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 DECEMBER 31, 2015

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 February 1, 2016 was 85,923,516.

New Jersey Resources Corporation

TABLE OF CONTENTS

			Page
Glossary of Terms			1
Information Concerning Forward-Looking Statements			3
PART I. FINANCIAL INFORMATION
	ITEM 1.	Unaudited Condensed Consolidated Financial Statements	4
		Notes to Unaudited Condensed Consolidated Financial Statements	8
		Note 1. Nature of the Business	8
		Note 2. Summary of Significant Accounting Policies	8
		Note 3. Regulation	11
		Note 4. Derivative Instruments	13
		Note 5. Fair Value	18
		Note 6. Investments in Equity Investees	20
		Note 7. Earnings Per Share	20
		Note 8. Common Stock Equity	20
		Note 9. Debt	21
		Note 10. Employee Benefit Plans	22
		Note 11. Income Taxes	23
		Note 12. Commitments and Contingent Liabilities	23
		Note 13. Business Segment and Other Operations Data	25
		Note 14. Related Party Transactions	28
	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	28
	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	55
	ITEM 4.	Controls and Procedures	58
PART II. OTHER INFORMATION
	ITEM 1.	Legal Proceedings	59
	ITEM 1A.	Risk Factors	59
	ITEM 2.	Unregistered Sale of Equity Securities and Use of Proceeds	59
	ITEM 6.	Exhibits	60
		Signatures	61

GLOSSARY OF KEY TERMS                                                                                                                                                        

AFUDC	Allowance for Funds Used During Construction
AIP	Accelerated Infrastructure Program
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
Bcf	Billion Cubic Feet
BGSS	Basic Gas Supply Service
BPU	New Jersey Board of Public Utilities
CIP	Conservation Incentive Program
CME	Chicago Mercantile Exchange
CR&R	Commercial Realty & Resources Corp.
DM	Dominion Midstream Partners, L.P., a master limited partnership
DM Common Units	Common units representing limited partnership interests in DM
Dodd-Frank Act	Dodd-Frank Wall Street Reform and Consumer Protection Act
DRP	NJR Direct Stock Purchase and Dividend Reinvestment Plan
dths	Dekatherms
FASB	Financial Accounting Standards Board
FCM	Futures Commission Merchant
FERC	Federal Energy Regulatory Commission
Financial Margin	A non-GAAP financial measure, which represents revenues earned from the sale of natural gas less costs of natural gas sold including any transportation and storage costs, and excludes any accounting impact from the change in the fair value of certain derivative instruments
FMB	First Mortgage Bonds
FRM	Financial Risk Management
GAAP	Generally Accepted Accounting Principles of the United States
Home Services and Other	Home Services and Other Operations (formerly Retail and Other Operations)
ICE	Intercontinental Exchange
Iroquois	Iroquois Gas Transmission L.P.
ISDA	The International Swaps and Derivatives Association
ITC	Federal Investment Tax Credit
LNG	Liquefied Natural Gas
MetLife	Metropolitan Life Insurance Company
MetLife Facility	NJR's unsecured, uncommitted $100 million private placement shelf note agreement with MetLife, Inc. expiring in September 2016
MGP	Manufactured Gas Plant
Moody's	Moody's Investors Service, Inc.
Mortgage Indenture	The Amended and Restated Indenture of Mortgage, Deed of Trust and Security Agreement between NJNG and U.S. Bank National Association dated as of September 1, 2014
MW	Megawatts
MWh	Megawatt Hour
NAESB	The North American Energy Standards Board
NFE	Net Financial Earnings
NGV	Natural Gas Vehicles
NJ RISE	New Jersey Reinvestment in System Enhancement
NJCEP	New Jersey's Clean Energy Program
NJDEP	New Jersey Department of Environmental Protection
NJNG	New Jersey Natural Gas Company

1

GLOSSARY OF KEY TERMS (cont.)
NJNG Credit Facility	NJNG's $250 million unsecured committed credit facility expiring in May 2019
NJR Credit Facility	NJR's $425 million unsecured committed credit facility expiring in September 2020
NJR Energy	NJR Energy Corporation
NJR or The Company	New Jersey Resources Corporation
NJRCEV	NJR Clean Energy Ventures Corporation
NJRES	NJR Energy Services Company
NJRHS	NJR Home Services Company
Non-GAAP	Not in accordance with Generally Accepted Accounting Principles of the United States
NPNS	Normal Purchase/Normal Sale
NYMEX	New York Mercantile Exchange
O&M	Operation and Maintenance
OCI	Other Comprehensive Income
OPEB	Other Postemployment Benefit Plans
PennEast	PennEast Pipeline Company, LLC
PIM	Pipeline Integrity Management
PPA	Power Purchase Agreement
Prudential	Prudential Investment Management, Inc.
Prudential Facility	NJR's unsecured, uncommitted private placement shelf note agreement with Prudential
PTC	Federal Production Tax Credit
RA	Remediation Adjustment
Retail Holdings	NJR Retail Holdings Corporation
S&P	Standard & Poor's Financial Services, LLC
SAFE	Safety Acceleration and Facility Enhancement
Sarbanes-Oxley	Sarbanes-Oxley Act of 2002
SAVEGREEN	The SAVEGREEN Project®
SBC	Societal Benefits Charge
SREC	Solar Renewable Energy Certificate
SRL	Southern Reliability Link
Steckman Ridge	Collectively, Steckman Ridge GP, LLC and Steckman Ridge, LP
Superstorm Sandy	Post-Tropical Cyclone Sandy
Tetco	Texas Eastern Transmission
The Exchange Act	The Securities Exchange Act of 1934, as amended
Trustee	U.S. Bank National Association
U.S.	The United States of America
USF	Universal Service Fund

2

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 “anticipate,” “estimate,” “may,” “intend,” “expect,” “believe,” “will” “plan,” “should,” 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 on 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 ITCs, PTCs and SRECs, financial condition, results of operations, cash flows, capital requirements, future capital expenditures, market risk, effective tax rate and other matters for fiscal 2016 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 Annual Report on Form 10-K for the year ended September 30, 2015, as well as the following:

• weather and economic conditions;

• demographic changes in the 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 BGSS incentive programs, 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 on our access to capital;

• 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, revised actuarial assumptions or impacts associated with the Patient Protection and Affordable Care Act;

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

• commercial and wholesale credit risks, including the availability of creditworthy customers and counterparties, and liquidity in the wholesale energy trading market;

• regulatory approval of NJNG's planned infrastructure programs;

• the ability to obtain governmental and regulatory approvals, land-use rights, electric grid connection (in the case of distributed power projects) and/or financing for the construction, development and operation of NJR's unregulated energy investments and NJNG's infrastructure projects in a timely manner;

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

• risks associated with NJR's investments in distributed power projects, including the availability of regulatory and tax incentives, the availability of viable projects, NJR's eligibility for ITCs and PTCs, the future market for SRECs and operational risks related to projects in service;

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

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

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

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

• risks related to our employee workforce;

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

• the costs of compliance with 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 could adversely affect our operations, financial conditions and results of operations.

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.

3

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS                                                                                                                                          

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

	Three Months Ended
	December 31,
(Thousands, except per share data)	2015		2014
OPERATING REVENUES
Utility	$	151,606	$	208,727
Nonutility	292,652		615,397
Total operating revenues	444,258		824,124
OPERATING EXPENSES
Gas purchases:
Utility	46,665		84,263
Nonutility	254,088		472,971
Related parties	2,074		3,264
Operation and maintenance	46,233		44,759
Regulatory rider expenses	9,628		21,463
Depreciation and amortization	16,482		14,386
Energy and other taxes	9,637		14,321
Total operating expenses	384,807		655,427
OPERATING INCOME	59,451		168,697
Other income (expense), net	1,924		(110		)
Interest expense, net of capitalized interest	6,777		7,195
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	54,598		161,392
Income tax provision	8,357		40,867
Equity in earnings of affiliates	2,406		2,795
NET INCOME	$	48,647	$	123,320
EARNINGS PER COMMON SHARE
Basic	$.57		$1.46
Diluted	$.56		$1.44
DIVIDENDS DECLARED PER COMMON SHARE	$.24		$.225
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic	85,675		84,552
Diluted	86,676		85,574

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Net income	$	48,647		$	123,320
Other comprehensive income, net of tax
Unrealized gain on available for sale securities, net of tax of $(2,614) and $(455), respectively	3,701			659
Net unrealized (loss) on derivatives, net of tax of $19, and $18, respectively	(33		)	(31		)
Adjustment to postemployment benefit obligation, net of tax of $(174) and $(169), respectively	256			247
Other comprehensive income	3,924			875
Comprehensive income	$	52,571		$	124,195

See Notes to Unaudited Condensed Consolidated Financial Statements

4

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                      

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	Three Months Ended
	December 31,
(Thousands)	2015			2014
CASH FLOWS (USED IN) FROM OPERATING ACTIVITIES
Net income	$	48,647		$	123,320
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) on derivative instruments	(1,135		)	(88,673		)
Depreciation and amortization	16,482			14,386
Allowance for equity used during construction	(1,215		)	(1,253		)
Allowance for bad debt expense	334			964
Deferred income taxes	46,166			35,897
Manufactured gas plant remediation costs	(1,520		)	(1,008		)
Equity in earnings of equity investees, net of distributions received	1,139			2,146
Cost of removal - asset retirement obligations	(33		)	(105		)
Contributions to postemployment benefit plans	(30,144		)	(69		)
Changes in:
Components of working capital	(102,068		)	(75,089		)
Other noncurrent assets	(20,270		)	13,489
Other noncurrent liabilities	4,401			16,844
Cash flows (used in) from operating activities	(39,216		)	40,849
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Expenditures for:
Utility plant	(42,465		)	(34,114		)
Solar and wind equipment	(45,006		)	(55,345		)
Real estate properties and other	(797		)	(11		)
Cost of removal	(6,575		)	(2,634		)
Investments in equity investees	(2,846		)	(547		)
Other	2,304			445
Cash flows (used in) investing activities	(95,385		)	(92,206		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common stock	3,807			24,373
Tax benefit from stock options exercised	—			816
Proceeds from sale-leaseback transaction	7,107			7,216
Proceeds from long-term debt	—			100,000
Payments of long-term debt	(2,676		)	(1,723		)
Purchases of treasury stock	(1,008		)	(3,945		)
Payments of common stock dividends	(20,524		)	(18,993		)
Net proceeds from (payments of) short-term debt	144,650			(46,804		)
Cash flows from financing activities	131,356			60,940
Change in cash and cash equivalents	(3,245		)	9,583
Cash and cash equivalents at beginning of period	4,928			2,151
Cash and cash equivalents at end of period	$	1,683		$	11,734
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	(27,784	)	$	(166,229	)
Inventories	(26,772		)	8,385
Recovery of gas costs	(11,882		)	2,015
Gas purchases payable	(7,071		)	65,563
Gas purchases payable - related parties	(406		)	184
Prepaid and accrued taxes	(27,794		)	14,108
Accounts payable and other	(22,489		)	(53,852		)
Restricted broker margin accounts	6,855			46,550
Customers' credit balances and deposits	10,056			14,345
Other current assets	5,219			(6,158		)
Total	$	(102,068	)	$	(75,089	)
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for:
Interest (net of amounts capitalized)	$	5,403		$	1,376
Income taxes	$	202		$	2,228
Accrued capital expenditures	$	21,721		$	12,107

See Notes to Unaudited Condensed Consolidated Financial Statements

5

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                      

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

ASSETS

(Thousands)	December 31, 2015			September 30, 2015
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	1,937,686		$	1,908,024
Construction work in progress	161,686			155,553
Solar and wind equipment, real estate properties and other, at cost	569,820			481,003
Construction work in progress	35,253			77,705
Total property, plant and equipment	2,704,445			2,622,285
Accumulated depreciation and amortization, utility plant	(446,133		)	(437,097		)
Accumulated depreciation and amortization, solar and wind equipment, real estate properties and other	(62,213		)	(56,927		)
Property, plant and equipment, net	2,196,099			2,128,261
CURRENT ASSETS
Cash and cash equivalents	1,683			4,928
Customer accounts receivable
Billed	168,729			155,273
Unbilled revenues	19,883			6,372
Allowance for doubtful accounts	(4,706		)	(5,189		)
Regulatory assets	26,739			24,258
Gas in storage, at average cost	189,907			163,905
Materials and supplies, at average cost	7,908			7,138
Prepaid and accrued taxes	64,616			36,810
Derivatives, at fair value	58,978			40,743
Restricted broker margin accounts	21,334			12,990
Other	33,868			40,987
Total current assets	588,939			488,215
NONCURRENT ASSETS
Investments in equity investees	134,280			132,002
Regulatory assets	423,332			410,155
Derivatives, at fair value	3,741			4,334
Available for sale securities	65,790			59,475
Other	65,057			61,915
Total noncurrent assets	692,200			667,881
Total assets	$	3,477,238		$	3,284,357

See Notes to Unaudited Condensed Consolidated Financial Statements

6

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                      

CAPITALIZATION AND LIABILITIES

(Thousands)	December 31, 2015			September 30, 2015
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding December 31, 2015 — 85,809,094; September 30, 2015 — 85,531,423	$	221,555		$	220,838
Premium on common stock	213,351			209,931
Accumulated other comprehensive (loss), net of tax	(5,470		)	(9,394		)
Treasury stock at cost and other; shares December 31, 2015 — 2,812,896; September 30, 2015 — 2,804,847	(91,290		)	(92,164		)
Retained earnings	805,798			777,745
Common stock equity	1,143,944			1,106,956
Long-term debt	848,206			843,595
Total capitalization	1,992,150			1,950,551
CURRENT LIABILITIES
Current maturities of long-term debt	10,958			11,138
Short-term debt	211,000			66,350
Gas purchases payable	144,349			151,375
Gas purchases payable to related parties	1,150			1,601
Accounts payable and other	69,563			99,651
Dividends payable	20,594			20,528
Accrued taxes	1,338			1,326
Regulatory liabilities	1,091			12,154
New Jersey clean energy program	12,907			14,293
Derivatives, at fair value	51,879			32,791
Broker margin accounts	19,307			4,103
Customers' credit balances and deposits	30,846			20,790
Total current liabilities	574,982			436,100
NONCURRENT LIABILITIES
Deferred income taxes	491,522			444,935
Deferred investment tax credits	4,859			4,940
Deferred revenue	29,130			29,334
Derivatives, at fair value	2,606			5,529
Manufactured gas plant remediation	180,400			180,400
Postemployment employee benefit liability	108,432			137,414
Regulatory liabilities	63,311			67,533
Asset retirement obligation	20,960			19,145
Other	8,886			8,476
Total noncurrent liabilities	910,106			897,706
Commitments and contingent liabilities (Note 12)
Total capitalization and liabilities	$	3,477,238		$	3,284,357

See Notes to Unaudited Condensed Consolidated Financial Statements

7

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS                                              

1. NATURE OF THE BUSINESS

New Jersey Resources Corporation provides regulated gas distribution services and operates certain unregulated businesses primarily through the following subsidiaries:

New Jersey Natural Gas Company provides natural gas utility service to approximately 516,300 retail customers in central and northern New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment;

NJR Energy Services Company comprises the Energy Services segment that maintains and transacts around a portfolio of natural gas storage and transportation capacity contracts and provides physical wholesale energy and energy management services;

NJR Clean Energy Ventures Corporation, the Company's distributed power subsidiary, comprises the Clean Energy Ventures segment and consists of the Company's capital investments in distributed power projects, including commercial and residential solar projects and onshore wind investments;

NJR Midstream Holdings Corporation invests in energy-related ventures through its subsidiaries, NJR Steckman Ridge Storage Company, which holds the Company's 50 percent combined interest in Steckman Ridge, and NJR Pipeline Company, which holds the Company's 20 percent ownership interest in PennEast and1.84 million Common Units of Dominion Midstream Partners, L.P. The investments in Steckman Ridge, PennEast and DM comprise the Midstream segment; and

NJR Retail Holdings Corporation has two principal subsidiaries, NJR Home Services Company and Commercial Realty & Resources Corporation. Retail Holdings and NJR Energy Corporation are included in Home Services 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 Generally Accepted in the United States of America. The September 30, 2015, 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 2015 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, 2016. Intercompany transactions and accounts have been eliminated.

Gas in Storage

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

	December 31, 2015				September 30, 2015
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJRES		$	119,401	62.0		$	93,696	44.6
NJNG		70,506		23.0		70,209		21.4
Total		$	189,907	85.0		$	163,905	66.0

Sales Tax Accounting

Sales tax, that is collected from customers and presented in both operating revenues and operating expenses on the Unaudited Condensed Consolidated Statements of Operations, was $7.2 million and $11.8 million during the three months endedDecember 31, 2015 and 2014, respectively.

8

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Available for Sale Securities

Included in available for sale securities on the Unaudited Condensed Consolidated Balance Sheets are certain investments in two publicly traded energy companies. Total unrealized gains associated with these investments are included as a part of accumulated other comprehensive income, a component of common stock equity. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

The Company has equity securities that had a fair value of $9.4 million and $10.1 million as of December 31, 2015 and September 30, 2015, respectively. Total unrealized gains associated with these equity securities were $6.8 million, $4 million after tax, and $7.5 million, $4.4 million after tax, as of December 31, 2015 and September 30, 2015, respectively. The Company also has 1.84 million DM Common Units that had a fair value of $56.4 million and $49.4 million as of December 31, 2015 and September 30, 2015, respectively. Total unrealized gains associated with these units were $10.3 million, $6.1 million after tax, and $3.3 million, $1.9 million after tax, as of December 31, 2015 and September 30, 2015, respectively.

Common Stock Split

On January 20, 2015, NJR’s Board of Directors approved a 2 for 1 stock split of the Company’s common stock for the Company’s common stock holders of record on February 6, 2015. The additional shares were issued on March 3, 2015, resulting in an increase in average shares outstanding from approximately 42.7 million to approximately 85.4 million. All share-related information for prior periods has been adjusted throughout this report on a retroactive basis to reflect the effects of the stock split. As well, common stock and premium on common stock amounts have been adjusted as of the earliest period presented on the Unaudited Condensed Consolidated Balance Sheets.

Customer Accounts Receivable

Customer accounts receivable include outstanding billings from the following subsidiaries as of:

(Thousands)	December 31, 2015				September 30, 2015
NJRES	$	113,332	67	%	$	107,461	69	%
NJNG (1)	49,664		29		41,130		26
NJRCEV	1,471		1		1,084		1
NJRHS and other	4,262		3		5,598		4
Total	$	168,729	100	%	$	155,273	100	%

(1) Does not include unbilled revenues of $19.9 million and $6.4 million as of December 31, 2015 and September 30, 2015, respectively.

Loan Receivable

NJNG provides interest-free loans, with terms ranging from two to 10 years, to customers that elect to purchase and install certain energy efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at net present value on the Unaudited Condensed Consolidated Balance Sheets. The Company has recorded $7 million and $6.2 million in other current assets and $39.2 million and $36.2 million in other noncurrent assets as of December 31, 2015 and September 30, 2015, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans.

NJR's policy is to establish an allowance for doubtful accounts when loan balances are in arrears for more than 60 days. As of December 31, 2015 and September 30, 2015, there was no allowance for doubtful accounts established for the SAVEGREEN loans.

Recent Updates to the Accounting Standards Codification

Revenue

In May 2014, the FASB issued ASU No. 2014-09, and added Topic 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries,

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jurisdictions and capital markets. In August 2015, the FASB issued ASU No. 2015-14, which defers the implementation of the new guidance for one year. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Upon adoption, the guidance will be applied on a full or modified retrospective basis. The Company is currently evaluating the provisions of ASC 606 to understand the impact, if any, to its financial position, results of operations and cash flows upon adoption.

Stock Compensation

In June 2014, the FASB issued ASU No. 2014-12, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for performance awards when the terms of the award provide that a performance target could be achieved after the requisite service period. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. The Company does not expect this standard to have any impact to its financial position, results of operations and cash flows upon adoption.

Consolidation

In February 2015, the FASB issued ASU No. 2015-02, an amendment to ASC 810, Consolidation, which changes the consolidation analysis required under GAAP and reevaluates whether limited partnerships and similar entities must be consolidated. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendment will be applied on a full or modified retrospective basis. The Company is currently evaluating the provisions of ASU No. 2015-02 to understand the impact, if any, on its financial position, results of operations and cash flows upon adoption.

Interest

In April 2015, the FASB issued ASU No. 2015-03, an amendment to ASC 835, Interest - Imputation of Interest, which simplifies the presentation of debt issuance costs by requiring them to be presented in the balance sheet as a deduction from the carrying amount of the liability. The amendments do not affect the recognition and measurement guidance for debt issuance costs. In August 2015, the FASB issued ASU No. 2015-15, which clarified that the amendments contained within ASU No. 2015-03 do not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The amended guidance becomes effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendment will be applied on a retrospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations and cash flows upon adoption.

Intangibles

In April 2015, the FASB issued ASU No. 2015-05, an amendment to ASC 350, Intangibles - Goodwill and Other - Internal-Use Software, which clarifies the accounting for fees in a cloud computing arrangement. The amendments provide guidance on how an entity should evaluate the accounting for fees paid in a cloud computing arrangement to determine whether an arrangement includes the sale or license of software. The amended guidance becomes effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendments can be applied on a prospective or retrospective basis. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Inventory

In July 2015, the FASB issued ASU No. 2015-11, an amendment to ASC 330, Inventory, which requires entities to measure most inventory “at the lower of cost and net realizable value,” thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. The guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations and cash flows upon adoption.

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New Jersey Resources Corporation

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Income Taxes

In November 2015, the FASB issued ASU 2015-17, an amendment to ASC 740, Income Taxes, to simplify the balance sheet presentation of deferred income taxes. The update requires entities to present all deferred tax assets and liabilities as noncurrent. The Company elected to early adopt the amended guidance effective October 1, 2015, and applied the new provisions retrospectively. Accordingly, the following amounts on the Unaudited Condensed Consolidated Balance Sheets, as of September 30, 2015, have been adjusted:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Deferred taxes (current)	$	56,296	$	(56,296	)	$	—
Total current assets	$	544,511	$	(56,296	)	$	488,215
Other noncurrent assets	$	60,300	$	1,615		$	61,915
Total noncurrent assets	$	666,266	$	1,615		$	667,881
Total assets	$	3,339,038	$	(54,681	)	$	3,284,357
Capitalization and Liabilities
Deferred income taxes	$	499,616	$	(54,681	)	$	444,935
Total noncurrent liabilities	$	952,387	$	(54,681	)	$	897,706
Total capitalization and liabilities	$	3,339,038	$	(54,681	)	$	3,284,357

There was no additional impact to the Unaudited Condensed Consolidated Statements of Operations or the Unaudited Condensed Consolidated Statements of Cash Flows.

