			2,733,952
Retail and Other	86,920			73,298
Eliminations (1)	(66,394		)	(37,245		)
Total	$	2,991,195		$	2,770,005

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

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DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Sep. 30, 2012
Broker margin - Current assets	$ 1,350	$ 21,929
Broker margin - Current (liabilities)	6,181	0
NJNG [Member]
Broker margin - Current assets	1,350	1,713
NJRES [Member]
Broker margin - Current assets	0	20,216
Broker margin - Current (liabilities)	$ 6,181	$ 0

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INCOME TAXES

9 Months Ended

Jun. 30, 2013

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

NJR evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with unrecognized tax benefits. During the nine months endedJune 30, 2013 and 2012, 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 nine months endedJune 30, 2013 and 2012, are 27.6 percent and 13.5 percent, respectively. The change in the rate is due primarily to the impact of federal investment tax credits (ITC), net of deferred taxes, recognized in the nine months endedJune 30, 2013 and 2012, of $13.1 million and $27.2 million, respectively, which are generated by solar investments forecasted to be completed before the end of the fiscal year.

To calculate the estimated annual effective tax rate, NJR considers solar projects that are probable of being completed and placed in service during the current fiscal year based on the best information available at each reporting period. The estimate includes an assessment of various factors, such as board of director approval, status of contractual agreements, permitting, regulatory approval and interconnection. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

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INVESTMENTS IN EQUITY INVESTEES

9 Months Ended

Jun. 30, 2013

Equity Method Investments and Joint Ventures [Abstract]

INVESTMENTS IN EQUITY INVESTEES

INVESTMENTS IN EQUITY INVESTEES

Investment in equity investees includes NJR's equity method and cost method investments.

Equity Method Investments

(Thousands)	June 30, 2013		September 30, 2012
Steckman Ridge	$	130,715	$	132,931
Iroquois	23,915		22,864
Total	$	154,630	$	155,795

As of June 30, 2013, the investment in Steckman Ridge includes loans with a total outstanding principal balance of $70.4 million. The loans accrue interest at a variable rate that resets quarterly and are due 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 intercompany transactions.

Cost Method Investments

During the fourth quarter of fiscal 2012, NJR invested $8.8 million in OwnEnergy, a developer of on-shore wind projects. At that time, the investment represented a 19.9 percent equity interest. Under the terms of the investment agreements, other OwnEnergy investors had the opportunity to invest in the same round of equity financing that NJR participated in. As of June 30, 2013, NJR's ownership interest is 18.7 percentand is accounted for in accordance with the cost method of accounting.

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NATURE OF THE BUSINESS

9 Months Ended

Jun. 30, 2013

NATURE OF THE BUSINESS [Abstract]

NATURE OF THE BUSINESS

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 497,400 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 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 and on-shore wind investments;

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 Energy Holdings Corporation primarily invests in energy-related ventures through its subsidiaries, NJNR Pipeline Company, 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 Midstream Investments segment (formerly Energy Holdings segment);

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

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INCOME TAXES (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Income Tax Disclosure [Abstract]
Effective income tax rate	27.60%	13.50%
Income tax reconciliation, tax credits, investment	$ 13.1	$ 27.2

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INVESTMENTS IN EQUITY INVESTEES - SCHEDULE OF COST METHOD INVESTMENTS (Details) (OwnEnergy [Member], USD $) In Millions, unless otherwise specified	Jun. 30, 2013	Sep. 30, 2012
OwnEnergy [Member]
Schedule of Cost-method Investments [Line Items]
Cost method investments		$ 8.8
Cost method investment, ownership percentage	18.70%	19.90%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - AVAILABLE FOR SALE SECURITIES (Details) (USD $)	3 Months Ended
	Jun. 30, 2013		Sep. 30, 2012
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, gross unrealized gain (loss)	$ 8,900,000		$ 8,300,000
Accumulated other comprehensive income, available-for-sale securities adjustment, net of tax	5,300,000		4,900,000
Proceeds from Sale of Available-for-sale Securities, Equity	482,000
Available-for-sale Securities, Gross Realized Gains	380,000
Fair Value, Measurements, Recurring [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, fair value disclosure	11,482,000	[1]	11,009,000	[1]
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, fair value disclosure	$ 11,482,000	[1]	$ 11,009,000	[1]