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. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.

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

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

(Thousands)	December 31, 2015		September 30, 2015
Regulatory assets-current
Conservation Incentive Program	$	819	$	—
New Jersey Clean Energy Program	12,907		14,293
Derivatives at fair value, net	13,013		9,965
Total current regulatory assets	$	26,739	$	24,258
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	17,963	$	18,886
Liability for future expenditures	180,400		180,400
Deferred income taxes	18,233		17,460
Derivatives at fair value, net	1,861		5,153
SAVEGREEN	27,968		26,882
Postemployment and other benefit costs	138,491		140,636
Deferred Superstorm Sandy costs	15,201		15,201
Conservation Incentive Program	17,552		—
Other noncurrent regulatory assets	5,663		5,537
Total noncurrent regulatory assets	$	423,332	$	410,155
Regulatory liability-current
Conservation Incentive Program	$	—	$	5,167
Overrecovered gas costs	1,091		6,987
Total current regulatory liabilities	$	1,091	$	12,154
Regulatory liabilities-noncurrent
Cost of removal obligation	$	48,683	$	54,880
New Jersey Clean Energy Program	14,512		11,956
Other noncurrent regulatory liabilities	116		697
Total noncurrent regulatory liabilities	$	63,311	$	67,533

Regulatory filings and/or actions that occurred during the current fiscal year include the following:

• On October 15, 2015, the BPU approved a base rate increase related to NJ RISE resulting in a .07 percent increase to the average residential heat customer's bill, effective November 1, 2015, to recover costs through July 31, 2015.

• On October 15, 2015, the BPU issued an order approving the continuation of the BGSS Incentive Programs with modification to the storage incentive program, beginning with the 2015 storage injection period, and termination of the FRM Program, effective November 1, 2015.

• On October 27, 2015, NJNG notified the BPU that the bill credits to residential and small commercial customers, which will be issued from November 2015 through February 2016, will be approximately $76 million and will result in an approximate 17 percent decrease to the average residential heat customer's bill.

• On November 13, 2015, NJNG filed a base rate petition with the BPU to increase its base tariff rates in the amount of $147.6 million.

• On December 24, 2015, NJNG filed an SBC petition with the BPU to increase the RA factor, to decrease the NJCEP factor and to request approval of its remediation expenses incurred through June 30, 2015, resulting in an overall decrease of .8 percent to the average residential heat customer's bill.

• On January 27, 2016, the BPU approved NJNG’s July 2015 petition to maintain its existing SAVEGREEN recovery rate.

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• On January 27, 2016, the BPU approved NJNG's proposed SRL pipeline installation, operation and route selection, as modified by NJNG, including specific requirements regarding permitting, safety and integrity assessment.

4. DERIVATIVE INSTRUMENTS

The Company is subject to commodity price risk due to fluctuations in the market price of natural gas, SRECs, and electricity. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs, and electricity. In addition, the Company may utilize foreign currency derivatives as cash flow hedges of Canadian dollar denominated gas purchases and/or sales. 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 NJR's derivative instruments, see Note 5. Fair Value.

Since NJRES chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, 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 U.S. dollar. NJRES may utilize 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 may be used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company designates these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in OCI. When the foreign exchange contracts are settled and the related purchases are recognized in income, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over 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. NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff for gas service.

The Company elects NPNS accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, physical purchases are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered. The average cost of natural gas is amortized in current period earnings based on the current BPU BGSS factor and therm sales.

NJRCEV hedges certain of its expected production of SRECs through forward and futures contracts. The contracts require the Company to physically deliver the SRECs upon settlement. The Company elects NPNS accounting treatment on all SREC forward and futures contracts it enters into during the period. NJRCEV recognizes the related revenue upon transfer of the SREC certificate to the counterparty.

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In an April 2014 BPU Order, NJNG received regulatory approval to enter into interest rate risk management transactions related to long-term debt securities. On June 1, 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with the forecasted $125 million debt issuance expected in May 2018. This forecasted debt issuance coincides with the maturity of NJNG's existing $125 million, 5.6 percent notes due May 15, 2018. The change in fair value of NJNG's treasury lock agreement is recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets since NJNG believes that the market value upon settlement will be reflected in future rates. Upon settlement, any gain or loss will be amortized in earnings over the life of the future debt issuance.

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
			December 31, 2015						September 30, 2015
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	—		$	52		$	—		$	—
Fair value of derivatives designated as hedging instruments			$	—		$	52		$	—		$	—
Derivatives not designated as hedging instruments:
NJNG:
Financial commodity contracts	Derivatives - current		$	820		$	13,819		$	207		$	10,163
	Derivatives - noncurrent		—			—			—			925
Interest rate contracts	Derivatives - noncurrent		$	—		$	1,861		$	—		$	4,228
NJRES:
Physical forward commodity contracts	Derivatives - current		$	9,844		$	22,333		$	4,854		$	9,281
	Derivatives - noncurrent		3,045			650			1,718			—
Financial commodity contracts	Derivatives - current		48,314			15,675			35,682			13,347
	Derivatives - noncurrent		696			95			2,626			386
Fair value of derivatives not designated as hedging instruments			$	62,719		$	54,433		$	45,087		$	38,330
Total fair value of derivatives			$	62,719		$	54,485		$	45,087		$	38,330

Offsetting of Derivatives

NJR transacts under master netting arrangements or equivalent agreements that allow it to offset derivative assets and liabilities with the same counterparty. However, NJR's policy is to present its derivative assets and liabilities on a gross basis on the Unaudited Condensed Consolidated Balance Sheets.

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The following table summarizes the reported gross amounts, the amounts that NJR has the right to offset but elects not to, financial collateral, as well as the net amounts NJR could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(Thousands)	Amounts Presented in Balance Sheets (1)			Offsetting Derivative Instruments (2)				Financial Collateral Received/Pledged (3)				Net Amounts (4)
As of December 31, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	12,889		$	(809	)		$	(1,000	)		$	11,080
Financial commodity contracts		49,010			(13,004		)		(25,136		)		10,870
Total NJRES		$	61,899		$	(13,813	)		$	(26,136	)		$	21,950
NJNG
Financial commodity contracts		$	820		$	(820	)		$	—			$	—
Total NJNG		820			(820		)		—				—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	22,983		$	(809	)		$	(1,200	)		$	20,974
Financial commodity contracts		15,770			(13,004		)		(2,766		)		—
Foreign currency contracts		52			—				—				52
Total NJRES		$	38,805		$	(13,813	)		$	(3,966	)		$	21,026
NJNG
Financial commodity contracts		$	13,819		$	(820	)		$	(12,999	)		$	—
Interest rate contracts		$	1,861		$	—			$	—			$	1,861
Total NJNG		$	15,680		$	(820	)		$	(12,999	)		$	1,861
As of September 30, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	6,562		$	(1,326	)		$	—			$	5,236
Financial commodity contracts		38,308			(13,734		)		3,841				28,415
Total NJRES		$	44,870		$	(15,060	)		$	3,841			$	33,651
NJNG
Financial commodity contracts		$	207		$	(207	)		$	—			$	—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	9,271		$	(1,326	)		$	(1,200	)		$	6,745
Financial commodity contracts		13,733			(13,733		)		—				—
Total NJRES		$	23,004		$	(15,059	)		$	(1,200	)		$	6,745
NJNG
Financial commodity contracts		$	11,088		$	(207	)		$	(10,881	)		$	—
Interest rate contracts		4,228			—				—				4,228
Total NJNG		$	15,316		$	(207	)		$	(10,881	)		$	4,228

(1) Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.

(2) Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.

(3) Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties.

(4) Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.

NJRES utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical gas for injection into storage and the subsequent sale of physical gas at a later date. The gains or (losses) on the financial transactions that are economic hedges of the cost of the purchased gas are recognized prior to the gains or (losses) on the physical transaction, which are recognized in earnings when the natural gas is sold. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments creates volatility in the results of NJRES, although the Company's intended economic results relating to the entire transaction are unaffected.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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
		December 31,
Derivatives not designated as hedging instruments:		2015			2014
NJRES:
Physical commodity contracts	Operating revenues	$	11,874		$	16,091
Physical commodity contracts	Gas purchases	(21,237		)	(19,856		)
Financial commodity contracts	Gas purchases	41,276			117,721
Total unrealized and realized gains		$	31,913		$	113,956

The table above does not include gains (losses) associated with NJNG's financial derivatives of $(5.6) million and $(19) million for the three months endedDecember 31, 2015 and 2014, respectively and the treasury rate lock of $2.4 million for the three months endedDecember 31, 2015. NJNG’s derivative contracts are part of the Company's risk management activities that relate to its natural gas purchases, BGSS incentive programs and debt financing. These transactions are entered into pursuant to regulatory guidance and at settlement the resulting gains and/or losses are payable to and/or recoverable from customers. Any changes in the value of NJNG's financial derivatives are deferred in regulatory assets or liabilities resulting in no impact to earnings.

NJRES previously designated 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 table reflects the effect of derivative instruments designated as cash flow hedges on OCI as of December 31:

(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)					Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Three Months Ended						Three Months Ended					Three Months Ended
	December 31,						December 31,					December 31,
Derivatives in cash flow hedging relationships:	2015			2014			2015		2014			2015		2014
Foreign currency contracts	$	(64	)	$	(24	)	$	12	$	(25	)	$	—	$	—

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

		Volume (Bcf)
		December 31, 2015		September 30, 2015
NJNG	Futures(1)	19.5		25.8
NJRES	Futures	(120.8	)	(91.1	)
	Options	5.8		1.2
	Physical	111.7		48.2

(1) Not included is the notional amount of $125 million related to NJNG’s treasury lock agreement.

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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 exchange requirements and a variable amount based on a daily mark-to-market. The Company maintains separate broker margin accounts for NJNG and NJRES. The balances by company, are as follows:

(Thousands)	Balance Sheet Location	December 31, 2015			September 30, 2015
NJNG	Broker margin - Current assets	$	17,487		$	12,990
NJRES	Broker margin - Current assets	$	3,847		$	—
	Broker margin - Current (liabilities)	$	(19,307	)	$	(4,103	)

Wholesale Credit Risk

NJNG and NJRES are exposed to credit risk as a result of their wholesale marketing activities. In addition, NJRCEV engages in sales of electricity, capacity and SRECs. As a result of the inherent volatility in the prices of natural gas commodities, derivatives and SRECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty failed to perform the obligations under its contract (e.g., failed to deliver or pay for natural gas or SRECs), then the Company could sustain a loss.

NJR monitors and manages the credit risk of its wholesale marketing operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of current and prospective counterparties' financial statements and/or credit ratings, daily monitoring of counterparties' credit limits and exposure, daily communication with traders regarding credit status and the use of credit mitigation measures, such as collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit. Collateral may be requested due to NJR's election not to extend credit or because exposure exceeds defined thresholds. Most of NJR's wholesale marketing contracts contain standard netting provisions. These contracts include those governed by ISDA and the NAESB. The netting provisions refer to payment netting, whereby receivables and payables with the same counterparty are offset and the resulting net amount is paid to the party to which it is due.

Internally-rated exposure applies to counterparties that are not rated by S&P or Moody's. In these cases, the Company's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by S&P and/or Moody's are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of December 31, 2015. 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 and NJRCEV residential solar installations.

(Thousands)	Gross Credit Exposure
Investment grade		$	99,405
Noninvestment grade		9,693
Internally rated investment grade		22,507
Internally rated noninvestment grade		7,815
Total		$	139,420

Conversely, certain of NJNG's and NJRES' derivative instruments are linked to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG's credit rating were to fall below its current level. NJNG's credit rating, with respect to S&P, reflects the overall corporate credit profile of NJR. Specifically, most, but not all, of these additional payments will be triggered if NJNG's debt is downgraded by the major credit agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings, but are based on certain financial metrics.

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Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company's credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on December 31, 2015 and September 30, 2015, was $1.9 million and $4.2 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on December 31, 2015 and September 30, 2015, the Company would have been required to post an additional $1.9 million and $4.2 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, as previously discussed.

5. FAIR VALUE

Fair Value of Assets and Liabilities

The fair value of cash and temporary investments, accounts receivable, current loan receivables, accounts payable, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. Non-current loan receivables are recorded based on what the Company expects to receive, which approximates fair value. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.

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

(Thousands)	December 31, 2015		September 30, 2015
Carrying value (1)	$	807,845	$	807,845
Fair market value	$	809,107	$	817,319

(1) Excludes capital leases of $51.3 million and $46.9 million as of December 31, 2015 and September 30, 2015, respectively.

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 December 31, 2015, NJR discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

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

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

Level 2 Other significant observable inputs such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG's treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. 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

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transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were 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 December 31, 2015:
Assets:
Physical forward commodity contracts		$	—		$	12,889		$	—	$	12,889
Financial derivative contracts - natural gas		49,830			—			—		49,830
Available for sale equity securities - energy industry(1)		65,790			—			—		65,790
Other (2)		1,809			—			—		1,809
Total assets at fair value		$	117,429		$	12,889		$	—	$	130,318
Liabilities:
Physical forward commodity contracts		$	—		$	22,983		$	—	$	22,983
Financial commodity contracts - natural gas		29,589			—			—		29,589
Financial commodity contracts - foreign exchange		—			52			—		52
Interest rate contracts		—			1,861			—		1,861
Total liabilities at fair value		$	29,589		$	24,896		$	—	$	54,485
As of September 30, 2015:
Assets:
Physical forward commodity contracts		$	—		$	6,572		$	—	$	6,572
Financial derivative contracts - natural gas		38,515			—			—		38,515
Available for sale equity securities - energy industry(1)		59,475			—			—		59,475
Other (2)		1,572			—			—		1,572
Total assets at fair value		$	99,562		$	6,572		$	—	$	106,134
Liabilities:
Physical forward commodity contracts		$	—		$	9,281		$	—	$	9,281
Financial commodity contracts - natural gas		24,821			—			—		24,821
Interest rate contracts		—			4,228			—		4,228
Total liabilities at fair value		$	24,821		$	13,509		$	—	$	38,330

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

(2) Includes various money market funds in Level 1.

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6. INVESTMENTS IN EQUITY INVESTEES

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

(Thousands)	December 31, 2015		September 30, 2015
Steckman Ridge (1)	$	125,058	$	125,649
PennEast	9,222		6,353
Total	$	134,280	$	132,002

(1) Includes loans with a total outstanding principal balance of $70.4 million for both December 31, 2015 and September 30, 2015. The loans accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

NJR, through a subsidiary, NJR Pipeline Company, formed PennEast with five other investors, and plans to construct and operate a 118-mile pipeline that will extend from northeast Pennsylvania to western New Jersey.

NJRES and NJNG have entered into storage and park and loan agreements with Steckman Ridge. In addition, NJNG has entered into a precedent capacity agreement with PennEast with an estimated service date of November 2017. See Note 14. Related Party Transactions for more information on these intercompany transactions.

7. EARNINGS PER SHARE

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

	Three Months Ended
	December 31,
(Thousands, except per share amounts)	2015		2014
Net income, as reported	$	48,647	$	123,320
Basic earnings per share
Weighted average shares of common stock outstanding-basic	85,675		84,552
Basic earnings per common share	$0.57		$1.46
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	85,675		84,552
Incremental shares (1)	1,001		1,022
Weighted average shares of common stock outstanding-diluted	86,676		85,574
Diluted earnings per common share (2)	$0.56		$1.44

(1) Incremental shares consist primarily of stock awards and performance shares.

(2) There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three months endedDecember 31, 2015, and 2014.

8. COMMON STOCK EQUITY

Changes in common stock equity during the three months endedDecember 31, 2015, are as follows:

(Thousands)	Number of Shares		Common Stock		Premium on Common Stock			Accumulated Other Comprehensive (Loss) Income				Treasury Stock And Other			Retained Earnings			Total
Balance at September 30, 2015	85,531		$	220,838	$	209,931			$	(9,394	)	$	(92,164	)	$	777,745		$	1,106,956
Net income															48,647			48,647
Other comprehensive income									3,924									3,924
Common stock issued:
Incentive plan	286		717		4,782													5,499
Dividend reinvestment plan	127				(1,339		)					5,144						3,805
Cash dividend declared ($.24 per share)															(20,594		)	(20,594		)
Treasury stock and other	(135	)			(23		)					(4,270		)				(4,293		)
Balance at December 31, 2015	85,809		$	221,555	$	213,351			$	(5,470	)	$	(91,290	)	$	805,798		$	1,143,944

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NJR satisfies its external common equity requirements, if any, through issuances of its common stock, including the proceeds from stock issuances under its DRP. The DRP allows NJR, at its option, to use treasury shares or newly issued shares to raise capital. On December 14, 2015, NJR registered 5 million shares of NJR common stock for issuance under the DRP. NJR raised $3.8 million of equity through the DRP for both the three months endedDecember 31, 2015 and 2014, by issuing approximately 127,000 and 148,000 shares, respectively. NJR also raised approximately $19.8 million of equity by issuing approximately 688,000 new shares through the waiver discount feature of the DRP during the three months endedDecember 31, 2014. NJR issued no new shares through the waiver discount feature of the DRP during the three months endedDecember 31, 2015. All fiscal 2015 share data has been adjusted for the March 2015 stock split.

Accumulated Other Comprehensive Income

The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects:

(Thousands)	Available for Sale Securities		Cash Flow Hedges				Postemployment Benefit Obligation				Total
Balance at September 30, 2015	$	6,385	$	—			$	(15,779	)		$	(9,394	)
Other comprehensive income, net of tax
Other comprehensive income (loss), before reclassifications, net of tax of ($2,614), $23, $0, ($2,591)	3,701		(41		)		—				3,660
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, ($4), ($174), ($178)	—		8			(1)	256			(2)	264
Net current-period other comprehensive income, net of tax of ($2,614), $19, $(174), $(2,769)	3,701		(33		)		256				3,924
Balance at December 31, 2015	$	10,086	$	(33	)		$	(15,523	)		$	(5,470	)
Balance at September 30, 2014	$	4,782	$	(93	)		$	(10,283	)		$	(5,594	)
Other comprehensive income (loss), net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(455), $9, $0, $(446)	659		(15		)		—				644
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $9, $(169), $(160)	—		(16		)	(1)	247			(2)	231
Net current-period other comprehensive income (loss), net of tax of $(455), $18, $(169), $(606)	659		(31		)		247				875
Balance at December 31, 2014	$	5,441	$	(124	)		$	(10,036	)		$	(4,719	)

(1) Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

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

9. DEBT

NJR and NJNG finance working capital requirements and capital expenditures through various short-term debt and long-term financing arrangements, including a commercial paper program, committed unsecured credit facilities and private placement debt shelf facilities.

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Credit Facilities

A summary of NJR's credit facility and NJNG's commercial paper program and credit facility are as follows:

(Thousands)	December 31, 2015			September 30, 2015			Expiration Dates
NJR
Bank revolving credit facilities(1)	$	425,000		$	425,000		September 2020
Notes outstanding at end of period	$	135,000		$	39,350
Weighted average interest rate at end of period	1.24		%	1.17		%
Amount available at end of period (2)	$	267,055		$	369,176
Bank revolving credit facilities(3)	$	—		$	100,000		October 2015
Amount available at end of period	$	—		$	100,000
NJNG
Bank revolving credit facilities (1)	$	250,000		$	250,000		May 2019
Commercial paper outstanding at end of period	$	76,000		$	27,000
Weighted average interest rate at end of period	.28		%	.20		%
Amount available at end of period (4)	$	173,269		$	222,269

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

(2) Letters of credit outstanding total $22.9 million and $16.5 million as of December 31, 2015 and September 30, 2015, respectively, which reduces amount available by the same amount.

(3) Uncommitted credit facilities, which require no commitment fees.

(4) Letters of credit outstanding total $731,000 and $731,000 as of December 31, 2015 and September 30, 2015, respectively, which reduces the amount available by the same amount.

On October 24, 2014, NJR entered into a $100 million uncommitted line of credit agreement, with Santander Bank, N.A., which expired on October 24, 2015.

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.

NJNG Long-term Debt

NJNG received $7.1 million and $7.2 million in December 2015 and 2014, 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.

10. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

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

	Pension						OPEB
	Three Months Ended						Three Months Ended
	December 31,						December 31,
(Thousands)	2015			2014			2015			2014
Service cost	$	1,898		$	1,871		$	1,130		$	1,063
Interest cost	2,836			2,550			1,564			1,435
Expected return on plan assets	(5,029		)	(4,272		)	(1,211		)	(1,244		)
Recognized actuarial loss	1,820			1,745			819			736
Prior service cost amortization	28			28			(91		)	(91		)
Net periodic benefit cost	$	1,553		$	1,922		$	2,211		$	1,899

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The Company made a discretionary contribution of $30 million during the three months endedDecember 31, 2015, to improve the funded status of the pension plans based on current actuarial assumptions, which includes the most recent mortality table change. The Company does not expect to be required to make additional contributions to fund the pension plans over the next two 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. There were no discretionary contributions made during the three months endedDecember 31, 2014.

11. 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 three months endedDecember 31, 2015 and 2014, based on its analysis, the Company determined there was no need to recognize any liabilities associated with uncertain tax positions.

To calculate the estimated annual effective tax rate, NJR considers tax credits associated with solar and wind projects. For investment tax credits the estimate is based on 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. For production tax credits the estimate is based on the forecast of electricity produced during the current fiscal year based on the best information available at each reporting period. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

The effective tax rates for the three months endedDecember 31, 2015 and 2014, were 14.7 percent and 24.9 percent, respectively. The decreased tax rate is due primarily to a decrease in forecasted pre-tax income for the fiscal year ended September 30, 2016, compared to the prior fiscal year. Forecasted tax credits, net of deferred taxes, are $26.8 million and $27.1 million for fiscal 2016 and 2015, respectively. Even though forecasted tax credits are lower in fiscal 2016, there is a greater impact to the effective tax rate due to the lower forecasted earnings.

As of December 31, 2015, the Company has total state income tax net operating losses of approximately $222.6 million, which generally have a life of 20 years. The Company has recorded a deferred state tax asset of approximately $13 million on the Unaudited Condensed Consolidated Balance Sheets, reflecting the tax benefit associated with the loss carryforwards. In addition, as of December 31, 2015, the Company has recorded a valuation allowance of $271,000 because it believes that it is more likely than not that the state net operating losses related to CR&R and NJR will expire unused. As of September 30, 2015, the Company had total state income tax net operating losses of approximately $218.1 million, a deferred state tax asset of approximately $12.8 million and a valuation allowance of $176,000.

In addition, as of September 30, 2015, the Company had an ITC carryforward of approximately $22.1 million, all of which was generated in fiscal year 2015, and has a life of 20 years. The Company expects to utilize this entire carryforward.

In December 2015, the Consolidated Appropriations Act extended the 30 percent ITC for solar property that is under construction on or before December 31, 2019. The credit will decline to 26 percent for property under construction as of and during 2020 and to 20 percent for property under construction as of and during 2021. For any property that is under construction before 2022, but not placed in service before 2024 the energy credit is reduced to 10 percent. In addition, the Consolidated Appropriations Act retroactively extends the PTC for five years through December 31, 2019, with a gradual three year phase out for any project for which construction of the facility begins after December 31, 2016.

12. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through October 2032, for the supply, storage and transportation of natural gas. These contracts include annual fixed charges of approximately $58.5 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 10 years. Demand charges are established by interstate storage and pipeline operators and are regulated by the FERC. These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and/or 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 December 31, 2015, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2016		2017		2018		2019		2020		Thereafter
NJRES:
Natural gas purchases	$	212,469	$	94,896	$	84,187	$	51,029	$	—	$	—
Storage demand fees	20,288		13,290		8,565		4,960		3,672		3,270
Pipeline demand fees	74,404		51,024		16,673		7,508		4,253		3,894
Sub-total NJRES	$	307,161	$	159,210	$	109,425	$	63,497	$	7,925	$	7,164
NJNG:
Natural gas purchases	$	41,962	$	63,953	$	39,885	$	40,976	$	43,775	$	98,948
Storage demand fees	21,815		25,328		15,871		11,079		5,345		—
Pipeline demand fees	36,684		67,858		93,474		90,226		89,459		783,107
Sub-total NJNG	$	100,461	$	157,139	$	149,230	$	142,281	$	138,579	$	882,055
Total(1)	$	407,622	$	316,349	$	258,655	$	205,778	$	146,504	$	889,219

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

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of five MGP sites, dating back to gas operations in the late 1800s and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the NJDEP, and 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 recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RA approved by the BPU. In September 2014, NJNG requested approval of its MGP expenditures incurred through June 2014 and to recover $8.5 million annually related to the SBC RA factor. The petition was approved by the BPU on May 19, 2015, with rates effective June 1, 2015. As of December 31, 2015, $18 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets.

NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent 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 $150.9 million to $242.1 million. NJNG's estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG's policy to accrue the lower end of the range. Accordingly, as of December 31, 2015, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $180.4 million on the Unaudited Condensed Consolidated Balance Sheets, based on the most likely amount. 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.

General

The Company is party to various other claims, legal actions and complaints arising in the ordinary course of business. In the Company's opinion, the ultimate disposition of these matters will not have a material effect on its financial condition, results of operations or cash flows.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

13. BUSINESS SEGMENT AND OTHER OPERATIONS DATA

NJR organizes its businesses based on a combination of factors including its products and its regulatory environment. As a result, the Company manages the businesses through the following reportable segments and other operations: the Natural Gas Distribution segment consists of regulated energy and off-system, capacity and storage management operations; the Energy Services segment consists of unregulated wholesale energy operations; the Clean Energy Ventures segment consists of capital investments in distributed power projects; the Midstream segment consists of NJR's investments in natural gas transportation and storage facilities; the Home Services and Other operations consist of heating, cooling and water appliance sales, installations 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
	December 31,
(Thousands)	2015			2014
Operating revenues
Natural Gas Distribution
External customers	$	151,606		$	208,727
Energy Services
External customers (1)	276,182			600,562
Intercompany	2,511			3,126
Clean Energy Ventures
External customers	7,794			6,235
Subtotal	438,093			818,650
Home Services and Other
External customers	8,676			8,600
Intercompany	897			411
Eliminations	(3,408		)	(3,537		)
Total	$	444,258		$	824,124
Depreciation and amortization
Natural Gas Distribution	$	11,238		$	10,545
Energy Services	23			22
Clean Energy Ventures	5,110			3,591
Midstream	1			2
Subtotal	16,372			14,160
Home Services and Other	227			238
Eliminations	(117		)	(12		)
Total	$	16,482		$	14,386
Interest income (2)
Natural Gas Distribution	$	68		$	90
Energy Services	72			—
Midstream	264			239
Subtotal	404			329
Home Services and Other	37			—
Eliminations	(371		)	(239		)
Total	$	70		$	90

(1) Includes sales to Canada, which accounted for 3.5 and 4.7 percent of total operating revenues during the three months endedDecember 31, 2015 and 2014.

(2) Included in other income, net on the Unaudited Condensed Consolidated Statements of Operations.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Interest expense, net of capitalized interest
Natural Gas Distribution	$	4,588		$	4,609
Energy Services	208			513
Clean Energy Ventures	2,053			1,817
Midstream	42			250
Subtotal	6,891			7,189
Home Services and Other	—			6
Eliminations	(114		)	—
Total	$	6,777		$	7,195
Income tax provision (benefit)
Natural Gas Distribution	$	13,863		$	14,166
Energy Services	5,195			45,877
Clean Energy Ventures	(11,587		)	(19,721		)
Midstream	1,640			1,492
Subtotal	9,111			41,814
Home Services and Other	(288		)	(452		)
Eliminations	(466		)	(495		)
Total	$	8,357		$	40,867
Equity in earnings of affiliates
Midstream	$	3,545		$	3,775
Eliminations	(1,139		)	(980		)
Total	$	2,406		$	2,795
Net financial earnings
Natural Gas Distribution	$	30,570		$	28,186
Energy Services	10,014			16,436
Clean Energy Ventures	7,505			9,008
Midstream	2,344			2,120
Subtotal	50,433			55,750
Home Services and Other	(583		)	(592		)
Eliminations	(218		)	(49		)
Total	$	49,632		$	55,109
Capital expenditures
Natural Gas Distribution	$	49,040		$	36,748
Clean Energy Ventures	45,006			55,345
Subtotal	94,046			92,093
Home Services and Other	797			11
Total	$	94,843		$	92,104
Investments in equity investees
Midstream	$	2,846		$	547
Total	$	2,846		$	547

26

New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Consolidated NFE	$	49,632		$	55,109
Less:
Unrealized (gain) on derivative instruments and related transactions	(1,135		)	(88,673		)
Effects of economic hedging related to natural gas inventory	3,813			(8,765		)
Tax adjustments	(1,693		)	29,227
Consolidated net income	$	48,647		$	123,320

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 when the gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical gas flows. Timing differences occur in two ways:

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

• Unrealized gains and losses of prior periods are reclassified as realized gains and losses when derivatives are settled in the same period as physical gas inventory movements occur.

NFE is a measure of the earnings based on eliminating these timing differences, to effectively match the earnings effects of the economic hedges with the physical sale of gas. Consequently, to reconcile between GAAP and NFE, current period unrealized gains and losses on the derivatives are excluded from NFE as a reconciling item. Additionally, realized derivative gains and losses are also included in current period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical gas flows. NJR also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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

(Thousands)	December 31, 2015			September 30, 2015
Assets at end of period:
Natural Gas Distribution	$	2,357,063		$	2,305,293
Energy Services	310,364			260,021
Clean Energy Ventures	597,897			504,885
Midstream	191,292			182,007
Subtotal	3,456,616			3,252,206
Home Services and Other	90,012			88,880
Intercompany assets(1)	(69,390		)	(56,729		)
Total	$	3,477,238		$	3,284,357

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

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

14. 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. As of December 31, 2015, NJRES has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which will expire by October 31, 2020. NJRES had demand fees, net of eliminations, associated with Steckman Ridge of $685,000 and $484,000 during the three months endedDecember 31, 2015 and 2014, respectively, and demand fees payable of $376,000 and $375,000 as of December 31, 2015 and September 30, 2015, respectively.

In January 2010, NJNG entered into a 10-year agreement effective April 1, 2010, for 3 Bcf of firm storage capacity with Steckman Ridge. Under the terms of the agreement, NJNG incurs demand fees, at market rates, of approximately $9.3 million annually, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG's BGSS mechanism and are included in regulatory assets. During the three months endedDecember 31, 2015 and 2014, NJNG had demand fees, net of eliminations, associated with Steckman Ridge of $1.4 million for both periods and demand fees payable of $774,900 as of December 31, 2015 and September 30, 2015.

NJNG and NJRES have entered into various asset management agreements. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to NJRES. NJNG retains the right to purchase market priced gas or fixed price storage gas from NJRES. As of December 31, 2015, NJNG and NJRES had four asset management agreements with expiration dates ranging from March 2016 through March 2018.

In the fourth quarter of fiscal 2014, NJNG entered into a 15 year transportation precedent agreement for committed capacity of 180,000 dths per day with PennEast with an estimated service date of November 2017.

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

OPERATIONS                                                                                                                                                                                   

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, 2015. NJR's critical accounting policies have not changed from those reported in the 2015 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.

Management's Overview

Consolidated

NJR 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 the U.S. and Canada, through its subsidiaries NJNG and NJRES. In addition, NJR invests in distributed power projects, midstream assets and provides various repair, sales and installations services. A more detailed description of NJR's organizational structure can be found in Item 1. Business of NJR's 2015 Annual Report on Form 10-K.

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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)

Business Segments

NJR has four primary business segments as presented in the chart below:

In addition to the four business segments, NJR has non-utility operations that either provide corporate support services or do not meet management's criteria to be treated as a separate business segment. These operations, which comprise Home Services and Other, include: appliance repair services, sales and installations at NJRHS; energy-related ventures at NJR Energy and commercial real estate holdings at CR&R.

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

	Three Months Ended
	December 31,
(Thousands)	2015					2014
Net Income (Loss)
Natural Gas Distribution	$	30,570		63	%	$	28,186		23	%
Energy Services	9,106			18		78,887			64
Clean Energy Ventures	8,226			17		15,607			12
Midstream	2,344			5		2,120			2
Home Services and Other	(583		)	(1	)	(592		)	—
Eliminations (1)	(1,016		)	(2	)	(888		)	(1	)
Total	$	48,647		100	%	$	123,320		100	%

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

The decrease in net income during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014 was primarily driven by:

• decreases at NJRES due primarily to lower gross margin related to a decrease of $87.6 million in unrealized gains on derivative instruments and related transactions as a result of timing differences in the settlement of certain economic hedges, partially offset by an increase of $12.6 million related to changes in the value of financial hedges; and

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

OPERATIONS (Continued)

• a decrease at CEV due primarily to a decrease in tax credits recognized due primarily to lower consolidated quarterly income along with increased costs related to depreciation and O&M, partially offset by higher operating revenues due to increased electricity sales; partially offset by

• an increase at NJNG due primarily to higher total utility gross margin of $2.7 million, partially offset by greater depreciation expense.

The primary drivers of the changes noted above are described in more detail in the individual segment discussions.

Assets by business segment and operations are as follows:

(Thousands)	December 31, 2015					September 30, 2015
Assets
Natural Gas Distribution	$	2,357,063		68	%	$	2,305,293		70	%
Energy Services	310,364			9		260,021			8
Clean Energy Ventures	597,897			17		504,885			15
Midstream	191,292			5		182,007			6
Home Services and Other	90,012			3		88,880			3
Intercompany assets(1)	(69,390		)	(2	)	(56,729		)	(2	)
Total	$	3,477,238		100	%	$	3,284,357		100	%

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

The increase in assets during the three months endedDecember 31, 2015, was due primarily to additional wind expenditures at NJRCEV, additional utility plant expenditures at NJNG, and increased gas in storage and accounts receivable at NJRES.

Management of the Company uses NFE, a non-GAAP financial measure, when evaluating the operating results of the Company. NJRES economically hedges its natural gas inventory with financial derivative instruments. NFE is a measure of the earnings based on eliminating timing differences surrounding the recognition of certain gains or losses, to effectively match the earnings effects of the economic hedges with the physical sale of gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments.

For NFE purposes, an annual estimated effective tax rate is calculated and any necessary quarterly tax adjustment is applied to NJRCEV, as such adjustment is primarily related to tax credits generated by NJRCEV.

Non-GAAP financial measures are not in accordance with, or an alternative to GAAP, and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.

The following is a reconciliation of consolidated net income, the most directly comparable GAAP measure, to NFE:

	Three Months Ended
	December 31,
($ in Thousands)	2015			2014
Net income	$	48,647		$	123,320
Add:
Consolidated unrealized (gain) on derivative instruments	(1,135		)	(88,673		)
Effects of economic hedging related to natural gas inventory	3,813			(8,765		)
Tax adjustments	(1,693		)	29,227
Net financial earnings	$	49,632		$	55,109

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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)

NFE by business segment and other operations, discussed in more detail within the operating results sections of each segment, is summarized as follows:

	Three Months Ended
	December 31,
($ in Thousands)	2015					2014
Net Financial Earnings (Loss)
Natural Gas Distribution	$	30,570		61	%	$	28,186		51	%
Energy Services	10,014			20		16,436			30
Clean Energy Ventures	7,505			15		9,008			16
Midstream	2,344			5		2,120			4
Home Services and Other	(583		)	(1	)	(592		)	(1	)
Eliminations(1)	(218		)	—		(49		)	—
Total	$	49,632		100	%	$	55,109		100	%

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

The decrease in NFE during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, was primarily driven by:

• a decrease at NJRES due primarily to lower financial margin of $10.1 million due primarily to the timing of certain transactions related to storage and narrower price spreads related to the decreased average gas prices due to the record warmth across the eastern U.S. and higher O&M, partially offset by a decrease in income taxes related to the financial margin; and

• a decrease at CEV due primarily to a decrease in tax credits recognized along with increased costs related to depreciation and O&M, partially offset by higher operating revenues, as previously discussed; partially offset by

• an increase at NJNG due primarily to higher total utility gross margin of $2.7 million, partially offset by greater depreciation expense.

Natural Gas Distribution Segment

Overview

Our Natural Gas Distribution segment is comprised of NJNG, a natural gas utility that provides regulated retail natural gas service in central and northern New Jersey to approximately 516,300 residential and commercial customers in its service territory and also participates in the off-system sales and capacity release markets. The business is subject to various risks, such as those associated with adverse economic conditions, which 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.

In addition, 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.

As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 3. Regulation in the accompanying Unaudited Condensed Consolidated Financial Statements for a more detailed discussion on regulatory actions, including filings related to programs and associated expenditures, as well as rate requests related to recovery of costs.

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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 operations are managed with the goal of providing safe and reliable service, growing its customer base, diversifying its gross margin, promoting clean energy programs and mitigating the risks discussed above, through several key initiatives including:

• earning a reasonable rate of return on the investments in its natural gas distribution and transmission businesses, as well as timely recovery of all prudently incurred costs in order to provide safe and reliable service throughout NJNG's territory:

-    NJNG filed a base rate case petition with the BPU on November 13, 2015 requesting an increase in base tariff rates in the amount of $147.6 million;

• continuing to invest in the safety and integrity of its infrastructure;

• managing its customer growth rate, which NJNG expects will be approximately 1.6 percent annually over the next two years;

• maintaining a collaborative relationship with the BPU on regulatory initiatives, including:

-    planning and authorization of infrastructure investments;

-    pursuing rate and regulatory strategies to stabilize and decouple margin, including CIP;

-    utilizing BGSS incentive programs through BPU-approved mechanisms to reduce gas costs and generate margin; and

-    administering and promoting NJNG's BPU-approved SAVEGREEN Project;

• managing the volatility of wholesale natural gas prices through a hedging program designed to keep customers' BGSS rates as stable as possible; and

• working to manage its financial obligations related to remediation activities associated with its former MGP sites.

Infrastructure projects

NJNG has significant annual capital expenditures associated with the management of its natural gas distribution and transmission system, including new utility plant associated with customer growth and its associated PIM and infrastructure programs.

Below is a summary of actual capital expenditures for the three months endedDecember 31, 2015, and estimates for fiscal 2016 and 2017:

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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)

Estimated capital expenditures are reviewed on a regular basis and may vary based on the ongoing effects of regulatory oversight, environmental regulations, unforeseen events and the ability to access capital.

SAFE and NJ RISE

NJNG has implemented BPU-approved infrastructure projects that are designed to enhance the reliability of NJNG's gas distribution system.

NJNG has implemented its SAFE program whereby NJNG has approval to invest up to $130 million, exclusive of AFUDC, to replace portions of its gas distribution infrastructure, consisting of unprotected steel and cast iron, over a four-year period. The SAFE program was authorized by the BPU to earn an overall weighted average cost of capital of 6.9 percent, with a return on equity of 9.75 percent. NJNG has included its SAFE infrastructure investments for recovery in its base rate case petition filed on November 13, 2015.

On July 23, 2014, the BPU approved a Stipulation of Settlement related to the recovery of NJNG's NJ RISE capital infrastructure program, which consists of six capital investment projects estimated to cost $102.5 million, excluding AFUDC, for gas distribution storm hardening and mitigation projects, along with associated depreciation expense. These system enhancements are intended to minimize service impacts during extreme weather events to customers that live in the most storm prone areas of NJNG's service territory. The submission was made in response to a March 2013 BPU order, initiating a proceeding to investigate prudent, cost efficient and effective opportunities to protect New Jersey's utility infrastructure from future major storm events. In the filing, NJNG proposed the recovery of its capital costs associated with NJ RISE through an annual adjustment to its base rate. On May 29, 2015, NJNG filed a petition with the BPU requesting approval to recover costs through July 31, 2015. On October 15, 2015, the BPU approved a base rate increase resulting in a .07 percent increase to the average residential heat customer's bill, effective November 1, 2015. Investments through July 31, 2015, will earn a weighted average cost of capital of 6.74 percent, including a return on equity of 9.75 percent. Estimated capital expenditures through December 31, 2016, have been included for recovery in NJNG’s base rate case petition filed with the BPU on November 13, 2015.

NGV Advantage

On June 18, 2012, the BPU approved a pilot program for NJNG to invest up to $10 million to build NGV refueling stations. As of December 31, 2015, NJNG has opened two NGV stations to the public and development of an additional NGV station continues in Middletown Township and is expected to be open to the public in February 2016. In addition, the BPU approved a deferred accounting methodology related to the NGV investment costs consistent with NJNG's SAFE Program. The NGV program was authorized by the BPU to earn an overall weighted average cost of capital of 7.1 percent, including a return on equity of 10.3 percent. A portion of the proceeds from the utilization of the compressed natural gas equipment, along with any available federal and state incentives, will be credited back to ratepayers to help offset the cost of this investment. NJNG has included its NGV investments for recovery in its base rate case petition filed with the BPU on November 13, 2015. Refer to Note 3. Regulation in the accompanying Unaudited Condensed Consolidated Financial Statements, for a discussion of SAFE deferred accounting methodology.

Liquefaction/LNG

NJNG is in the construction phase of its Liquefaction project, which when completed will allow NJNG to convert natural gas into LNG to fill NJNG's existing LNG storage tanks. NJNG's base rate case petition filed with the BPU on November 13, 2015, includes capital cost recovery for the project. NJNG estimates that the total costs for this project along with other plant upgrades will be $35.7 million.

Southern Reliability Link

The SRL is an approximate 30-mile, 30-inch transmission main designed to support improved system integrity and reliability in the southern portion of NJNG's service territory, estimated to cost between $175 million and $180 million. On April 2, 2015, NJNG filed two petitions with the BPU to construct, operate and finalize the route for its Southern Reliability Link project. On June 5, 2015, NJNG filed two petitions with the BPU to amend the previously proposed route. The capital investment cost associated with the SRL has been included for recovery in NJNG’s base rate case petition, filed with the BPU on November 13, 2015. On January 27, 2016, the BPU approved NJNG's proposed SRL pipeline installation, operation and route selection, as modified by NJNG, including specific requirements regarding permitting, safety and integrity assessment.

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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)

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 and business conditions.

During three months endedDecember 31, 2015 and 2014 respectively, NJNG added 2,046 and 2,581 new customers and converted 77 and 183 existing customers to natural gas heat and other services. The current customer growth represents an estimated increase of approximately $1.3 million annually to utility gross margin assuming normal weather and usage. In addition, NJNG currently expects to add approximately 16,000 to 18,000 new customers during the two-year period of fiscal 2016 and 2017. Based on information from municipalities and developers, as well as external industry analysts and management's experience, NJNG estimates that approximately 50 percent of the growth will come from new construction markets and another 50 percent from customer conversions to natural gas from other fuel sources. This new customer and conversion growth would increase utility gross margin under NJNG's base rates by approximately $4.4 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.

SAVEGREEN

SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives, that are designed to encourage the installation of high efficiency heating and cooling equipment and other energy efficiency upgrades. Depending on the specific incentive or approval, NJNG recovers costs associated with the programs over a two to 10-year period through a tariff rider mechanism. On July 22, 2015, the BPU approved NJNG's petition filed in December 2014, allowing the extension of SAVEGREEN through July 31, 2017, with an additional $75.2 million in investments and a weighted average cost of capital of 6.69 percent.

Since inception, the BPU has approved total SAVEGREEN investments of approximately $219.3 million, of which, $126.1 million in grants, rebates and loans has been provided to customers, with a total annual recovery of approximately $20 million. On January 27, 2016, the BPU approved NJNG’s July 2015 petition to maintain its existing SAVEGREEN recovery rate. The recovery includes a weighted average cost of capital that ranges from 6.69 percent, with a return on equity of 9.75 percent, to 7.76 percent, with a return on equity of 10.3 percent.

Conservation Incentive Program

The CIP facilitates normalizing NJNG's utility gross margin for variances not only due to weather but also for other factors affecting customer usage, such as conservation and energy efficiency. Recovery of utility gross margin for the non-weather variance through the CIP is limited to the amount of certain gas supply cost savings achieved and is subject to an annual earnings test. An annual review of the CIP must be filed by June 1, coincident with NJNG's annual BGSS filing, during which NJNG can request rate changes to the CIP. In May 2014, the BPU approved the continuation of the CIP program with no expiration date; however, it is subject to review in the 2017 tariff rate filing. On April 15, 2015, the BPU approved on a final basis a reduction to NJNG's CIP rates which were provisionally approved effective October 1, 2014, which resulted in a 4.3 percent reduction to the average residential heat customer's bill. On June 1, 2015, NJNG filed a petition with the BPU to increase its CIP rates resulting in a .08 percent increase to the average residential heat customer's bill to be effective October 1, 2015. The BPU provisionally approved this rate on September 11, 2015.