[1] Included in Other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets

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RELATED PARTY TRANSACTIONS (Details) (USD $)	9 Months Ended						9 Months Ended	39 Months Ended		9 Months Ended				9 Months Ended
	Jun. 30, 2013 NJRES to Steckman RIdge and Iroquios Affliates [Member]	Jun. 30, 2012 NJRES to Steckman RIdge and Iroquios Affliates [Member]	Jun. 30, 2013 NJRES to Steckman Ridge Affiliate	Sep. 30, 2012 NJRES to Steckman Ridge Affiliate	Jun. 30, 2013 NJRES to Iroquois Affiliate [Member]	Sep. 30, 2012 NJRES to Iroquois Affiliate [Member]	Jun. 30, 2013 NJNG to Steckman RIdge Affiliate MMcf	Jun. 30, 2013 NJNG to Steckman RIdge Affiliate	Sep. 30, 2012 NJNG to Steckman RIdge Affiliate	Jun. 30, 2013 NJNG to Steckman RIdge and Iroquios Affiliates [Member]	Jun. 30, 2012 NJNG to Steckman RIdge and Iroquios Affiliates [Member]	Jun. 30, 2013 NJNG to Iroquois Affiliate [Member]	Sep. 30, 2012 NJNG to Iroquois Affiliate [Member]	Jun. 30, 2013 NJNG to NJRES Affiliate [Member] MMcf
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement	$ 4,600,000	$ 5,000,000								$ 4,300,000	$ 3,900,000
Due to related parties			157,000	170,000	392,000	394,000	775,000	775,000	775,000			61,000	61,000
Related party agreement term								10 years
Agreement for natural gas storage capacity between NJNG and affiliate (MMcf)							3,000
Approximate annual demand fees under agreement from April 1 2010 to March 31 2020							$ 9,300,000
Natural gas sold at cost under asset management agreement (MMcf)														1,000

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RELATED PARTY TRANSACTIONS

9 Months Ended

Jun. 30, 2013

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS

NJRES may periodically enter into storage, or park and loan agreements with its affiliated FERC-regulated natural gas storage facility, Steckman Ridge, or transportation agreements with its affiliated FERC-regulated interstate pipeline, Iroquois Gas Transmission. As of June 30, 2013, NJRES has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which expire by June 2014. Additionally, NJRES has transportation capacity with Iroquois Gas Transmission that expires by March 2019. Demand fees, net of eliminations, associated with both Steckman Ridge and Iroquois Gas Transmission were $4.6 million and $5 million during the nine months endedJune 30, 2013 and 2012, respectively. As of June 30, 2013, NJRES had demand fees payable of $157,000 and $392,000 to Steckman Ridge and Iroquois Gas Transmission, respectively, which are included in gas purchases payable. As of September 30, 2012, fees payable to Steckman Ridge and Iroquois Gas Transmission, were $170,000 and $394,000, 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, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG's BGSS mechanism and are included in regulatory assets. Additionally, NJNG has transportation capacity with Iroquois Gas Transmission that expires by January 2019. Demand fees, net of eliminations, associated with both Steckman Ridge and Iroquois Gas Transmission were $4.3 million and $3.9 million during the nine months endedJune 30, 2013 and 2012, respectively. NJNG had demand fees payable to Steckman Ridge in the amount of $775,000 as of both June 30, 2013 and September 30, 2012. NJNG had fees payable to Iroquois Gas Transmission of $61,000 as of both June 30, 2013 and September 30, 2012.

In December 2009, NJNG and NJRES entered into an asset management agreement that began in January 2010 and ends in March 2014. 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

9 Months Ended

Jun. 30, 2013

Compensation and Retirement Disclosure [Abstract]

EMPLOYEE BENEFIT PLANS

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						Nine Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						June 30,						June 30,
(Thousands)	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	1,718		$	1,344		$	5,154		$	4,032		$	1,171		$	896		$	3,513		$	2,688
Interest cost	2,235			2,206			6,705			6,618			1,287			1,283			3,861			3,849
Expected return on plan assets	(3,706		)	(3,171		)	(11,118		)	(9,513		)	(913		)	(687		)	(2,739		)	(2,059		)
Recognized actuarial loss	1,911			1,254			5,733			3,762			964			724			2,892			2,172
Prior service cost amortization	27			11			81			33			(281		)	6			(267		)	18
Recognized net initial obligation	—			—			—			—			199			89			21			267
Net periodic benefit cost	$	2,185		$	1,644		$	6,555		$	4,932		$	2,427		$	2,311		$	7,281		$	6,935

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 discretionary contributions of $20 million to the pension plans in both December 2012 and 2011.

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REGULATION (Tables)

9 Months Ended

Jun. 30, 2013

Regulated Operations [Abstract]

Schedule of Regulatory Assets and Liabilities

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

(Thousands)	June 30, 2013		September 30, 2012
Regulatory assets-current
Conservation Incentive Program	$	18,954	$	25,681
Underrecovered gas costs	2,059		7,053
Total current	$	21,013	$	32,734
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	47,405	$	59,745
Liability for future expenditures	182,000		182,000
Deferred income taxes	11,405		11,405
Derivatives at fair value, net	386		—
Energy Efficiency Program	38,759		26,025
New Jersey Clean Energy Program (NJCEP)	16,953		5,619
Postemployment and other benefit costs	135,303		142,495
Deferred Superstorm Sandy costs	14,916		—
Other	13,105		13,974
Total noncurrent	$	460,232	$	441,263
Regulatory liability-current
Derivatives at fair value, net	$	1,191	$	1,169
Total current	$	1,191	$	1,169
Regulatory liabilities-noncurrent
Cost of removal obligation	$	77,581	$	65,994
Derivatives at fair value, net	—		1,000
Other	848		83
Total noncurrent	$	78,429	$	67,077