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

	Three Months Ended
	December 31,
(Thousands)	2015		2014
Weather (1)	$	18,162	$	2,254
Usage	4,292		3,224
Total	$	22,454	$	5,478

(1) Compared with the CIP 20-year average, weather was 33.6 percent and 2 percentwarmer-than-normal during the three months endedDecember 31, 2015 and 2014, respectively.

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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)

As of December 31, 2015, NJNG has $18.4 million in regulatory assets to be collected from customers in future periods on the Unaudited Condensed Consolidated Balance Sheets related to CIP. As of September 30, 2015, NJNG had $5.2 million in regulatory liabilities, on the Unaudited Condensed Consolidated Balance Sheets related to CIP to be returned to customers in future periods.

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, the price of natural gas charged to our customers through the BGSS clause, our 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 shown in the graph below for the three months endedDecember 31, 2015 and 2014, which illustrates the daily natural gas prices⁽¹⁾ in the Northeast market region, also known as Tetco M-3:

(1) Data source from Platts, a division of McGraw Hill Financial.

The maximum daily price at Tetco M-3 was $1.88 and $4.70 and the minimum daily price was $0.74 and $1.15 for the three months endedDecember 31, 2015 and 2014, respectively. A more detailed discussion of the impacts of the price of natural gas on 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

Recovery of natural gas costs

NJNG's cost of natural gas is passed through to our customers, without markup, by applying NJNG's authorized BGSS tariff rate to actual therms delivered. There is no utility gross margin associated with BGSS costs; therefore, changes in such costs do not impact NJNG's earnings. NJNG monitors its actual gas costs in comparison to its tariff rates to manage its cash flows associated with its allowed recovery of natural gas costs, which is facilitated through BPU-approved deferred accounting and the BGSS pricing mechanism. Accordingly, NJNG occasionally adjusts its periodic BGSS tariff rates or can issue credits or refunds, as appropriate, for its residential and small commercial customers when the commodity cost varies from the existing BGSS tariff rate. BGSS tariff rates for its large commercial customers are adjusted monthly based on NYMEX prices.

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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 October 1, 2014, NJNG implemented a decrease to its BGSS rate for residential sales and general service small sales customers resulting in a 5 percent decrease to the average residential heat customer's bill, which was approved by the BPU in April 2015. On June 1, 2015, NJNG filed a petition with the BPU to continue its existing BGSS rate for residential and small commercial customers, which was provisionally approved by the BPU on September 11, 2015. NJNG’s petition included a notification to provide estimated bill credits to NJNG's residential and small commercial customers during the months of November 2015 through February 2016, as a result of the decline in the wholesale price of natural gas. On October 27, 2015, NJNG notified the BPU that the estimated bill credits will be approximately $76 million and will result in an approximate 17 percent decrease to the average residential heat customer's bill. As of December 31, 2015, $19.6 million in bill credits have been issued. Refer to Note 3. Regulation in the accompanying Unaudited Condensed Consolidated Financial Statements, for a discussion of BGSS rate actions.

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 and storage incentive programs, and through October 31, 2015, the FRM program. These programs are designed to encourage better utilization and hedging of its natural gas supply, transportation and storage assets. Depending on the program, NJNG shares 80 or 85 percent of utility gross margin generated by these programs with firm customers. Should performance of the existing incentives or market conditions warrant, NJNG is permitted to propose a process to re-evaluate and discuss alternative incentive programs annually. On March 27, 2015, NJNG filed a letter petition with the BPU requesting the continuation of its existing BGSS Incentive Programs. On October 15, 2015, the BPU issued an order approving the continuation of the BGSS Incentive Programs with modification to the storage incentive program beginning with the 2015 storage injection period and termination of the FRM Program, effective November 1, 2015.

Utility gross margin from incentive programs was $4.5 million and $4.2 million during the three months endedDecember 31, 2015 and 2014, respectively. A more detailed discussion of the impacts to utility gross margin can be found in the Results of Operations sectionof Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Hedging

In order to provide relative price stability to its natural gas supply portfolio, NJNG employs a hedging strategy with the goal of having at least 75 percent of the Company's projected winter gas purchase volumes hedged by each November 1 and at least 25 percent of the gas purchase requirements hedged for the following April through March period. This is accomplished with the use of various financial instruments including futures, swaps and options used in conjunction with commodity and/or weather-related hedging activity.

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 impact NJNG's results. In an April 2014 BPU Order, NJNG received regulatory approval to enter into interest rate risk management transactions related to long-term debt securities. On June 1, 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with the forecasted $125 million debt issuance expected in May 2018. This forecasted debt issuance coincides with the maturity of NJNG's existing $125 million, 5.6 percent notes on May 15, 2018. The change in fair value of NJNG's treasury lock agreement is recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets since the Company believes that the market value upon settlement will be reflected in future rates. Upon settlement, any gain or loss will be amortized in earnings over the life of the future debt issuance.

A more detailed discussion of NJNG's debt 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.

Environmental Remediation

NJNG is responsible for the environmental remediation of five MGP sites, which contain contaminated residues from former gas manufacturing operations that ceased operating at these sites by the mid-1950s and, in some cases, had been discontinued many years earlier. Actual MGP remediation costs may vary from management's estimates due to the developing nature of remediation requirements, regulatory decisions by the NJDEP and related litigation. NJNG reviews these costs at the end of each fiscal year and adjusts its liability and corresponding regulatory asset as necessary to reflect its expected future remediation

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

OPERATIONS (Continued)

obligation. Accordingly, NJNG recognized a regulatory asset and an obligation of $180.4 million as of December 31, 2015, a increase of $3.4 million, compared with the prior fiscal year. NJNG is currently authorized to recover remediation costs of approximately $8.5 million annually, which is based on expenditures incurred through June 30, 2014. On December 24, 2015, NJNG filed an SBC petition with the BPU to increase the RA factor, to decrease the NJCEP factor and to request approval of its remediation expenses incurred through June 30, 2015, resulting in an overall decrease of .8 percent to the average residential heat customer's bill.

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 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.

Other regulatory filings and a more detailed discussion of the filings in this section can be found in Note 3. Regulation in the accompanying Unaudited Condensed Consolidated Financial Statements.

Operating Results

NJNG's operating results are as follows:

	Three Months Ended
	December 31,
(Thousands)	2015		2014
Utility gross margin
Operating revenues	$	151,606	$	208,727
Less:
Gas purchases (1)	45,243		88,568
Energy and other taxes	6,908		11,528
Regulatory rider expense	9,628		21,463
Total utility gross margin	89,827		87,168
Operation and maintenance	29,628		29,980
Depreciation and amortization	11,238		10,545
Other taxes not reflected in utility gross margin	1,254		1,079
Operating income	47,707		45,564
Other income, net	1,314		1,397
Interest expense, net of capitalized interest	4,588		4,609
Income tax provision	13,863		14,166
Net income	$	30,570	$	28,186

(1) Includes related party transactions of approximately $1.4 million and $1.6 million for the three months endedDecember 31, 2015 and 2014, respectively.

Operating Revenues and Gas Purchases

Operating revenues decreased by 27.4 percent and gas purchases decreased48.9 percent during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014.

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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 factors contributing to the (decreases) increases in operating revenues and gas purchases are as follows:

	Three Months Ended
	December 31,
	2015 v. 2014
(Millions)	Operating revenues			Gas purchases
Bill credits	$	(19.6	)	$	(18.3	)
Average BGSS rates (1)	(2.0		)	(1.9		)
Firm sales	(43.8		)	(18.8		)
Off-system sales	(4.0		)	(3.9		)
CIP adjustments	17.0			—
Other	(4.7		)	(0.4		)
Total decrease	$	(57.1	)	$	(43.3	)

(1) Operating revenues include changes in sales tax of $(1.4) million during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014.

The decrease in operating revenues and gas purchases during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, was due primarily to:

• decreased firm sales due primarily to lower usage related to weather being32 percentwarmerduring the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014;

• bill credits issued to residential and small commercial customers effective November 1, 2015;

• lower off-system sales due primarily to a 56.8 percentdecrease in the average price of gas sold, partially offset by a 95.7 percentincrease in volumes; partially offset by

• a increase in CIP adjustments of $15.9 millionrelated to weather and $1.1 millionrelated to usage.

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, 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 and regulatory rider expenses are included in operating revenue and passed through to customers and, therefore, have no effect on utility gross margin. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.

The following provides more information on the components of utility gross margin and associated throughput (Bcf) of natural gas delivered to customers:

	Three Months Ended
	December 31,
	2015			2014
($ in thousands)	Margin		Bcf	Margin		Bcf
Utility gross margin/throughput
Residential	$	55,076	8.9	$	52,844	12.4
Commercial, industrial and other	13,279		1.7	13,097		2.3
Firm transportation	15,547		3.4	16,197		4.6
Total utility firm gross margin/throughput	83,902		14.0	82,138		19.3
BGSS incentive programs	4,535		55.9	4,177		52.9
Interruptible/off-tariff agreements	1,390		16.0	853		4.1
Total utility gross margin/throughput	$	89,827	85.9	$	87,168	76.3

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OPERATIONS (Continued)

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.

The factors contributing to the increases in utility firm gross margin are as follows:

	Three Months Ended
	December 31,
(Thousands)	2015 v. 2014
Customer growth		$	1,448
SAVEGREEN		316
Total increase		$	1,764

The decrease in firm transportation margin is a result of customers returning to NJNG from third party natural gas providers in NJNG's distribution service territory. The transfer of residential and commercial customers has no net impact on NJNG's total utility firm gross margin because distribution tariff rates are the same for these customer classes.

NJNG's total customers include the following:

	December 31, 2015	December 31, 2014
Firm customers
Residential	441,464	428,088
Commercial, industrial & other	27,240	26,697
Residential transport	37,352	44,304
Commercial transport	10,184	10,408
Total firm customers	516,240	509,497
Other	62	76
Total customers	516,302	509,573

NJNG added 2,046 and 2,581 new customers and converted 77 and 183 existing customers to natural gas heat and other services during the three months endedDecember 31, 2015 and 2014, respectively. This customer growth represents an estimated annual increase of approximately .3 Bcf in sales to firm customers, assuming normal weather and usage, which would contribute approximately $1.3 million annually to utility gross margin.

BGSS Incentive Programs

The factors contributing to the increases (decreases) in utility gross margin generated by BGSS incentive programs are as follows:

	Three Months Ended
	December 31,
(Thousands)	2015 v. 2014
Storage		$	619
FRM		(202		)
Off-system sales		(56		)
Capacity release		(3		)
Total increase		$	358

The increase in the storage incentive program was due primarily to lower natural gas prices at injection points and the timing of storage injections. The FRM Program was terminated effective November 1, 2015.

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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)

Operation and Maintenance Expense

A summary and description of the factors contributing to the increases (decreases) in O&M expense is as follows:

	Three Months Ended
	December 31,
(Thousands)	2015 v. 2014
Shared corporate costs		$	733
Bad debt		(621		)
Consulting		(418		)
Compensation and benefits		(213		)
Maintenance and repairs		(53		)
Other		220
Total decrease		$	(352	)

The decrease in O&M expense was due primarily to lower health care expenses resulting from a change to a premium based health care plan, reduced pension expenses due to an increase in the expected return on assets in the pension plan related to the $30 million discretionary contribution made in November 2015, lower contractor and LNG costs due primarily to the timing of expenses, as well as reduced software maintenance and tax audit expenses. These decreases were partially offset by increased compensation costs.

Depreciation Expense

Depreciation expense increased$693,000 during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, as a result of additional utility plant being placed into service.

Operating Income

Operating income increased$2.1 million during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to the increase in total utility gross margin of $2.7 million and the decrease in O&M, partially offset by the increase in depreciation expense, as previously discussed.

Net Income

Net income increased$2.4 million, or 8.5 percent, to $30.6 million during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to the increased operating income, as previously discussed along with a decrease in the income tax provision due primarily to increased forecasted tax benefits related to AFUDC.

Energy Services Segment

Overview

NJRES is an unregulated wholesale provider of physical natural gas, producer and asset management services to a diverse customer base across North America. The market areas in which it operates includes the U.S. and Canada.

NJRES focuses on creating value from its physical natural gas assets and services, which are typically amassed through contractual rights to natural gas storage and transportation capacity within the regions that encompass its market area. Through the use of its capacity contracts, NJRES is able to take advantage of pricing differences between geographic locations, commonly referred to as “locational” or “basis” spreads, in addition to pricing differences over specific periods of time commonly referred to as “time spreads.” To monetize these differences, NJRES may enter into contracts that call for the future delivery and/or sale of physical natural gas and simultaneously enter into financial derivative contracts to establish an initial financial margin for each of its forecasted physical commodity transactions. Financial instruments are utilized to economically hedge natural gas inventory that will be sold at a future date, all of which were contemplated as part of an entire forecasted transaction. The financial derivative

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OPERATIONS (Continued)

contracts, primarily exchange-traded futures, options, and swap contracts, are used to lock in transactional cash flows and help manage volatility in commodity market prices. Typically, periods of increased market volatility provide NJRES with additional opportunistic revenue generating strategies that allow the Company to capture margin by improving the respective time or locational spreads on a forward basis.

Predominantly all of NJRES' physical purchases and sales of natural gas result in the physical delivery of natural gas. NJRES accounts for its physical commodity contracts and its financial derivative instruments at fair value on the Unaudited Condensed Consolidated Balance Sheets. Changes in the fair value of physical commodity contracts and financial derivative instruments are included in earnings as a component of operating revenue and/or gas purchases, and gas purchases respectively, on the Unaudited Condensed Consolidated Statements of Operations. Volatility in reported net income at NJRES can occur over periods of time due to changes in the fair value of derivatives, as well as timing differences related to certain transactions. Unrealized gains and losses can fluctuate as a result of changes in the price of natural gas from the original hedge price compared with the market price of natural gas at each reporting date. Volatility in earnings also occurs as a result of timing differences between the settlement of financial derivatives and the sale of the corresponding physical natural gas that was economically hedged. When a 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, at which time NJRES realizes the entire margin on the transaction.

Operating Results

NJRES' financial results are summarized as follows:

	Three Months Ended
	December 31,
(Thousands)	2015		2014
Operating revenues	$	278,693	$	603,688
Gas purchases (including demand charges (1))	260,239		474,947
Gross margin	18,454		128,741
Operation and maintenance	3,757		2,988
Depreciation and amortization	23		22
Other taxes	237		454
Operating income	14,437		125,277
Other income	72		—
Interest expense, net	208		513
Income tax provision	5,195		45,877
Net income	$	9,106	$	78,887

(1) Costs associated with pipeline and storage capacity that are expensed over the term of the related contracts, which generally varies from less than one year to ten years.

NJRES' portfolio of financial derivative instruments are composed of:

	Three Months Ended
	December 31,
(in Bcf)	2015	2014
Net short futures contracts	120.8	83.2
Net long options	5.8	1.2

Operating Revenues and Gas Purchases

Operating revenues decreased$325 million and gas purchases decreased$214.7 million during the three months endedDecember 31, 2015, due primarily to an approximate 43.3 percentdecrease in average gas prices as well as a 19.8 percentdecrease in sales volumes due to record warmth across the eastern U.S., compared with the three months endedDecember 31, 2014. Future results at NJRES are subject to volatility in the natural gas market due to weather. Variations in weather may affect earnings during the fiscal year. Demand and volatility in the natural gas market may decrease due to milder temperatures, which can negatively impact NJRES' earnings.

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

OPERATIONS (Continued)

Gross Margin

Gross margin was lower by approximately $110.3 million, during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to the decreases in operating revenues and gas purchases as described above. In addition, there was a decrease of $87.6 million in unrealized gains on derivative instruments and related transactions as a result of timing differences in the settlement of certain economic hedges, partially offset by an increase of $12.6 million related to changes in the value of financial hedges.

Operation and Maintenance Expense

O&M expense increased$769,000, or 25.7 percent, during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to increases in compensation partially offset by decreased software maintenance costs.

Net Income

Net income decreased$69.8 million during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to the lower gross margin and the increase in O&M expense discussed above, partially offset by decreased income tax expense related to the gross margin.

Non-GAAP Financial Measures

Management uses financial margin and NFE, non-GAAP financial measures, when evaluating the operating results of NJRES. Financial margin and NFE are measures of margin and earnings based on eliminating timing differences associated with certain derivative instruments, as discussed above. Management views these measures as more representative of the overall expected economic result and uses these measures to compare NJRES' results against established benchmarks and earnings targets as these measures eliminate the impact of volatility on GAAP earnings as a result of timing differences associated with these derivative instruments. 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. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.

When NJRES reconciles the most directly comparable GAAP measure to both financial margin and NFE, the current period unrealized gains and losses on the derivatives are excluded as a reconciling item. Financial margin and NFE also exclude the effects of economic hedging of the value of our natural gas in storage and, therefore, only include 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 the related physical gas flows.

Financial Margin

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

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Operating revenues	$	278,693		$	603,688
Less: Gas purchases	260,239			474,947
Add:
Unrealized (gain) on derivative instruments and related transactions (1)	(2,387		)	(90,000		)
Effects of economic hedging related to natural gas inventory	3,813			(8,765		)
Financial margin	$	19,880		$	29,976

(1) Includes unrealized (gains) related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $1.3 million for both thethree months endedDecember 31, 2015, and 2014.

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OPERATIONS (Continued)

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

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Operating income	$	14,437		$	125,277
Add:
Operation and maintenance	3,757			2,988
Depreciation and amortization	23			22
Other taxes	237			454
Subtotal - Gross margin	18,454			128,741
Add:
Unrealized (gain) on derivative instruments and related transactions	(2,387		)	(90,000		)
Effects of economic hedging related to natural gas inventory	3,813			(8,765		)
Financial margin	$	19,880		$	29,976

Financial margin decreased$10.1 million during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to the timing of certain transactions related to storage and narrower price spreads related to the decreased average gas prices discussed above resulting in lower financial margin from transportation and storage assets.

Net Financial Earnings

A reconciliation of NJRES' net (loss) income, the most directly comparable GAAP financial measurement to NFE is as follows:

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Net income	$	9,106		$	78,887
Add:
Unrealized (gain) on derivative instruments and related transactions	(2,387		)	(90,000		)
Effects of economic hedging related to natural gas inventory	3,813			(8,765		)
Tax adjustments	(518		)	36,314
Net financial earnings	$	10,014		$	16,436

NFE decreased$6.4 million during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to lower financial margin of $10.1 million and higher O&M, partially offset by lower taxes related to the financial margin, as previously discussed. Assuming a return to more normal weather patterns, the Company expects NJRES to generate a smaller portion of NJR's NFE in the future than in fiscal 2015.

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

Clean Energy Ventures Segment

Overview

Our Clean Energy Ventures segment actively pursues opportunities in the clean energy markets, including solar and onshore wind. Clean Energy Ventures has entered into various agreements to install solar net-metered systems for residential and commercial customers, as well as large commercial grid-connected projects. In addition, Clean Energy Ventures has entered into various long-term agreements, including PPAs, to supply energy from wind and solar projects.

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

OPERATIONS (Continued)

Solar

Since its inception, Clean Energy Ventures has placed a total of 118.4 MW of solar capacity into service and as of December 31, 2015, has 18.8 MW under construction. The Company estimates total solar-related capital expenditures for projects to be placed in service during fiscal 2016 to be between $75 million and $95 million. There were no commercial projects placed into service during the three months endedDecember 31, 2015. During the three months endedDecember 31, 2014, NJRCEV placed into service one commercial project totaling approximately 9.9 MW of solar capacity.

As part of its solar investment portfolio, NJRCEV operates a residential solar program, The Sunlight Advantage®, that provides qualifying homeowners the opportunity to have a solar system installed at their home with no installation or maintenance expenses. NJRCEV owns, operates and maintains the system over the life of the contract in exchange for monthly lease payments. NJRCEV's residential solar leasing program installed approximately .7 MW of capacity on 84 homes, and 1.4 MW of capacity on 145 homes during the three months endedDecember 31, 2015 and 2014, respectively.

Once a solar installation commences operations and is properly registered, each MWh of electricity produced creates an SREC that represents the renewable energy attribute of the solar-electricity generated that can be sold to third parties, including certain load-serving entities that are required to comply with the solar carve out of New Jersey's renewable portfolio standard. In addition, under the recently updated federal tax guidelines, projects that are placed in service through December 31, 2019, qualify for a 30 percent federal ITC.

SREC activity consisted of the following:

	Three Months Ended
	December 31,
	2015		2014
Beginning balance as of October 1,	33,203		29,970
SRECs generated	35,014		22,247
SRECs sold	(21,182	)	(24,994	)
Ending balance as of December 31,	47,035		27,223

NJRCEV hedges a portion of its expected SREC production through the use of forward sales contracts. As of December 31, 2015, NJRCEV has hedged approximately 92 percent and 100 percent of its SREC inventory and projected SREC production related to its in-service commercial and residential assets for energy years 2016 and 2017, respectively. Energy years are compliance periods for New Jersey's renewable portfolio standard that run from June 1 to May 31.

Onshore Wind

Clean Energy Ventures invests in small to mid-size onshore wind projects that fit its investment profile, including the following as of December 31, 2015:

• a $20.3 million, 9.7 MW project in Two Dot, Montana that was completed in June 2014;

• a $42.1 million, 20 MW project in Carroll County, Iowa that was completed in January 2015;

• an $84.5 million, 50.7 MW project in Rush County, Kansas that was completed in December 2015; and

• an $84 million, 39.9 MW project in Somerset County, Pennsylvania that is currently under construction and which is expected to be completed in the first quarter of fiscal 2017.

The wind projects are eligible for PTCs for a 10-year period following commencement of operation and have power purchase agreements of various terms in place, which govern the sale of energy, capacity and renewable energy credits.

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OPERATIONS (Continued)

Clean Energy Ventures' investments are subject to a variety of factors, such as timing of construction schedules, permitting and regulatory processes, delays related to electric grid interconnection, which can affect our ability to commence operations on a timely basis or, at all, economic trends, the ability to access capital or allocation of capital to other investments or business opportunities and other unforeseen events. Solar projects not placed in service, as originally planned prior to the end of a reporting period, may result in a failure to qualify for ITCs and along with changes in SREC prices could have a significant adverse impact on that period's earnings. Wind projects for which construction of the facility begins after December 31, 2016 through December 31, 2019, will be subject to reduced PTCs, and could have a significant adverse impact on 10 years of forward earnings. In addition, since the primary contributors toward the value of qualifying power projects are tax incentives and SRECs, changes in the federal statutes related to the ITC or PTC or in the marketplace and/or relevant legislation surrounding renewable energy credits, could also significantly affect earnings.

Operating Results

The financial results of NJRCEV are summarized as follows:

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Operating revenues	$	7,794		$	6,235
Operation and maintenance	3,857			3,133
Depreciation and amortization	5,110			3,591
Other taxes	253			214
Operating (loss)	(1,426		)	(703		)
Other income (expense), net	118			(1,594		)
Interest expense, net	2,053			1,817
Income tax (benefit)	(11,587		)	(19,721		)
Net Income	$	8,226		$	15,607

Operating Revenues

Operating revenues consist of the following:

The average SREC sales price was $217 and $176 during the three months endedDecember 31, 2015, and 2014, respectively.

There are no direct production costs associated with the revenue generation by our solar assets. All related costs are included as a component of O&M expenses on the Unaudited Condensed Consolidated Statements of Operations, including such expenses as facility maintenance and various fees.

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OPERATIONS (Continued)

Operation and Maintenance Expense

O&M expense increased$724,000 during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to additional leasing and maintenance costs associated with wind and solar projects placed in service and higher shared services costs due primarily to increased compensation costs.

Depreciation Expense

Depreciation expense increased $1.5 million during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, as a result of increases in solar and wind capital additions.

Income Tax (Benefit)

NJR’s effective tax rate is significantly impacted by the amount of tax credits forecast to be earned during the fiscal year. GAAP requires NJR to estimate its annual effective tax rate and use this rate to calculate its year-to-date tax provision. Based on NJRCEV’s forecast of solar projects to be completed and wind production during the fiscal year, NJR’s estimated annual effective tax rate for fiscal 2016 is 14.7 percent and $10.1 million related to tax credits, net of deferred taxes, were recognized during the three months endedDecember 31, 2015. The effective annual effective tax rate as of December 31, 2014, was 24.9 percent and $18 million related to tax credits, net of deferred taxes, were recognized during the three months endedDecember 31, 2014.

Net Income

Net income decreased$7.4 million, during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to:

• a decrease in tax credits recognized due primarily to NJR's lower estimated annual effective tax rate and lower consolidated quarterly income; and

• increased costs related to depreciation and O&M as discussed above; partially offset by

• an increase in operating revenues as discussed above; and

• an increase in PTCs due to increased wind production as a result of more MW in service.

Non-GAAP Financial Measures

Management of the Company uses NFE, a non-GAAP financial measure, when evaluating the operating results of Clean Energy Ventures. For NFE purposes an annual estimated effective tax rate is calculated and any necessary quarterly tax adjustment is applied to NJRCEV, as such adjustment is primarily related to tax credits generated by NJRCEV. Accordingly, for NFE purposes, the effective tax rate for fiscal 2016 is estimated at 16.4 percent and $9.6 million of tax credits, net of deferred taxes, were recognized during the three months endedDecember 31, 2015.

During the three months endedDecember 31, 2014, the effective tax rate for fiscal 2015 was estimated at 17.4 percent and $11.4 million of tax credits, net of deferred taxes, were recognized during the three months endedDecember 31, 2014, respectively. Since the effective tax rate is based on certain forecasted assumptions, including estimates surrounding completion of projects, the rate and resulting NFE are subject to change. Non-GAAP financial measures are not in accordance with, or an alternative to GAAP, and should be considered in addition to, and not as a substitute for the comparable GAAP measure.

A reconciliation of NJRCEV's net income, the most directly comparable GAAP financial measurement to NFE is as follows:

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Net income	$	8,226		$	15,607
Add:
Tax adjustments	(721		)	(6,599		)
Net financial earnings	$	7,505		$	9,008

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

OPERATIONS (Continued)

Midstream Segment

Overview

Our Midstream segment invests in natural gas assets, such as natural gas transportation and storage facilities. NJR believes that acquiring, owning and developing these midstream assets, which operate under a tariff structure that has either regulated or market-based rates, can provide a growth opportunity for the Company. To that end, NJR has a 50 percent ownership interest in Steckman Ridge, a storage facility that operates under market-based rates and a 20 percent ownership interest in PennEast, a natural gas pipeline, which the Company estimates will be completed and operational in fiscal 2018. As of December 31, 2015, NJR's net investments in Steckman Ridge and PennEast were $125.1 million and $9.2 million, respectively.

During fiscal 2015, NJR Midstream Holdings Corporation, through its subsidiary, NJNR Pipeline Company, also held the Company's 5.53 percent ownership interest in Iroquois Gas Transmission L.P. On September 29, 2015, NJNR Pipeline Company exchanged its ownership interest in Iroquois with Dominion Midstream Partners, L.P. for 1.84 million DM Common Units.

Operating Results

The financial results of Midstream are summarized as follows:

	Three Months Ended
	December 31,
(Thousands)	2015		2014
Equity in earnings of affiliates	$	3,545	$	3,775
Operation and maintenance	$	148	$	147
Other income	$	632	$	239
Interest expense, net	$	42	$	250
Income tax provision	$	1,640	$	1,492
Net income	$	2,344	$	2,120

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

	Three Months Ended
	December 31,
(Thousands)	2015		2014
Steckman Ridge	$	3,545	$	2,729
Iroquois	—		1,046
Total equity in earnings	$	3,545	$	3,775

Equity in earnings of affiliates decreased$230,000 during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, due primarily to the exchange of NJR's ownership interest in Iroquois, partially offset by increases in storage service revenue and demand for hub services at Steckman Ridge.

Other income increased due to dividend income from the new DM Common Units for the three months endedDecember 31, 2015, compared with three months endedDecember 31, 2014.

Home Services and Other Operations

Overview

The financial results of Home Services and Other consist primarily of the operating results of NJRHS, CR&R, and NJR Energy. NJRHS provides service, sales and installation of appliances to approximately 116,000 service contract 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 building and undeveloped land. NJR Energy invests in other energy-related ventures. Home Services and Other also includes organizational expenses incurred at NJR.

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OPERATIONS (Continued)

Operating Results

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

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Operating revenues	$	9,573		$	9,011
Operation and maintenance	$	9,393		$	8,855
Energy and other taxes	$	983		$	1,043
Income tax (benefit)	$	(288	)	$	(452	)
Net (loss)	$	(583	)	$	(592	)

Operating revenue increased$562,000 during the three months endedDecember 31, 2015, compared with the three months ended December 31, 2014, due primarily to increased solar installations, as well as increased contract revenue at NJRHS as a result of existing customers upgrading to the total comfort and platinum comfort plans and expanded service contract product line, partially offset by a decrease in generator sales and installations.

O&M expense increased$538,000 during the three months endedDecember 31, 2015, compared with the three months ended December 31, 2014, due primarily to increased labor resulting from increased complement and the timing of incentives and as well as increased consulting fees and additional temporary help.

Energy & other taxes remained relatively flat during the three months endedDecember 31, 2015, compared with the three months ended December 31, 2014.

Income tax benefit decreased $164,000 during the three months endedDecember 31, 2015, compared with the three months ended December 31, 2014, due primarily to increased operating income at NJRHS related to the increased revenues discussed above.

Net loss remained relatively flat during the three months endedDecember 31, 2015, compared with the three months ended December 31, 2014.

Liquidity and Capital Resources

NJR's objective is to maintain an efficient consolidated capital structure that reflects 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:

	December 31, 2015		September 30, 2015
Common stock equity	52	%	54	%
Long-term debt	38		42
Short-term debt	10		4
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 DRP. The DRP allows NJR, at its option, to use treasury shares or newly issued shares to raise capital. On December 14, 2015, NJR registered an additional 5 million shares of NJR common stock for issuance under the DRP. NJR raised $3.8 million of equity through the DRP for both the three months endedDecember 31, 2015 and 2014, by issuing approximately 127,000 and 148,000 shares, respectively. NJR also raised approximately $19.8 million of equity by issuing approximately 688,000 new shares through the waiver discount feature of the DRP during the three months ended2014. NJR issued no new shares through the waiver discount feature of the DRP during the three months endedDecember 31, 2015. All fiscal 2015 share data has been adjusted for the March 2015 stock split.

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

OPERATIONS (Continued)

In 1996, the Board of Directors authorized the Company to implement a share repurchase program, which was expanded seven times since the inception of the program. As of December 31, 2015, the Company has repurchased a total of approximately 16.9 million of those shares and may repurchase an additional 2.6 million shares under the approved program. There were 34,700 and 54,200 shares repurchased during the three months endedDecember 31, 2015 and 2014, respectively.

Debt

NJR and its unregulated subsidiaries generally rely on cash flows generated from operating activities and the utilization of committed credit facilities to provide liquidity to meet working capital and short-term debt financing requirements. NJNG also relies on the issuance of commercial paper for short-term funding. NJR and NJNG periodically access the capital markets to fund long-life assets through the issuance of long-term debt securities.

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 next 12 months. NJR, NJNG, NJRCEV and NJRES currently anticipate that each of their financing requirements for the next 12 months will be met primarily through the issuance of short and long-term debt, meter sale-leasebacks and proceeds from the Company's DRP.

NJR believes that as of December 31, 2015, NJR and NJNG were, and currently are, in compliance with all existing debt covenants, both financial and non-financial.

Short-Term Debt

NJR uses its short-term borrowings primarily to finance its share repurchases, NJRES' short-term liquidity needs and, on an initial basis, NJRCEV's investments and our Midstream segment's PennEast contributions. NJRES' use of high volume 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.

As of December 31, 2015, NJR had a revolving credit facility totaling $425 million, as described below, with $267.1 million available under the facility.

NJNG satisfies its debt needs by issuing short- and long-term debt based on its 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, based on its financial profile, through the issuance of commercial paper supported by the NJNG Credit Facility or through short-term bank loans under the NJNG Credit Facility.

NJNG’s commercial paper is sold through several commercial banks under an issuing and paying agency agreement and is supported by the $250 million NJNG Credit Facility. As of December 31, 2015, the unused amount available under the NJNG Credit Facility, including amounts allocated to the backstop under the commercial paper program and the issuance of letters of credit, was $173.3 million.

Due to the seasonal nature of natural gas prices and demand and because inventory levels are built up during its natural gas injection season (April through October), NJR and NJNG's short-term borrowings tend to peak towards the end of the injection season.

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

OPERATIONS (Continued)

Short-term borrowings were as follows:

	Three Months Ended
(Thousands)	December 31, 2015
NJR
Notes Payable to banks:
Balance at end of period		$	135,000
Weighted average interest rate at end of period		1.24		%
Average balance for the period		$	76,903
Weighted average interest rate for average balance		1.16		%
Month end maximum for the period		$	135,000
NJNG
Commercial Paper and Notes Payable to banks:
Balance at end of period		$	76,000
Weighted average interest rate at end of period		0.28		%
Average balance for the period		$	74,183
Weighted average interest rate for average balance		0.22		%
Month end maximum for the period		$	96,000

NJR

As noted above, based on its average borrowings during the three months endedDecember 31, 2015, NJR's average interest rate was 1.16 percent, resulting in interest expense of $228,000.

As of December 31, 2015, NJR has five letters of credit outstanding totaling $22.9 million, which reduces the amount available under the NJR Credit Facility by the same amount. NJR does not anticipate that these letters of credit will be drawn upon by the counterparties.

NJR's $100 million uncommitted Line of Credit Agreement with Santander Bank, N.A. expired on October 24, 2015, and was not renewed.

Neither NJNG nor its assets are obligated or pledged to support the NJR credit facility.

NJNG

As noted above, NJNG's weighted average interest rate on outstanding commercial paper was .22 percent during the three months endedDecember 31, 2015, resulting in interest expense of $43,700.

As of December 31, 2015, NJNG has two letters of credit outstanding for $731,000, which reduces the amount available under NJNG's committed credit facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by the counterparties.

Short-Term Debt Covenants

Borrowings under the NJR Credit Facility and NJNG Credit Facility are conditioned upon compliance with a maximum leverage ratio (consolidated total indebtedness to consolidated total capitalization as defined in the applicable agreements), of not more than .65 to 1.00 at any time. These revolving credit facilities contain customary representations and warranties for transactions of this type. They also contain customary events of default and certain covenants that will limit NJR's or NJNG's ability, beyond agreed upon thresholds, to, among other things:

•incur additional debt;

•incur liens and encumbrances;

•make dispositions of assets;

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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)

•enter into transactions with affiliates; and

•merge, consolidate, transfer, sell or lease all or substantially all of the borrower's or guarantors' assets.

These covenants are subject to a number of exceptions and qualifications set forth in the applicable agreements.

Default Provisions

The agreements governing our long-term and short-term debt obligations include provisions that, if not complied with, could require early payment or similar actions. Default events include, but are not limited to, the following:

•defaults for non-payment;

•defaults for breach of representations and warranties;

•defaults for insolvency;

•defaults for non-performance of covenants;

•cross-defaults to other debt obligations of the borrower; and

•guarantor defaults.

The occurrence of an event of default under these agreements could result in all loans and other obligations of the borrower becoming immediately due and payable and the termination of the credit facilities or term loan.

Long-Term Debt

NJR

NJR has outstanding $50 million of 6.05 percent senior unsecured notes due September 2017, $25 million of 2.51 percent senior notes due September 2018, $50 million of 3.25 percent senior notes due September 2022 and $100 million of 3.48 percent senior notes due November 2024, which were issued under private placement debt shelf facilities. NJR has an unsecured, uncommitted $100 million private placement shelf note agreement that expires September 26, 2016. As of December 31, 2015, $100 million remains available for borrowing on that shelf facility.

Neither NJNG nor its assets are obligated or pledged to support NJR's long-term debt.

NJNG

As of December 31, 2015, NJNG's long-term debt consisted of $485.8 million in fixed-rate debt issuances secured by the Mortgage Indenture, with maturities ranging from 2018 to 2045, $97 million in secured variable rate debt with maturities ranging from 2027 to 2041 and $40.4 million in capital leases with various maturities ranging from 2016 to 2022.

NJR is not obligated directly or contingently with respect to the NJNG notes or the FMB.

Long-Term Debt Covenants and Default Provisions

The NJR and NJNG long-term debt instruments contain customary representations and warranties for transaction of their type. They also contain customary events of default and certain covenants that will limit NJR or NJNG's ability beyond agreed upon thresholds to, among other things:

•incur additional debt (including a covenant that limits the amount of consolidated total debt of the borrower at the end of a fiscal quarter to 65 percent of the consolidated total capitalization of the borrower, as those terms are defined in the applicable agreements, and a covenant limiting priority debt to 20 percent of the borrower's consolidated total capitalization, as those terms are defined in the applicable agreements);

•incur liens and encumbrances;

•make loans and investments;

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

OPERATIONS (Continued)

•make dispositions of assets;

•make dividends or restricted payments;

•enter into transactions with affiliates; and

•merge, consolidate, transfer, sell or lease substantially all of the borrower's assets.

The aforementioned covenants are subject to a number of exceptions and qualifications set forth in the applicable note purchase agreements.

In addition, the FMB issued by NJNG under the Mortgage Indenture are subject to certain default provisions. Events of Default, as defined in the Mortgage Indenture, consist mainly of:

•failure for 30 days to pay interest when due;

•failure to pay principal or premium when due and payable;

•failure to make sinking fund payments when due;

•failure to comply with any other covenants of the Mortgage Indenture after 30 days' written notice from the Trustee;

•failure to pay or provide for judgments in excess of $30 million in aggregate amount within 60 days of the entry thereof; or

•certain events that are or could be the basis of a bankruptcy, reorganization, insolvency or receivership proceeding.

Upon the occurrence and continuance of such an Event of Default, the Mortgage Indenture, subject to any provisions of law applicable thereto, provides that the Trustee may take possession and conduct the business of the NJNG, may sell the trust estate, or proceed to foreclose the lien of the Mortgage Indenture. The interest rate on defaulted principal and interest, to the extent permitted by law, on the FMB issued under the Mortgage Indenture is the rate stated in the applicable supplement or, if no such rate is stated, six percent per annum.

Sale-Leaseback

NJNG received $7.1 million and $7.2 million in December 2015 and 2014, 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

NJNG's total capital expenditures are projected to be $291.1 million and $230.5 million, in fiscal 2016 and 2017, respectively. Total capital expenditures spent or accrued during the three months endedDecember 31, 2015 were $44.4 million.

NJNG expects to fund its obligations with a combination of cash flow from operations, cash on hand, issuance of commercial paper, available capacity under its revolving credit facility, the issuance of long-term debt and contributions from NJR.

As of December 31, 2015, NJNG's future MGP expenditures are estimated to be $180.4 million. For a more detailed description of MGP see Note 12. Commitments and Contingent Liabilities in the accompanying Unaudited Condensed Consolidated Financial Statements.

Estimated capital expenditures are reviewed on a regular basis and may vary based on the ongoing effects of regulatory constraints, environmental regulations, unforeseen events, and the ability to access capital.

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

OPERATIONS (Continued)

NJRCEV's expenditures include distributed power 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. During three months endedDecember 31, 2015, capital expenditures spent related to the purchase and installation of the solar equipment were $14.9 million. An additional $45.3 million has been committed or accrued for solar projects to be placed into service during fiscal 2016 and beyond. The Company estimates solar-related capital expenditures placed in service in fiscal 2016 to be between $75 million and $95 million.

During the first quarter of fiscal 2016, NJRCEV commenced construction of an $84 million, 39.9 MW onshore wind project in Somerset County, Pennsylvania which is expected to be completed in the first quarter of fiscal 2017.

As of December 31, 2015, a total of $30.1 million has been spent and an additional $52.8 million has been committed or accrued for wind projects. In fiscal 2016, NJRCEV estimates that its wind-related capital expenditures will range between $80 million and $100 million.

Capital expenditures related to distributed power projects are subject to change due to a variety of factors that may affect our ability to commence operations at these projects on a timely basis or, at all, 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, economic trends, unforeseen events and the ability to access capital or allocation of capital to other investments or business opportunities.

We expect our expenditures related to our investment in the PennEast pipeline project to total between $40 million and $50 million in fiscal 2016.

NJRES does not currently anticipate any significant capital expenditures in fiscal 2016 and 2017.

Off-Balance-Sheet Arrangements

The Company's off-balance-sheet arrangements consist of guarantees covering approximately $296.4 million of natural gas purchases, SREC sales and demand fee commitments and outstanding letters of credit totaling $23.7 million, as noted above.

Cash Flow

Operating Activities

Cash flows (used in) from operating activities during during the three months endedDecember 31, 2015, totaled $(39.2) million compared with $40.8 million during the three months ended December 31, 2014. Operating cash flows are primarily affected by variations in working capital, which can be impacted by several factors, including:

•seasonality of NJR's business;

•fluctuations in wholesale natural gas prices, including changes in derivative asset and liability values;

•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;

•broker margin requirements;

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

•volumes of natural gas purchased and sold; and

•timing of SREC deliveries.

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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 decrease of $80.1 million in operating cash flows during the three months endedDecember 31, 2015, compared with the three months endedDecember 31, 2014, was impacted by:

• lower overall commodity prices and sales volumes, which contributed towards favorable changes at NJRES of $88.2 million in receivables balances, offset by a decrease in cash associated with gas purchases payables of $64.8 million and $15.2 million in gas in storage at NJRES, due primarily to the volatility that occurred during the three months endedDecember 31, 2014 that did not recur during three months endedDecember 31, 2015;

• a decrease of $39.7 million in broker margin balances resulting primarily from a change in the value of open positions held as of December 31, 2015, compared with those held as of December 31, 2014, due to the volatility as discussed above;

• lower usage related to warmer winter weather, coupled with bill credits issued to NJNG's customers during fiscal 2016 for overrecovered gas costs as a result of the decline in the wholesale price of natural gas; and

• a discretionary contribution of $30 million to the Company's pension plan during fiscal 2016.

Investing Activities

Cash flows used in investing activities totaled $95.4 million during three months endedDecember 31, 2015, compared with $92.2 million during the three months ended December 31, 2014. The increase of $3.2 million was due primarily to an increase in utility plant expenditures of $12.3 million, partially offset by a decrease in capital expenditures of $10.3 million related to wind projects at NJRCEV. NJR also contributed an additional $2.3 million for its investment in PennEast during three months endedDecember 31, 2015.

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 gas management and marketing activities at NJRES and distributed power investments at NJRCEV.

Cash flows used in financing activities totaled $131.4 million during the three months endedDecember 31, 2015, compared with $60.9 million during the three months endedDecember 31, 2014. The increase of $70.4 million is due primarily to increased short-term borrowings at both NJR and NJNG, partially offset by the issuance of $100 million in long-term debt for NJR during the three months endedDecember 31, 2014, along with a decrease in proceeds from the issuance of common stock when compared with the three months endedDecember 31, 2014, during which 688,000 new shares were issued through the waiver discount feature of the DRP.

Credit Ratings

On January 30, 2014, Moody's upgraded NJNG's senior secured rating from Aa3 to Aa2, while maintaining a stable outlook. The rating upgrade was driven primarily by the overall credit supportiveness of the regulatory environment under which NJNG operates. In its review of NJNG's credit rating, Moody's considered the BPU's continued support of NJNG's rate mechanisms, which allows for timely recovery of costs, including those associated with NJNG's BGSS and CIP. In addition, the favorable recovery of investments related to NJNG's infrastructure and energy efficiency programs factored into the rating upgrade.

The table below summarizes NJNG's current credit ratings issued by two rating entities, S&P and Moody's

	Standard and Poor's	Moody's
Corporate Rating	A	N/A
Commercial Paper	A-1	P-1
Senior Secured	A+	Aa2
Ratings Outlook	Stable	Stable

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

OPERATIONS (Continued)

These ratings were re-affirmed by each agency respectively prior to December 31, 2015. NJNG's S&P and Moody's ratings are investment-grade ratings. NJR is not a rated entity.

Although 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 and our access to capital markets would be reduced. Even if ratings are downgraded without falling below investment grade, NJR and NJNG could face increased borrowing costs under their credit facilities. A rating set forth above is not a recommendation to buy, sell or hold the Company's or NJNG's securities and may be subject to revision or withdrawal at any time. Each rating set forth above should be evaluated independently of any other rating.