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

9 Months Ended

Jun. 30, 2013

Accounting Policies [Abstract]

Available for Sale Securities

Included in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets are certain investments in equity securities of a publicly traded energy company that have a fair value of $11.5 million and $11 million as of June 30, 2013 and September 30, 2012, respectively. Total unrealized gains associated with these equity securities, which are included as a part of accumulated other comprehensive income, a component of common stock equity, were $8.9 million ($5.3 million, after tax) and $8.3 million ($4.9 million, after tax) as of June 30, 2013 and September 30, 2012, respectively. During the third quarter of fiscal 2013, NJR received proceeds of approximately $482,000 from the sale of available-for-sale securities and realized a pre-tax gain of $380,000, which is included in other income in the Unaudited Condensed Consolidated Statements of Operations. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

Derivatives

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, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or (losses). For NJRES at settlement, realized gains and (losses) on all financial derivative instruments are recognized as a component of gas purchases and realized gains and (losses) on all physical derivatives follow the presentation of the related unrealized gains and (losses) as a component of either gas purchases or operating revenues.

NJRES also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the US dollar. NJRES utilizes foreign currency derivatives to lock in the currency translation rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are being used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company has designated these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in other comprehensive income (OCI). When the foreign exchange contracts are settled, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that may ultimately be repaid, based on changes in forward natural gas prices during the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings.

Changes in fair value of NJNG's financial derivative instruments are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets, as NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff.

The Company elects normal purchase/normal sale (NPNS) accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, gains or (losses) are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered.

During fiscal 2012, NJRCEV began economically hedging certain of its expected production of solar renewable energy certificates (SRECs) through forward sale contracts. The Company intends to physically deliver the SRECs upon settlement and, therefore, applies NPNS accounting treatment to the contracts and recognizes related revenue upon transfer of the SRECs.

Fair Value Hierarchy

NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following:

Level 1 Unadjusted quoted prices for identical assets or liabilities in active markets; NJR's Level 1 assets and liabilities include exchange traded futures and options contracts, listed equities, and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX/Chicago Mercantile Exchange (CME) and ICE that NJR refers internally to as basis swaps, fixed swaps, futures and options that are cleared through a Futures Commission Merchant (FCM).

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. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input was considered to be a “model”, it would still be considered to be a Level 2 input as:

1)     The data is widely accepted and public

2)    The data is non-proprietary and sourced from an independent third party

3)    The data is observable and published

These additional adjustments are generally not considered to be significant to the ultimate recognized values.

Level 3 Inputs derived from a significant amount of unobservable market data; these include NJR's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

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Document and Entity Information	9 Months Ended
	Jun. 30, 2013	Aug. 05, 2013
Document Information [Line Items]
Entity Registrant Name	NEW JERSEY RESOURCES CORP
Entity Central Index Key	0000356309
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		41,380,558
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

9 Months Ended

Jun. 30, 2013

Accounting Policies [Abstract]

Schedule of Utility Inventory

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

	June 30, 2013				September 30, 2012
($ in thousands)	Gas in Storage			Bcf (1)	Gas in Storage			Bcf (1)
NJNG		$	63,900	12.3		$	145,379	22.2
NJRES		216,218		56.3		119,814		45.5
Total		$	280,118	68.6		$	265,193	67.7

(1) Billion cubic feet (Bcf).

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

(Thousands)	Unrealized gain on available for sale securities				Net unrealized gain on derivatives				Adjustment to postemployment benefit obligation				Total
Beginning balance as of January 1, 2013	$	4,601			$	41			$	(15,330	)		$	(10,688	)
Other comprehensive income, excluding reclassifications, net of tax of $(611), $(4), $-, $(615)	885				6				—				891
Amounts reclassified from accumulated other comprehensive income, net of tax of $155, $21 $(405), $(229)	(225		)	(1)	(40		)	(2)	592			(3)	327
Net current-period other comprehensive income, net of tax of $(456), $17, $(405), $(844)	660				(34		)		592				1,218
Ending balance as of June 30, 2013	$	5,261			$	7			$	(14,738	)		$	(9,470	)

(1) Reclassified to other income in the Unaudited Consolidated Statements of Operations.

(2) Reclassified to gas purchases in the Unaudited Consolidated Statements of Operations.

(3) Included in the computation of net periodic pension cost, a component of operations and maintenance expense in the Unaudited Consolidated Statements of Operations.