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

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK                                              

Financial Risk Management

Commodity Market Risks

Natural gas is a nationally traded commodity. Its prices are determined effectively by the NYMEX, ICE and over-the-counter markets. The prices on the NYMEX/CME, 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 deregulated 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, options 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. Financial derivatives have historically been transacted on an exchange and cleared through an FCM, thus requiring daily cash margining for a majority of NJRES' and NJNG's positions. As a result of the Dodd-Frank Act, certain NJRES and NJNG 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 (i.e., 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, 2015 to December 31, 2015:

	Balance				Increase				Less				Balance
(Thousands)	September 30, 2015				(Decrease) in Fair Market Value				Amounts Settled				December 31, 2015
NJNG		$	(10,881	)		$	(6,623	)		$	(4,505	)		$	(12,999	)
NJRES		24,575				42,846				34,181				33,240
Total		$	13,694			$	36,223			$	29,676			$	20,241

There were no changes in methods of valuations during the three months endedDecember 31, 2015.

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

The following is a summary of fair market value of financial derivatives at December 31, 2015, excluding foreign exchange contracts discussed below, by method of valuation and by maturity for each fiscal year period:

(Thousands)	2016		2017		2018 - 2020				After 2020			Total Fair Value
Price based on NYMEX/CME	$	637	$	984		$	—			$	—		$	1,621
Price based on ICE	17,602		1,025			(7		)		—			18,620
Total	$	18,239	$	2,009		$	(7	)		$	—		$	20,241

The following is a summary of financial derivatives by type as of December 31, 2015:

		Volume Bcf		Price per MMBtu(1)	Amounts included in Derivatives (Thousands)
NJNG	Futures	19.5		$1.54 - $6.95		$	(12,999	)
NJRES	Futures	(120.8	)	$1.17 - $5.84		32,215
	Options	5.8		$0.01 - $0.24		1,025
Total						$	20,241

(1) Million British thermal unit

The following table reflects the changes in the fair market value of physical commodity contracts from September 30, 2015 to December 31, 2015:

	Balance				Increase			Less			Balance
(Thousands)	September 30, 2015				(Decrease) in Fair Market Value			Amounts Settled			December 31, 2015
NJRES - Prices based on other external data		$	(2,709	)		(14,366	)		(6,981	)		$	(10,094	)

The following table reflects the changes in the fair market value of interest rate contracts from September 30, 2015 to December 31, 2015:

	Balance				Increase		Less		Balance
(Thousands)	September 30, 2015				(Decrease) in Fair Market Value		Amounts Settled		December 31, 2015
NJNG - Prices based on other external data		$	(4,228	)		2,367		—		$	(1,861	)

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 fixed price swaps is derived from this location, the price sensitivity analysis 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 $12.7 million. This analysis does not include potential changes to reported credit adjustments embedded in the $21.7 million reported fair value.

Derivative Fair Value Sensitivity Analysis
(Thousands)	Henry Hub Futures and Fixed Price Swaps
Percent increase in NYMEX natural gas futures prices	0%		5%			10%			15%			20%
Estimated change in derivative fair value	$	—	$	(6,353	)	$	(12,706	)	$	(19,059	)	$	(25,412	)
Ending derivative fair value	$	21,704	$	15,351		$	8,998		$	2,645		$	(3,708	)
Percent decrease in NYMEX natural gas futures prices	0%		(5)%			(10)%			(15)%			(20)%
Estimated change in derivative fair value	$	—	$	6,353		$	12,706		$	19,059		$	25,412
Ending derivative fair value	$	21,704	$	28,057		$	34,410		$	40,763		$	47,116

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

Wholesale Credit Risk

The following is a summary of gross and net credit exposures, grouped by investment and noninvestment grade counterparties, as of December 31, 2015. 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 or power 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' & NJRCEV's counterparty credit exposure as of December 31, 2015, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	92,824		$	68,111
Noninvestment grade		9,672			531
Internally rated investment grade		22,397			11,743
Internally rated noninvestment grade		2,566			518
Total		$	127,459		$	80,903

NJNG's counterparty credit exposure as of December 31, 2015, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	6,581		$	5,772
Noninvestment grade		21			—
Internally rated investment grade		110			56
Internally rated noninvestment grade		5,249			72
Total		$	11,961		$	5,900

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, 2015.

Effects of Inflation

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

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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), 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 December 31, 2015, that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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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, 2015, and is set forth in Part I, Item 1, Note 12.Commitment and Contingent Liabilities-Legal Proceedings on the Unaudited Condensed Consolidated Financial Statements. No legal proceedings became reportable during the quarter ended December 31, 2015, 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 2015 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 2015 Annual Report on Form 10-K.

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

The following table sets forth NJR's repurchase activity for the quarter ended December 31, 2015:

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 (1)
10/01/15 - 10/31/15	—	$	—	—	2,662,653
11/01/15 - 11/30/15	—	$	—	—	2,662,653
12/01/15 - 12/30/15	34,700	$	29.04	34,700	2,627,953
Total	34,700	$	—	34,700	2,627,953

(1)    Share data has been retroactively adjusted to reflect a 2 for 1 stock split effective March 3, 2015.

The stock repurchase plan, which was authorized by our Board of Directors, became effective in September 1996 and as of December 31, 2015, included 19.5 million shares of common stock for repurchase, of which, approximately 2.6 million 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.

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ITEM 6. EXHIBITS                                                                                                                                                                         

Exhibit Number Exhibit Description

10.1	Form of Amended and Restated Employment Continuation Agreement between the Company and named executive officer (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K, as filed on December 16, 2015)
10.2	Form of Amended and Restated Employment Continuation Agreement between the Company and NJR Energy Services Company named executive officer (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K, as filed on December 16, 2015)
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 December 31, 2015, 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.

60

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:	February 3, 2016
		By:/s/ Patrick Migliaccio
		Patrick Migliaccio
		Senior Vice President and
		Chief Financial Officer

61

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 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 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:	February 3, 2016	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, Patrick Migliaccio, certify that:

1) I have reviewed this 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 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:	February 3, 2016	By:	/s/ Patrick Migliaccio
			Patrick Migliaccio
			Senior 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 quarter ended December 31, 2015, 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:	February 3, 2016	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, Patrick Migliaccio 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 quarter ended December 31, 2015, 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:	February 3, 2016	By:	/s/ Patrick Migliaccio
			Patrick Migliaccio
			Senior Vice President and Chief Financial Officer

XML

Document and Entity Information - shares	3 Months Ended
	Dec. 31, 2015	Feb. 01, 2016
Document and Entity Information [Abstract]
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		85,923,516
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
OPERATING REVENUES
Utility		$ 151,606	$ 208,727
Nonutility		292,652	615,397
Total operating revenues		444,258	824,124
OPERATING EXPENSES
Gas Purchases - Utility		46,665	84,263
Gas Purchases - Nonutility		254,088	472,971
Gas Purchases - Related parties		2,074	3,264
Operation and maintenance		46,233	44,759
Regulatory rider expenses		9,628	21,463
Depreciation and amortization		16,482	14,386
Energy and other taxes		9,637	14,321
Total operating expenses		384,807	655,427
OPERATING INCOME		59,451	168,697
Other income (expense), net		1,924	(110)
Interest expense, net of capitalized interest		6,777	7,195
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES		54,598	161,392
Income tax provision		8,357	40,867
Equity in earnings of affiliates		2,406	2,795
NET INCOME		$ 48,647	$ 123,320
EARNINGS PER COMMON SHARE
Basic (usd per share)		$ 0.57	$ 1.46
Diluted (usd per share)	[1]	0.56	1.44
DIVIDENDS DECLARED PER COMMON SHARE (usd per share)		$ 0.24	$ 0.225
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic (in shares)		85,675	84,552
Diluted (in shares)		86,676	85,574

[1] There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three months ended December 31, 2015, and 2014.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Net income	$ 48,647	$ 123,320
Other comprehensive income, net of tax
Unrealized gain on available for sale securities, net of tax of $(2,614) and $(455), respectively	3,701	659
Net unrealized (loss) on derivatives, net of tax of $19, and $18, respectively	(33)	(31)
Adjustment to postemployment benefit obligation, net of tax of $(174) and $(169), respectively	256	247
Other comprehensive income	3,924	875
Comprehensive income	$ 52,571	$ 124,195

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parentheticals) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Tax on unrealized gain on available for sale securities	$ (2,614)	$ (455)
Tax on net unrealized loss on derivatives	19	18
Tax on adjustment for postemployment benefit obligation	$ (174)	$ (169)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
CASH FLOWS (USED IN) FROM OPERATING ACTIVITIES
Net income	$ 48,647	$ 123,320
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) on derivative instruments	(1,135)	(88,673)
Depreciation and amortization	16,482	14,386
Allowance for equity used during construction	(1,215)	(1,253)
Allowance for bad debt expense	334	964
Deferred income taxes	46,166	35,897
Manufactured gas plant remediation costs	(1,520)	(1,008)
Equity in earnings of equity investees, net of distributions received	1,139	2,146
Cost of removal - asset retirement obligations	(33)	(105)
Contributions to postemployment benefit plans	(30,144)	(69)
Changes in:
Components of working capital	(102,068)	(75,089)
Other noncurrent assets	(20,270)	13,489
Other noncurrent liabilities	4,401	16,844
Cash flows (used in) from operating activities	(39,216)	40,849
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Utility plant expenditures	(42,465)	(34,114)
Solar and wind equipment expenditures	(45,006)	(55,345)
Real estate properties and other expenditures	(797)	(11)
Cost of removal expenditures	(6,575)	(2,634)
Investments in equity investees	(2,846)	(547)
Other	2,304	445
Cash flows (used in) investing activities	(95,385)	(92,206)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common stock	3,807	24,373
Tax benefit from stock options exercised	0	816
Proceeds from sale-leaseback transaction	7,107	7,216
Proceeds from long-term debt	0	100,000
Payments of long-term debt	(2,676)	(1,723)
Purchases of treasury stock	(1,008)	(3,945)
Payments of common stock dividends	(20,524)	(18,993)
Net proceeds from (payments of) short-term debt	144,650	(46,804)
Cash flows from financing activities	131,356	60,940
Change in cash and cash equivalents	(3,245)	9,583
Cash and cash equivalents at beginning of period	4,928	2,151
Cash and cash equivalents at end of period	1,683	11,734
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	(27,784)	(166,229)
Inventories	(26,772)	8,385
Recovery of gas costs	(11,882)	2,015
Gas purchases payable	(7,071)	65,563
Gas purchases payable - related parties	(406)	184
Prepaid and accrued taxes	(27,794)	14,108
Accounts payable and other	(22,489)	(53,852)
Restricted broker margin accounts	6,855	46,550
Customers' credit balances and deposits	10,056	14,345
Other current assets	5,219	(6,158)
Components of working capital	(102,068)	(75,089)
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for Interest (net of amounts capitalized)	5,403	1,376
Cash paid for Income taxes	202	2,228
Accrued capital expenditures	$ 21,721	$ 12,107

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Dec. 31, 2015	Sep. 30, 2015
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 1,937,686	$ 1,908,024
Construction work in progress	161,686	155,553
Solar and wind equipment, real estate properties and other, at cost	569,820	481,003
Construction work in progress	35,253	77,705
Total property, plant and equipment	2,704,445	2,622,285
Accumulated depreciation and amortization, utility plant	(446,133)	(437,097)
Accumulated depreciation and amortization, solar and wind equipment, real estate properties and other	(62,213)	(56,927)
Property, plant and equipment, net	2,196,099	2,128,261
CURRENT ASSETS
Cash and cash equivalents	1,683	4,928
Customer accounts receivable
Billed	168,729	155,273
Unbilled revenues	19,883	6,372
Allowance for doubtful accounts	(4,706)	(5,189)
Regulatory assets	26,739	24,258
Gas in storage, at average cost	189,907	163,905
Materials and supplies, at average cost	7,908	7,138
Prepaid and accrued taxes	64,616	36,810
Derivatives, at fair value	58,978	40,743
Restricted broker margin accounts	21,334	12,990
Other	33,868	40,987
Total current assets	588,939	488,215
NONCURRENT ASSETS
Investments in equity investees	134,280	132,002
Regulatory assets	423,332	410,155
Derivatives, at fair value	3,741	4,334
Available for sale securities	65,790	59,475
Other	65,057	61,915
Total noncurrent assets	692,200	667,881
Total assets	3,477,238	3,284,357
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding December 31, 2015 — 85,809,094; September 30, 2015 — 85,531,423	221,555	220,838
Premium on common stock	213,351	209,931
Accumulated other comprehensive (loss), net of tax	(5,470)	(9,394)
Treasury stock at cost and other; shares December 31, 2015 — 2,812,896; September 30, 2015 — 2,804,847	(91,290)	(92,164)
Retained earnings	805,798	777,745
Common stock equity	1,143,944	1,106,956
Long-term debt	848,206	843,595
Total capitalization	1,992,150	1,950,551
CURRENT LIABILITIES
Current maturities of long-term debt	10,958	11,138
Short-term debt	211,000	66,350
Gas purchases payable	144,349	151,375
Gas purchases payable to related parties	1,150	1,601
Accounts payable and other	69,563	99,651
Dividends payable	20,594	20,528
Accrued taxes	1,338	1,326
Regulatory liabilities	1,091	12,154
New Jersey clean energy program	12,907	14,293
Derivatives, at fair value	51,879	32,791
Broker margin accounts	19,307	4,103
Customers' credit balances and deposits	30,846	20,790
Total current liabilities	574,982	436,100
NONCURRENT LIABILITIES
Deferred income taxes	491,522	444,935
Deferred investment tax credits	4,859	4,940
Deferred revenue	29,130	29,334
Derivatives, at fair value	2,606	5,529
Manufactured gas plant remediation	180,400	180,400
Postemployment employee benefit liability	108,432	137,414
Regulatory liabilities	63,311	67,533
Asset retirement obligation	20,960	19,145
Other	8,886	8,476
Total noncurrent liabilities	$ 910,106	$ 897,706
Commitments and contingent liabilities (Note 12)
Total capitalization and liabilities	$ 3,477,238	$ 3,284,357

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parentheticals) - $ / shares	Dec. 31, 2015	Sep. 30, 2015
Statement of Financial Position [Abstract]
Common stock, par value (usd per share)	$ 2.50	$ 2.50
Common stock, shares authorized	150,000,000	150,000,000
Common stock, shares outstanding	85,809,094	85,531,423
Treasury stock at cost and other, shares	2,812,896	2,804,847

XML

NATURE OF THE BUSINESS

3 Months Ended

Dec. 31, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

NATURE OF THE BUSINESS

NATURE OF THE BUSINESS

New Jersey Resources Corporation provides regulated gas distribution services and operates certain unregulated businesses primarily through the following subsidiaries:

New Jersey Natural Gas Company provides natural gas utility service to approximately 516,300 retail customers in central and northern New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment;

NJR Energy Services Company comprises the Energy Services segment that maintains and transacts around a portfolio of natural gas storage and transportation capacity contracts and provides physical wholesale energy and energy management services;

NJR Clean Energy Ventures Corporation, the Company's distributed power subsidiary, comprises the Clean Energy Ventures segment and consists of the Company's capital investments in distributed power projects, including commercial and residential solar projects and onshore wind investments;

NJR Midstream Holdings Corporation invests in energy-related ventures through its subsidiaries, NJR Steckman Ridge Storage Company, which holds the Company's 50 percent combined interest in Steckman Ridge, and NJR Pipeline Company, which holds the Company's 20 percent ownership interest in PennEast and1.84 million Common Units of Dominion Midstream Partners, L.P. The investments in Steckman Ridge, PennEast and DM comprise the Midstream segment; and

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

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Dec. 31, 2015

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 Generally Accepted in the United States of America. The September 30, 2015, 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 2015 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, 2016. Intercompany transactions and accounts have been eliminated.

Gas in Storage

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

	December 31, 2015				September 30, 2015
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJRES		$	119,401	62.0		$	93,696	44.6
NJNG		70,506		23.0		70,209		21.4
Total		$	189,907	85.0		$	163,905	66.0

Sales Tax Accounting

Sales tax, that is collected from customers and presented in both operating revenues and operating expenses on the Unaudited Condensed Consolidated Statements of Operations, was $7.2 million and $11.8 million during the three months endedDecember 31, 2015 and 2014, respectively.

Available for Sale Securities

Included in available for sale securities on the Unaudited Condensed Consolidated Balance Sheets are certain investments in two publicly traded energy companies. Total unrealized gains associated with these investments are included as a part of accumulated other comprehensive income, a component of common stock equity. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

The Company has equity securities that had a fair value of $9.4 million and $10.1 million as of December 31, 2015 and September 30, 2015, respectively. Total unrealized gains associated with these equity securities were $6.8 million, $4 million after tax, and $7.5 million, $4.4 million after tax, as of December 31, 2015 and September 30, 2015, respectively. The Company also has 1.84 million DM Common Units that had a fair value of $56.4 million and $49.4 million as of December 31, 2015 and September 30, 2015, respectively. Total unrealized gains associated with these units were $10.3 million, $6.1 million after tax, and $3.3 million, $1.9 million after tax, as of December 31, 2015 and September 30, 2015, respectively.

Common Stock Split

On January 20, 2015, NJR’s Board of Directors approved a 2 for 1 stock split of the Company’s common stock for the Company’s common stock holders of record on February 6, 2015. The additional shares were issued on March 3, 2015, resulting in an increase in average shares outstanding from approximately 42.7 million to approximately 85.4 million. All share-related information for prior periods has been adjusted throughout this report on a retroactive basis to reflect the effects of the stock split. As well, common stock and premium on common stock amounts have been adjusted as of the earliest period presented on the Unaudited Condensed Consolidated Balance Sheets.

Customer Accounts Receivable

Customer accounts receivable include outstanding billings from the following subsidiaries as of:

(Thousands)	December 31, 2015				September 30, 2015
NJRES	$	113,332	67	%	$	107,461	69	%
NJNG (1)	49,664		29		41,130		26
NJRCEV	1,471		1		1,084		1
NJRHS and other	4,262		3		5,598		4
Total	$	168,729	100	%	$	155,273	100	%

(1) Does not include unbilled revenues of $19.9 million and $6.4 million as of December 31, 2015 and September 30, 2015, respectively.

Loan Receivable

NJNG provides interest-free loans, with terms ranging from two to 10 years, to customers that elect to purchase and install certain energy efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at net present value on the Unaudited Condensed Consolidated Balance Sheets. The Company has recorded $7 million and $6.2 million in other current assets and $39.2 million and $36.2 million in other noncurrent assets as of December 31, 2015 and September 30, 2015, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans.

NJR's policy is to establish an allowance for doubtful accounts when loan balances are in arrears for more than 60 days. As of December 31, 2015 and September 30, 2015, there was no allowance for doubtful accounts established for the SAVEGREEN loans.

Recent Updates to the Accounting Standards Codification

Revenue

In May 2014, the FASB issued ASU No. 2014-09, and added Topic 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries, jurisdictions and capital markets. In August 2015, the FASB issued ASU No. 2015-14, which defers the implementation of the new guidance for one year. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Upon adoption, the guidance will be applied on a full or modified retrospective basis. The Company is currently evaluating the provisions of ASC 606 to understand the impact, if any, to its financial position, results of operations and cash flows upon adoption.

Stock Compensation

In June 2014, the FASB issued ASU No. 2014-12, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for performance awards when the terms of the award provide that a performance target could be achieved after the requisite service period. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. The Company does not expect this standard to have any impact to its financial position, results of operations and cash flows upon adoption.

Consolidation

In February 2015, the FASB issued ASU No. 2015-02, an amendment to ASC 810, Consolidation, which changes the consolidation analysis required under GAAP and reevaluates whether limited partnerships and similar entities must be consolidated. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendment will be applied on a full or modified retrospective basis. The Company is currently evaluating the provisions of ASU No. 2015-02 to understand the impact, if any, on its financial position, results of operations and cash flows upon adoption.

Interest

In April 2015, the FASB issued ASU No. 2015-03, an amendment to ASC 835, Interest - Imputation of Interest, which simplifies the presentation of debt issuance costs by requiring them to be presented in the balance sheet as a deduction from the carrying amount of the liability. The amendments do not affect the recognition and measurement guidance for debt issuance costs. In August 2015, the FASB issued ASU No. 2015-15, which clarified that the amendments contained within ASU No. 2015-03 do not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The amended guidance becomes effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendment will be applied on a retrospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations and cash flows upon adoption.

Intangibles

In April 2015, the FASB issued ASU No. 2015-05, an amendment to ASC 350, Intangibles - Goodwill and Other - Internal-Use Software, which clarifies the accounting for fees in a cloud computing arrangement. The amendments provide guidance on how an entity should evaluate the accounting for fees paid in a cloud computing arrangement to determine whether an arrangement includes the sale or license of software. The amended guidance becomes effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendments can be applied on a prospective or retrospective basis. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Inventory

In July 2015, the FASB issued ASU No. 2015-11, an amendment to ASC 330, Inventory, which requires entities to measure most inventory “at the lower of cost and net realizable value,” thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. The guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations and cash flows upon adoption.

Income Taxes

In November 2015, the FASB issued ASU 2015-17, an amendment to ASC 740, Income Taxes, to simplify the balance sheet presentation of deferred income taxes. The update requires entities to present all deferred tax assets and liabilities as noncurrent. The Company elected to early adopt the amended guidance effective October 1, 2015, and applied the new provisions retrospectively. Accordingly, the following amounts on the Unaudited Condensed Consolidated Balance Sheets, as of September 30, 2015, have been adjusted:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Deferred taxes (current)	$	56,296	$	(56,296	)	$	—
Total current assets	$	544,511	$	(56,296	)	$	488,215
Other noncurrent assets	$	60,300	$	1,615		$	61,915
Total noncurrent assets	$	666,266	$	1,615		$	667,881
Total assets	$	3,339,038	$	(54,681	)	$	3,284,357
Capitalization and Liabilities
Deferred income taxes	$	499,616	$	(54,681	)	$	444,935
Total noncurrent liabilities	$	952,387	$	(54,681	)	$	897,706
Total capitalization and liabilities	$	3,339,038	$	(54,681	)	$	3,284,357

There was no additional impact to the Unaudited Condensed Consolidated Statements of Operations or the Unaudited Condensed Consolidated Statements of Cash Flows.

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REGULATION

3 Months Ended

Dec. 31, 2015

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. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.

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

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

(Thousands)	December 31, 2015		September 30, 2015
Regulatory assets-current
Conservation Incentive Program	$	819	$	—
New Jersey Clean Energy Program	12,907		14,293
Derivatives at fair value, net	13,013		9,965
Total current regulatory assets	$	26,739	$	24,258
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	17,963	$	18,886
Liability for future expenditures	180,400		180,400
Deferred income taxes	18,233		17,460
Derivatives at fair value, net	1,861		5,153
SAVEGREEN	27,968		26,882
Postemployment and other benefit costs	138,491		140,636
Deferred Superstorm Sandy costs	15,201		15,201
Conservation Incentive Program	17,552		—
Other noncurrent regulatory assets	5,663		5,537
Total noncurrent regulatory assets	$	423,332	$	410,155
Regulatory liability-current
Conservation Incentive Program	$	—	$	5,167
Overrecovered gas costs	1,091		6,987
Total current regulatory liabilities	$	1,091	$	12,154
Regulatory liabilities-noncurrent
Cost of removal obligation	$	48,683	$	54,880
New Jersey Clean Energy Program	14,512		11,956
Other noncurrent regulatory liabilities	116		697
Total noncurrent regulatory liabilities	$	63,311	$	67,533

Regulatory filings and/or actions that occurred during the current fiscal year include the following:

• On October 15, 2015, the BPU approved a base rate increase related to NJ RISE resulting in a .07 percent increase to the average residential heat customer's bill, effective November 1, 2015, to recover costs through July 31, 2015.

• On October 15, 2015, the BPU issued an order approving the continuation of the BGSS Incentive Programs with modification to the storage incentive program, beginning with the 2015 storage injection period, and termination of the FRM Program, effective November 1, 2015.

• On October 27, 2015, NJNG notified the BPU that the bill credits to residential and small commercial customers, which will be issued from November 2015 through February 2016, will be approximately $76 million and will result in an approximate 17 percent decrease to the average residential heat customer's bill.

• On November 13, 2015, NJNG filed a base rate petition with the BPU to increase its base tariff rates in the amount of $147.6 million.

• On December 24, 2015, NJNG filed an SBC petition with the BPU to increase the RA factor, to decrease the NJCEP factor and to request approval of its remediation expenses incurred through June 30, 2015, resulting in an overall decrease of .8 percent to the average residential heat customer's bill.

• On January 27, 2016, the BPU approved NJNG’s July 2015 petition to maintain its existing SAVEGREEN recovery rate.

• On January 27, 2016, the BPU approved NJNG's proposed SRL pipeline installation, operation and route selection, as modified by NJNG, including specific requirements regarding permitting, safety and integrity assessment.

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DERIVATIVE INSTRUMENTS

3 Months Ended

Dec. 31, 2015

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, SRECs, and electricity. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs, and electricity. In addition, the Company may utilize foreign currency derivatives as cash flow hedges of Canadian dollar denominated gas purchases and/or sales. 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 NJR's derivative instruments, see Note 5. Fair Value.

Since NJRES chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, 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 U.S. dollar. NJRES may utilize 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 may be used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company designates these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in OCI. When the foreign exchange contracts are settled and the related purchases are recognized in income, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over 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. NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff for gas service.

The Company elects NPNS accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, physical purchases are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered. The average cost of natural gas is amortized in current period earnings based on the current BPU BGSS factor and therm sales.

NJRCEV hedges certain of its expected production of SRECs through forward and futures contracts. The contracts require the Company to physically deliver the SRECs upon settlement. The Company elects NPNS accounting treatment on all SREC forward and futures contracts it enters into during the period. NJRCEV recognizes the related revenue upon transfer of the SREC certificate to the counterparty.

In an April 2014 BPU Order, NJNG received regulatory approval to enter into interest rate risk management transactions related to long-term debt securities. On June 1, 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with the forecasted $125 million debt issuance expected in May 2018. This forecasted debt issuance coincides with the maturity of NJNG's existing $125 million, 5.6 percent notes due May 15, 2018. The change in fair value of NJNG's treasury lock agreement is recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets since NJNG believes that the market value upon settlement will be reflected in future rates. Upon settlement, any gain or loss will be amortized in earnings over the life of the future debt issuance.

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
			December 31, 2015						September 30, 2015
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	—		$	52		$	—		$	—
Fair value of derivatives designated as hedging instruments			$	—		$	52		$	—		$	—
Derivatives not designated as hedging instruments:
NJNG:
Financial commodity contracts	Derivatives - current		$	820		$	13,819		$	207		$	10,163
	Derivatives - noncurrent		—			—			—			925
Interest rate contracts	Derivatives - noncurrent		$	—		$	1,861		$	—		$	4,228
NJRES:
Physical forward commodity contracts	Derivatives - current		$	9,844		$	22,333		$	4,854		$	9,281
	Derivatives - noncurrent		3,045			650			1,718			—
Financial commodity contracts	Derivatives - current		48,314			15,675			35,682			13,347
	Derivatives - noncurrent		696			95			2,626			386
Fair value of derivatives not designated as hedging instruments			$	62,719		$	54,433		$	45,087		$	38,330
Total fair value of derivatives			$	62,719		$	54,485		$	45,087		$	38,330

Offsetting of Derivatives

NJR transacts under master netting arrangements or equivalent agreements that allow it to offset derivative assets and liabilities with the same counterparty. However, NJR's policy is to present its derivative assets and liabilities on a gross basis on the Unaudited Condensed Consolidated Balance Sheets.

The following table summarizes the reported gross amounts, the amounts that NJR has the right to offset but elects not to, financial collateral, as well as the net amounts NJR could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(Thousands)	Amounts Presented in Balance Sheets (1)			Offsetting Derivative Instruments (2)				Financial Collateral Received/Pledged (3)				Net Amounts (4)
As of December 31, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	12,889		$	(809	)		$	(1,000	)		$	11,080
Financial commodity contracts		49,010			(13,004		)		(25,136		)		10,870
Total NJRES		$	61,899		$	(13,813	)		$	(26,136	)		$	21,950
NJNG
Financial commodity contracts		$	820		$	(820	)		$	—			$	—
Total NJNG		820			(820		)		—				—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	22,983		$	(809	)		$	(1,200	)		$	20,974
Financial commodity contracts		15,770			(13,004		)		(2,766		)		—
Foreign currency contracts		52			—				—				52
Total NJRES		$	38,805		$	(13,813	)		$	(3,966	)		$	21,026
NJNG
Financial commodity contracts		$	13,819		$	(820	)		$	(12,999	)		$	—
Interest rate contracts		$	1,861		$	—			$	—			$	1,861
Total NJNG		$	15,680		$	(820	)		$	(12,999	)		$	1,861
As of September 30, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	6,562		$	(1,326	)		$	—			$	5,236
Financial commodity contracts		38,308			(13,734		)		3,841				28,415
Total NJRES		$	44,870		$	(15,060	)		$	3,841			$	33,651
NJNG
Financial commodity contracts		$	207		$	(207	)		$	—			$	—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	9,271		$	(1,326	)		$	(1,200	)		$	6,745
Financial commodity contracts		13,733			(13,733		)		—				—
Total NJRES		$	23,004		$	(15,059	)		$	(1,200	)		$	6,745
NJNG
Financial commodity contracts		$	11,088		$	(207	)		$	(10,881	)		$	—
Interest rate contracts		4,228			—				—				4,228
Total NJNG		$	15,316		$	(207	)		$	(10,881	)		$	4,228

(1) Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.

(2) Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.

(3) Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties.

(4) Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.

NJRES utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical gas for injection into storage and the subsequent sale of physical gas at a later date. The gains or (losses) on the financial transactions that are economic hedges of the cost of the purchased gas are recognized prior to the gains or (losses) on the physical transaction, which are recognized in earnings when the natural gas is sold. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments creates volatility in the results of NJRES, although the Company's intended economic results relating to the entire transaction are unaffected.

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

(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended
		December 31,
Derivatives not designated as hedging instruments:		2015			2014
NJRES:
Physical commodity contracts	Operating revenues	$	11,874		$	16,091
Physical commodity contracts	Gas purchases	(21,237		)	(19,856		)
Financial commodity contracts	Gas purchases	41,276			117,721
Total unrealized and realized gains		$	31,913		$	113,956

The table above does not include gains (losses) associated with NJNG's financial derivatives of $(5.6) million and $(19) million for the three months endedDecember 31, 2015 and 2014, respectively and the treasury rate lock of $2.4 million for the three months endedDecember 31, 2015. NJNG’s derivative contracts are part of the Company's risk management activities that relate to its natural gas purchases, BGSS incentive programs and debt financing. These transactions are entered into pursuant to regulatory guidance and at settlement the resulting gains and/or losses are payable to and/or recoverable from customers. Any changes in the value of NJNG's financial derivatives are deferred in regulatory assets or liabilities resulting in no impact to earnings.

NJRES previously designated 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 table reflects the effect of derivative instruments designated as cash flow hedges on OCI as of December 31:

(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)					Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Three Months Ended						Three Months Ended					Three Months Ended
	December 31,						December 31,					December 31,
Derivatives in cash flow hedging relationships:	2015			2014			2015		2014			2015		2014
Foreign currency contracts	$	(64	)	$	(24	)	$	12	$	(25	)	$	—	$	—

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

		Volume (Bcf)
		December 31, 2015		September 30, 2015
NJNG	Futures(1)	19.5		25.8
NJRES	Futures	(120.8	)	(91.1	)
	Options	5.8		1.2
	Physical	111.7		48.2

(1) Not included is the notional amount of $125 million related to NJNG’s treasury lock agreement.

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 exchange requirements and a variable amount based on a daily mark-to-market. The Company maintains separate broker margin accounts for NJNG and NJRES. The balances by company, are as follows:

(Thousands)	Balance Sheet Location	December 31, 2015			September 30, 2015
NJNG	Broker margin - Current assets	$	17,487		$	12,990
NJRES	Broker margin - Current assets	$	3,847		$	—
	Broker margin - Current (liabilities)	$	(19,307	)	$	(4,103	)

Wholesale Credit Risk

NJNG and NJRES are exposed to credit risk as a result of their wholesale marketing activities. In addition, NJRCEV engages in sales of electricity, capacity and SRECs. As a result of the inherent volatility in the prices of natural gas commodities, derivatives and SRECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty failed to perform the obligations under its contract (e.g., failed to deliver or pay for natural gas or SRECs), then the Company could sustain a loss.

NJR monitors and manages the credit risk of its wholesale marketing operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of current and prospective counterparties' financial statements and/or credit ratings, daily monitoring of counterparties' credit limits and exposure, daily communication with traders regarding credit status and the use of credit mitigation measures, such as collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit. Collateral may be requested due to NJR's election not to extend credit or because exposure exceeds defined thresholds. Most of NJR's wholesale marketing contracts contain standard netting provisions. These contracts include those governed by ISDA and the NAESB. The netting provisions refer to payment netting, whereby receivables and payables with the same counterparty are offset and the resulting net amount is paid to the party to which it is due.

Internally-rated exposure applies to counterparties that are not rated by S&P or Moody's. In these cases, the Company's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by S&P and/or Moody's are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of December 31, 2015. 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 and NJRCEV residential solar installations.

(Thousands)	Gross Credit Exposure
Investment grade		$	99,405
Noninvestment grade		9,693
Internally rated investment grade		22,507
Internally rated noninvestment grade		7,815
Total		$	139,420

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 December 31, 2015 and September 30, 2015, was $1.9 million and $4.2 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on December 31, 2015 and September 30, 2015, the Company would have been required to post an additional $1.9 million and $4.2 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, as previously discussed.

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FAIR VALUE

3 Months Ended

Dec. 31, 2015

Fair Value Disclosures [Abstract]

FAIR VALUE

FAIR VALUE

Fair Value of Assets and Liabilities

The fair value of cash and temporary investments, accounts receivable, current loan receivables, accounts payable, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. Non-current loan receivables are recorded based on what the Company expects to receive, which approximates fair value. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.

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

(Thousands)	December 31, 2015		September 30, 2015
Carrying value (1)	$	807,845	$	807,845
Fair market value	$	809,107	$	817,319

(1) Excludes capital leases of $51.3 million and $46.9 million as of December 31, 2015 and September 30, 2015, respectively.

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 December 31, 2015, NJR discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

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

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

Level 2 Other significant observable inputs such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG's treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. 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 were 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 December 31, 2015:
Assets:
Physical forward commodity contracts		$	—		$	12,889		$	—	$	12,889
Financial derivative contracts - natural gas		49,830			—			—		49,830
Available for sale equity securities - energy industry(1)		65,790			—			—		65,790
Other (2)		1,809			—			—		1,809
Total assets at fair value		$	117,429		$	12,889		$	—	$	130,318
Liabilities:
Physical forward commodity contracts		$	—		$	22,983		$	—	$	22,983
Financial commodity contracts - natural gas		29,589			—			—		29,589
Financial commodity contracts - foreign exchange		—			52			—		52
Interest rate contracts		—			1,861			—		1,861
Total liabilities at fair value		$	29,589		$	24,896		$	—	$	54,485
As of September 30, 2015:
Assets:
Physical forward commodity contracts		$	—		$	6,572		$	—	$	6,572
Financial derivative contracts - natural gas		38,515			—			—		38,515
Available for sale equity securities - energy industry(1)		59,475			—			—		59,475
Other (2)		1,572			—			—		1,572
Total assets at fair value		$	99,562		$	6,572		$	—	$	106,134
Liabilities:
Physical forward commodity contracts		$	—		$	9,281		$	—	$	9,281
Financial commodity contracts - natural gas		24,821			—			—		24,821
Interest rate contracts		—			4,228			—		4,228
Total liabilities at fair value		$	24,821		$	13,509		$	—	$	38,330

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

(2) Includes various money market funds in Level 1.

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INVESTMENTS IN EQUITY INVESTEES

3 Months Ended

Dec. 31, 2015

Investments, All Other Investments [Abstract]

INVESTMENTS IN EQUITY INVESTEES

INVESTMENTS IN EQUITY INVESTEES

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

(Thousands)	December 31, 2015		September 30, 2015
Steckman Ridge (1)	$	125,058	$	125,649
PennEast	9,222		6,353
Total	$	134,280	$	132,002

(1) Includes loans with a total outstanding principal balance of $70.4 million for both December 31, 2015 and September 30, 2015. The loans accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

NJR, through a subsidiary, NJR Pipeline Company, formed PennEast with five other investors, and plans to construct and operate a 118-mile pipeline that will extend from northeast Pennsylvania to western New Jersey.

NJRES and NJNG have entered into storage and park and loan agreements with Steckman Ridge. In addition, NJNG has entered into a precedent capacity agreement with PennEast with an estimated service date of November 2017. See Note 14. Related Party Transactions for more information on these intercompany transactions.

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EARNINGS PER SHARE

3 Months Ended

Dec. 31, 2015

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
	December 31,
(Thousands, except per share amounts)	2015		2014
Net income, as reported	$	48,647	$	123,320
Basic earnings per share
Weighted average shares of common stock outstanding-basic	85,675		84,552
Basic earnings per common share	$0.57		$1.46
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	85,675		84,552
Incremental shares (1)	1,001		1,022
Weighted average shares of common stock outstanding-diluted	86,676		85,574
Diluted earnings per common share (2)	$0.56		$1.44

(1) Incremental shares consist primarily of stock awards and performance shares.

(2) There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three months endedDecember 31, 2015, and 2014.

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COMMON STOCK EQUITY

3 Months Ended

Dec. 31, 2015

Equity [Abstract]

COMMON STOCK EQUITY

COMMON STOCK EQUITY

Changes in common stock equity during the three months endedDecember 31, 2015, are as follows:

(Thousands)	Number of Shares		Common Stock		Premium on Common Stock			Accumulated Other Comprehensive (Loss) Income				Treasury Stock And Other			Retained Earnings			Total
Balance at September 30, 2015	85,531		$	220,838	$	209,931			$	(9,394	)	$	(92,164	)	$	777,745		$	1,106,956
Net income															48,647			48,647
Other comprehensive income									3,924									3,924
Common stock issued:
Incentive plan	286		717		4,782													5,499
Dividend reinvestment plan	127				(1,339		)					5,144						3,805
Cash dividend declared ($.24 per share)															(20,594		)	(20,594		)
Treasury stock and other	(135	)			(23		)					(4,270		)				(4,293		)
Balance at December 31, 2015	85,809		$	221,555	$	213,351			$	(5,470	)	$	(91,290	)	$	805,798		$	1,143,944

NJR satisfies its external common equity requirements, if any, through issuances of its common stock, including the proceeds from stock issuances under its DRP. The DRP allows NJR, at its option, to use treasury shares or newly issued shares to raise capital. On December 14, 2015, NJR registered 5 million shares of NJR common stock for issuance under the DRP. NJR raised $3.8 million of equity through the DRP for both the three months endedDecember 31, 2015 and 2014, by issuing approximately 127,000 and 148,000 shares, respectively. NJR also raised approximately $19.8 million of equity by issuing approximately 688,000 new shares through the waiver discount feature of the DRP during the three months endedDecember 31, 2014. NJR issued no new shares through the waiver discount feature of the DRP during the three months endedDecember 31, 2015. All fiscal 2015 share data has been adjusted for the March 2015 stock split.

Accumulated Other Comprehensive Income

The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects:

(Thousands)	Available for Sale Securities		Cash Flow Hedges				Postemployment Benefit Obligation				Total
Balance at September 30, 2015	$	6,385	$	—			$	(15,779	)		$	(9,394	)
Other comprehensive income, net of tax
Other comprehensive income (loss), before reclassifications, net of tax of ($2,614), $23, $0, ($2,591)	3,701		(41		)		—				3,660
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, ($4), ($174), ($178)	—		8			(1)	256			(2)	264
Net current-period other comprehensive income, net of tax of ($2,614), $19, $(174), $(2,769)	3,701		(33		)		256				3,924
Balance at December 31, 2015	$	10,086	$	(33	)		$	(15,523	)		$	(5,470	)
Balance at September 30, 2014	$	4,782	$	(93	)		$	(10,283	)		$	(5,594	)
Other comprehensive income (loss), net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(455), $9, $0, $(446)	659		(15		)		—				644
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $9, $(169), $(160)	—		(16		)	(1)	247			(2)	231
Net current-period other comprehensive income (loss), net of tax of $(455), $18, $(169), $(606)	659		(31		)		247				875
Balance at December 31, 2014	$	5,441	$	(124	)		$	(10,036	)		$	(4,719	)

(1) Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

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

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DEBT

3 Months Ended

Dec. 31, 2015

Debt Disclosure [Abstract]

DEBT

DEBT

NJR and NJNG finance working capital requirements and capital expenditures through various short-term debt and long-term financing arrangements, including a commercial paper program, committed unsecured credit facilities and private placement debt shelf facilities.

Credit Facilities

A summary of NJR's credit facility and NJNG's commercial paper program and credit facility are as follows:

(Thousands)	December 31, 2015			September 30, 2015			Expiration Dates
NJR
Bank revolving credit facilities(1)	$	425,000		$	425,000		September 2020
Notes outstanding at end of period	$	135,000		$	39,350
Weighted average interest rate at end of period	1.24		%	1.17		%
Amount available at end of period (2)	$	267,055		$	369,176
Bank revolving credit facilities(3)	$	—		$	100,000		October 2015
Amount available at end of period	$	—		$	100,000
NJNG
Bank revolving credit facilities (1)	$	250,000		$	250,000		May 2019
Commercial paper outstanding at end of period	$	76,000		$	27,000
Weighted average interest rate at end of period	.28		%	.20		%
Amount available at end of period (4)	$	173,269		$	222,269

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

(2) Letters of credit outstanding total $22.9 million and $16.5 million as of December 31, 2015 and September 30, 2015, respectively, which reduces amount available by the same amount.

(3) Uncommitted credit facilities, which require no commitment fees.

(4) Letters of credit outstanding total $731,000 and $731,000 as of December 31, 2015 and September 30, 2015, respectively, which reduces the amount available by the same amount.

On October 24, 2014, NJR entered into a $100 million uncommitted line of credit agreement, with Santander Bank, N.A., which expired on October 24, 2015.

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.

NJNG Long-term Debt

NJNG received $7.1 million and $7.2 million in December 2015 and 2014, 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.

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EMPLOYEE BENEFIT PLANS

3 Months Ended

Dec. 31, 2015

Compensation and Retirement Disclosure [Abstract]

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

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

	Pension						OPEB
	Three Months Ended						Three Months Ended
	December 31,						December 31,
(Thousands)	2015			2014			2015			2014
Service cost	$	1,898		$	1,871		$	1,130		$	1,063
Interest cost	2,836			2,550			1,564			1,435
Expected return on plan assets	(5,029		)	(4,272		)	(1,211		)	(1,244		)
Recognized actuarial loss	1,820			1,745			819			736
Prior service cost amortization	28			28			(91		)	(91		)
Net periodic benefit cost	$	1,553		$	1,922		$	2,211		$	1,899

The Company made a discretionary contribution of $30 million during the three months endedDecember 31, 2015, to improve the funded status of the pension plans based on current actuarial assumptions, which includes the most recent mortality table change. The Company does not expect to be required to make additional contributions to fund the pension plans over the next two 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. There were no discretionary contributions made during the three months endedDecember 31, 2014.

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INCOME TAXES

3 Months Ended

Dec. 31, 2015

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 three months endedDecember 31, 2015 and 2014, based on its analysis, the Company determined there was no need to recognize any liabilities associated with uncertain tax positions.

To calculate the estimated annual effective tax rate, NJR considers tax credits associated with solar and wind projects. For investment tax credits the estimate is based on 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. For production tax credits the estimate is based on the forecast of electricity produced during the current fiscal year based on the best information available at each reporting period. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

The effective tax rates for the three months endedDecember 31, 2015 and 2014, were 14.7 percent and 24.9 percent, respectively. The decreased tax rate is due primarily to a decrease in forecasted pre-tax income for the fiscal year ended September 30, 2016, compared to the prior fiscal year. Forecasted tax credits, net of deferred taxes, are $26.8 million and $27.1 million for fiscal 2016 and 2015, respectively. Even though forecasted tax credits are lower in fiscal 2016, there is a greater impact to the effective tax rate due to the lower forecasted earnings.

As of December 31, 2015, the Company has total state income tax net operating losses of approximately $222.6 million, which generally have a life of 20 years. The Company has recorded a deferred state tax asset of approximately $13 million on the Unaudited Condensed Consolidated Balance Sheets, reflecting the tax benefit associated with the loss carryforwards. In addition, as of December 31, 2015, the Company has recorded a valuation allowance of $271,000 because it believes that it is more likely than not that the state net operating losses related to CR&R and NJR will expire unused. As of September 30, 2015, the Company had total state income tax net operating losses of approximately $218.1 million, a deferred state tax asset of approximately $12.8 million and a valuation allowance of $176,000.

In addition, as of September 30, 2015, the Company had an ITC carryforward of approximately $22.1 million, all of which was generated in fiscal year 2015, and has a life of 20 years. The Company expects to utilize this entire carryforward.

In December 2015, the Consolidated Appropriations Act extended the 30 percent ITC for solar property that is under construction on or before December 31, 2019. The credit will decline to 26 percent for property under construction as of and during 2020 and to 20 percent for property under construction as of and during 2021. For any property that is under construction before 2022, but not placed in service before 2024 the energy credit is reduced to 10 percent. In addition, the Consolidated Appropriations Act retroactively extends the PTC for five years through December 31, 2019, with a gradual three year phase out for any project for which construction of the facility begins after December 31, 2016.

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COMMITMENTS AND CONTINGENT LIABILITIES

3 Months Ended

Dec. 31, 2015

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 October 2032, for the supply, storage and transportation of natural gas. These contracts include annual fixed charges of approximately $58.5 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 10 years. Demand charges are established by interstate storage and pipeline operators and are regulated by the FERC. These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and/or transport natural gas utilizing their respective assets.

Commitments as of December 31, 2015, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2016		2017		2018		2019		2020		Thereafter
NJRES:
Natural gas purchases	$	212,469	$	94,896	$	84,187	$	51,029	$	—	$	—
Storage demand fees	20,288		13,290		8,565		4,960		3,672		3,270
Pipeline demand fees	74,404		51,024		16,673		7,508		4,253		3,894
Sub-total NJRES	$	307,161	$	159,210	$	109,425	$	63,497	$	7,925	$	7,164
NJNG:
Natural gas purchases	$	41,962	$	63,953	$	39,885	$	40,976	$	43,775	$	98,948
Storage demand fees	21,815		25,328		15,871		11,079		5,345		—
Pipeline demand fees	36,684		67,858		93,474		90,226		89,459		783,107
Sub-total NJNG	$	100,461	$	157,139	$	149,230	$	142,281	$	138,579	$	882,055
Total(1)	$	407,622	$	316,349	$	258,655	$	205,778	$	146,504	$	889,219

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

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of five MGP sites, dating back to gas operations in the late 1800s and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the NJDEP, and 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 recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RA approved by the BPU. In September 2014, NJNG requested approval of its MGP expenditures incurred through June 2014 and to recover $8.5 million annually related to the SBC RA factor. The petition was approved by the BPU on May 19, 2015, with rates effective June 1, 2015. As of December 31, 2015, $18 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets.

NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent 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 $150.9 million to $242.1 million. NJNG's estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG's policy to accrue the lower end of the range. Accordingly, as of December 31, 2015, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $180.4 million on the Unaudited Condensed Consolidated Balance Sheets, based on the most likely amount. 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.

General

The Company is party to various other claims, legal actions and complaints arising in the ordinary course of business. In the Company's opinion, the ultimate disposition of these matters will not have a material effect on its financial condition, results of operations or cash flows.

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA

3 Months Ended

Dec. 31, 2015

Segment Reporting [Abstract]

BUSINESS SEGMENT AND OTHER OPERATIONS DATA

BUSINESS SEGMENT AND OTHER OPERATIONS DATA

NJR organizes its businesses based on a combination of factors including its products and its regulatory environment. As a result, the Company manages the businesses through the following reportable segments and other operations: the Natural Gas Distribution segment consists of regulated energy and off-system, capacity and storage management operations; the Energy Services segment consists of unregulated wholesale energy operations; the Clean Energy Ventures segment consists of capital investments in distributed power projects; the Midstream segment consists of NJR's investments in natural gas transportation and storage facilities; the Home Services and Other operations consist of heating, cooling and water appliance sales, installations 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
	December 31,
(Thousands)	2015			2014
Operating revenues
Natural Gas Distribution
External customers	$	151,606		$	208,727
Energy Services
External customers (1)	276,182			600,562
Intercompany	2,511			3,126
Clean Energy Ventures
External customers	7,794			6,235
Subtotal	438,093			818,650
Home Services and Other
External customers	8,676			8,600
Intercompany	897			411
Eliminations	(3,408		)	(3,537		)
Total	$	444,258		$	824,124
Depreciation and amortization
Natural Gas Distribution	$	11,238		$	10,545
Energy Services	23			22
Clean Energy Ventures	5,110			3,591
Midstream	1			2
Subtotal	16,372			14,160
Home Services and Other	227			238
Eliminations	(117		)	(12		)
Total	$	16,482		$	14,386
Interest income (2)
Natural Gas Distribution	$	68		$	90
Energy Services	72			—
Midstream	264			239
Subtotal	404			329
Home Services and Other	37			—
Eliminations	(371		)	(239		)
Total	$	70		$	90

(1) Includes sales to Canada, which accounted for 3.5 and 4.7 percent of total operating revenues during the three months endedDecember 31, 2015 and 2014.

(2) Included in other income, net on the Unaudited Condensed Consolidated Statements of Operations.

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Interest expense, net of capitalized interest
Natural Gas Distribution	$	4,588		$	4,609
Energy Services	208			513
Clean Energy Ventures	2,053			1,817
Midstream	42			250
Subtotal	6,891			7,189
Home Services and Other	—			6
Eliminations	(114		)	—
Total	$	6,777		$	7,195
Income tax provision (benefit)
Natural Gas Distribution	$	13,863		$	14,166
Energy Services	5,195			45,877
Clean Energy Ventures	(11,587		)	(19,721		)
Midstream	1,640			1,492
Subtotal	9,111			41,814
Home Services and Other	(288		)	(452		)
Eliminations	(466		)	(495		)
Total	$	8,357		$	40,867
Equity in earnings of affiliates
Midstream	$	3,545		$	3,775
Eliminations	(1,139		)	(980		)
Total	$	2,406		$	2,795
Net financial earnings
Natural Gas Distribution	$	30,570		$	28,186
Energy Services	10,014			16,436
Clean Energy Ventures	7,505			9,008
Midstream	2,344			2,120
Subtotal	50,433			55,750
Home Services and Other	(583		)	(592		)
Eliminations	(218		)	(49		)
Total	$	49,632		$	55,109
Capital expenditures
Natural Gas Distribution	$	49,040		$	36,748
Clean Energy Ventures	45,006			55,345
Subtotal	94,046			92,093
Home Services and Other	797			11
Total	$	94,843		$	92,104
Investments in equity investees
Midstream	$	2,846		$	547
Total	$	2,846		$	547

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

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Consolidated NFE	$	49,632		$	55,109
Less:
Unrealized (gain) on derivative instruments and related transactions	(1,135		)	(88,673		)
Effects of economic hedging related to natural gas inventory	3,813			(8,765		)
Tax adjustments	(1,693		)	29,227
Consolidated net income	$	48,647		$	123,320

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 when the gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical gas flows. Timing differences occur in two ways:

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

• Unrealized gains and losses of prior periods are reclassified as realized gains and losses when derivatives are settled in the same period as physical gas inventory movements occur.

NFE is a measure of the earnings based on eliminating these timing differences, to effectively match the earnings effects of the economic hedges with the physical sale of gas. Consequently, to reconcile between GAAP and NFE, current period unrealized gains and losses on the derivatives are excluded from NFE as a reconciling item. Additionally, realized derivative gains and losses are also included in current period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical gas flows. NJR also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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

(Thousands)	December 31, 2015			September 30, 2015
Assets at end of period:
Natural Gas Distribution	$	2,357,063		$	2,305,293
Energy Services	310,364			260,021
Clean Energy Ventures	597,897			504,885
Midstream	191,292			182,007
Subtotal	3,456,616			3,252,206
Home Services and Other	90,012			88,880
Intercompany assets(1)	(69,390		)	(56,729		)
Total	$	3,477,238		$	3,284,357

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

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RELATED PARTY TRANSACTIONS

3 Months Ended

Dec. 31, 2015

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. As of December 31, 2015, NJRES has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which will expire by October 31, 2020. NJRES had demand fees, net of eliminations, associated with Steckman Ridge of $685,000 and $484,000 during the three months endedDecember 31, 2015 and 2014, respectively, and demand fees payable of $376,000 and $375,000 as of December 31, 2015 and September 30, 2015, respectively.

In January 2010, NJNG entered into a 10-year agreement effective April 1, 2010, for 3 Bcf of firm storage capacity with Steckman Ridge. Under the terms of the agreement, NJNG incurs demand fees, at market rates, of approximately $9.3 million annually, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG's BGSS mechanism and are included in regulatory assets. During the three months endedDecember 31, 2015 and 2014, NJNG had demand fees, net of eliminations, associated with Steckman Ridge of $1.4 million for both periods and demand fees payable of $774,900 as of December 31, 2015 and September 30, 2015.

NJNG and NJRES have entered into various asset management agreements. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to NJRES. NJNG retains the right to purchase market priced gas or fixed price storage gas from NJRES. As of December 31, 2015, NJNG and NJRES had four asset management agreements with expiration dates ranging from March 2016 through March 2018.

In the fourth quarter of fiscal 2014, NJNG entered into a 15 year transportation precedent agreement for committed capacity of 180,000 dths per day with PennEast with an estimated service date of November 2017.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

3 Months Ended

Dec. 31, 2015

Accounting Policies [Abstract]

Available for Sale Securities

Available for Sale Securities

Included in available for sale securities on the Unaudited Condensed Consolidated Balance Sheets are certain investments in two publicly traded energy companies. Total unrealized gains associated with these investments are included as a part of accumulated other comprehensive income, a component of common stock equity. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

Loan Receivable

Loan Receivable

NJNG provides interest-free loans, with terms ranging from two to 10 years, to customers that elect to purchase and install certain energy efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at net present value on the Unaudited Condensed Consolidated Balance Sheets. The Company has recorded $7 million and $6.2 million in other current assets and $39.2 million and $36.2 million in other noncurrent assets as of December 31, 2015 and September 30, 2015, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans.

NJR's policy is to establish an allowance for doubtful accounts when loan balances are in arrears for more than 60 days. As of December 31, 2015 and September 30, 2015, there was no allowance for doubtful accounts established for the SAVEGREEN loans.

Recent Updates to the Accounting Standards Codification

Recent Updates to the Accounting Standards Codification

Revenue

In May 2014, the FASB issued ASU No. 2014-09, and added Topic 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries, jurisdictions and capital markets. In August 2015, the FASB issued ASU No. 2015-14, which defers the implementation of the new guidance for one year. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Upon adoption, the guidance will be applied on a full or modified retrospective basis. The Company is currently evaluating the provisions of ASC 606 to understand the impact, if any, to its financial position, results of operations and cash flows upon adoption.

Stock Compensation

In June 2014, the FASB issued ASU No. 2014-12, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for performance awards when the terms of the award provide that a performance target could be achieved after the requisite service period. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. The Company does not expect this standard to have any impact to its financial position, results of operations and cash flows upon adoption.

Consolidation

In February 2015, the FASB issued ASU No. 2015-02, an amendment to ASC 810, Consolidation, which changes the consolidation analysis required under GAAP and reevaluates whether limited partnerships and similar entities must be consolidated. The new guidance will become effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendment will be applied on a full or modified retrospective basis. The Company is currently evaluating the provisions of ASU No. 2015-02 to understand the impact, if any, on its financial position, results of operations and cash flows upon adoption.

Interest

In April 2015, the FASB issued ASU No. 2015-03, an amendment to ASC 835, Interest - Imputation of Interest, which simplifies the presentation of debt issuance costs by requiring them to be presented in the balance sheet as a deduction from the carrying amount of the liability. The amendments do not affect the recognition and measurement guidance for debt issuance costs. In August 2015, the FASB issued ASU No. 2015-15, which clarified that the amendments contained within ASU No. 2015-03 do not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The amended guidance becomes effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendment will be applied on a retrospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations and cash flows upon adoption.

Intangibles

In April 2015, the FASB issued ASU No. 2015-05, an amendment to ASC 350, Intangibles - Goodwill and Other - Internal-Use Software, which clarifies the accounting for fees in a cloud computing arrangement. The amendments provide guidance on how an entity should evaluate the accounting for fees paid in a cloud computing arrangement to determine whether an arrangement includes the sale or license of software. The amended guidance becomes effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. Upon adoption, the amendments can be applied on a prospective or retrospective basis. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Inventory

In July 2015, the FASB issued ASU No. 2015-11, an amendment to ASC 330, Inventory, which requires entities to measure most inventory “at the lower of cost and net realizable value,” thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. The guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations and cash flows upon adoption.

Income Taxes

In November 2015, the FASB issued ASU 2015-17, an amendment to ASC 740, Income Taxes, to simplify the balance sheet presentation of deferred income taxes. The update requires entities to present all deferred tax assets and liabilities as noncurrent. The Company elected to early adopt the amended guidance effective October 1, 2015, and applied the new provisions retrospectively. Accordingly, the following amounts on the Unaudited Condensed Consolidated Balance Sheets, as of September 30, 2015, have been adjusted:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Deferred taxes (current)	$	56,296	$	(56,296	)	$	—
Total current assets	$	544,511	$	(56,296	)	$	488,215
Other noncurrent assets	$	60,300	$	1,615		$	61,915
Total noncurrent assets	$	666,266	$	1,615		$	667,881
Total assets	$	3,339,038	$	(54,681	)	$	3,284,357
Capitalization and Liabilities
Deferred income taxes	$	499,616	$	(54,681	)	$	444,935
Total noncurrent liabilities	$	952,387	$	(54,681	)	$	897,706
Total capitalization and liabilities	$	3,339,038	$	(54,681	)	$	3,284,357

There was no additional impact to the Unaudited Condensed Consolidated Statements of Operations or the Unaudited Condensed Consolidated Statements of Cash Flows.

Derivative Instruments

The Company is subject to commodity price risk due to fluctuations in the market price of natural gas, SRECs, and electricity. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs, and electricity. In addition, the Company may utilize foreign currency derivatives as cash flow hedges of Canadian dollar denominated gas purchases and/or sales. 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 NJR's derivative instruments, see Note 5. Fair Value.

Since NJRES chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, 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 U.S. dollar. NJRES may utilize 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 may be used to hedge future forecasted cash payments associated with transportation and storage contracts along with purchases of natural gas. The Company designates these foreign currency derivatives as cash flow hedges of that exposure, and expects the hedge relationship to be highly effective throughout the term. Since NJRES designates its foreign exchange contracts as cash flow hedges, changes in fair value of the effective portion of the hedge are recorded in OCI. When the foreign exchange contracts are settled and the related purchases are recognized in income, realized gains and (losses) are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

As a result of NJRES entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over 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. NJNG has received regulatory approval to defer and to recover these amounts through future BGSS rates as an increase or decrease to the cost of natural gas in NJNG's tariff for gas service.

The Company elects NPNS accounting treatment on all physical commodity contracts at NJNG. These contracts are accounted for on an accrual basis. Accordingly, physical purchases are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered. The average cost of natural gas is amortized in current period earnings based on the current BPU BGSS factor and therm sales.

NJRCEV hedges certain of its expected production of SRECs through forward and futures contracts. The contracts require the Company to physically deliver the SRECs upon settlement. The Company elects NPNS accounting treatment on all SREC forward and futures contracts it enters into during the period. NJRCEV recognizes the related revenue upon transfer of the SREC certificate to the counterparty.

In an April 2014 BPU Order, NJNG received regulatory approval to enter into interest rate risk management transactions related to long-term debt securities. On June 1, 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with the forecasted $125 million debt issuance expected in May 2018. This forecasted debt issuance coincides with the maturity of NJNG's existing $125 million, 5.6 percent notes due May 15, 2018. The change in fair value of NJNG's treasury lock agreement is recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets since NJNG believes that the market value upon settlement will be reflected in future rates. Upon settlement, any gain or loss will be amortized in earnings over the life of the future debt issuance.

Fair Value Hierarchy

Fair Value Hierarchy

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

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

Level 2 Other significant observable inputs such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG's treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. 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 were 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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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

3 Months Ended

Dec. 31, 2015

Accounting Policies [Abstract]

Summary of Gas in Storage

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

	December 31, 2015				September 30, 2015
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJRES		$	119,401	62.0		$	93,696	44.6
NJNG		70,506		23.0		70,209		21.4
Total		$	189,907	85.0		$	163,905	66.0

Accounts Receivable by Subsidiary

Customer accounts receivable include outstanding billings from the following subsidiaries as of:

(Thousands)	December 31, 2015				September 30, 2015
NJRES	$	113,332	67	%	$	107,461	69	%
NJNG (1)	49,664		29		41,130		26
NJRCEV	1,471		1		1,084		1
NJRHS and other	4,262		3		5,598		4
Total	$	168,729	100	%	$	155,273	100	%

(1) Does not include unbilled revenues of $19.9 million and $6.4 million as of December 31, 2015 and September 30, 2015, respectively.

Schedule of Retrospective Application of New Accounting Standard

In November 2015, the FASB issued ASU 2015-17, an amendment to ASC 740, Income Taxes, to simplify the balance sheet presentation of deferred income taxes. The update requires entities to present all deferred tax assets and liabilities as noncurrent. The Company elected to early adopt the amended guidance effective October 1, 2015, and applied the new provisions retrospectively. Accordingly, the following amounts on the Unaudited Condensed Consolidated Balance Sheets, as of September 30, 2015, have been adjusted:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Deferred taxes (current)	$	56,296	$	(56,296	)	$	—
Total current assets	$	544,511	$	(56,296	)	$	488,215
Other noncurrent assets	$	60,300	$	1,615		$	61,915
Total noncurrent assets	$	666,266	$	1,615		$	667,881
Total assets	$	3,339,038	$	(54,681	)	$	3,284,357
Capitalization and Liabilities
Deferred income taxes	$	499,616	$	(54,681	)	$	444,935
Total noncurrent liabilities	$	952,387	$	(54,681	)	$	897,706
Total capitalization and liabilities	$	3,339,038	$	(54,681	)	$	3,284,357

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REGULATION (Tables)

3 Months Ended

Dec. 31, 2015

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)	December 31, 2015		September 30, 2015
Regulatory assets-current
Conservation Incentive Program	$	819	$	—
New Jersey Clean Energy Program	12,907		14,293
Derivatives at fair value, net	13,013		9,965
Total current regulatory assets	$	26,739	$	24,258
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	17,963	$	18,886
Liability for future expenditures	180,400		180,400
Deferred income taxes	18,233		17,460
Derivatives at fair value, net	1,861		5,153
SAVEGREEN	27,968		26,882
Postemployment and other benefit costs	138,491		140,636
Deferred Superstorm Sandy costs	15,201		15,201
Conservation Incentive Program	17,552		—
Other noncurrent regulatory assets	5,663		5,537
Total noncurrent regulatory assets	$	423,332	$	410,155
Regulatory liability-current
Conservation Incentive Program	$	—	$	5,167
Overrecovered gas costs	1,091		6,987
Total current regulatory liabilities	$	1,091	$	12,154
Regulatory liabilities-noncurrent
Cost of removal obligation	$	48,683	$	54,880
New Jersey Clean Energy Program	14,512		11,956
Other noncurrent regulatory liabilities	116		697
Total noncurrent regulatory liabilities	$	63,311	$	67,533

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DERIVATIVE INSTRUMENTS (Tables)

3 Months Ended

Dec. 31, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Assets and Liabilities

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
			December 31, 2015						September 30, 2015
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives designated as hedging instruments:
NJRES:
Foreign currency contracts	Derivatives - current		$	—		$	52		$	—		$	—
Fair value of derivatives designated as hedging instruments			$	—		$	52		$	—		$	—
Derivatives not designated as hedging instruments:
NJNG:
Financial commodity contracts	Derivatives - current		$	820		$	13,819		$	207		$	10,163
	Derivatives - noncurrent		—			—			—			925
Interest rate contracts	Derivatives - noncurrent		$	—		$	1,861		$	—		$	4,228
NJRES:
Physical forward commodity contracts	Derivatives - current		$	9,844		$	22,333		$	4,854		$	9,281
	Derivatives - noncurrent		3,045			650			1,718			—
Financial commodity contracts	Derivatives - current		48,314			15,675			35,682			13,347
	Derivatives - noncurrent		696			95			2,626			386
Fair value of derivatives not designated as hedging instruments			$	62,719		$	54,433		$	45,087		$	38,330
Total fair value of derivatives			$	62,719		$	54,485		$	45,087		$	38,330

Offsetting Assets

The following table summarizes the reported gross amounts, the amounts that NJR has the right to offset but elects not to, financial collateral, as well as the net amounts NJR could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(Thousands)	Amounts Presented in Balance Sheets (1)			Offsetting Derivative Instruments (2)				Financial Collateral Received/Pledged (3)				Net Amounts (4)
As of December 31, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	12,889		$	(809	)		$	(1,000	)		$	11,080
Financial commodity contracts		49,010			(13,004		)		(25,136		)		10,870
Total NJRES		$	61,899		$	(13,813	)		$	(26,136	)		$	21,950
NJNG
Financial commodity contracts		$	820		$	(820	)		$	—			$	—
Total NJNG		820			(820		)		—				—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	22,983		$	(809	)		$	(1,200	)		$	20,974
Financial commodity contracts		15,770			(13,004		)		(2,766		)		—
Foreign currency contracts		52			—				—				52
Total NJRES		$	38,805		$	(13,813	)		$	(3,966	)		$	21,026
NJNG
Financial commodity contracts		$	13,819		$	(820	)		$	(12,999	)		$	—
Interest rate contracts		$	1,861		$	—			$	—			$	1,861
Total NJNG		$	15,680		$	(820	)		$	(12,999	)		$	1,861
As of September 30, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	6,562		$	(1,326	)		$	—			$	5,236
Financial commodity contracts		38,308			(13,734		)		3,841				28,415
Total NJRES		$	44,870		$	(15,060	)		$	3,841			$	33,651
NJNG
Financial commodity contracts		$	207		$	(207	)		$	—			$	—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	9,271		$	(1,326	)		$	(1,200	)		$	6,745
Financial commodity contracts		13,733			(13,733		)		—				—
Total NJRES		$	23,004		$	(15,059	)		$	(1,200	)		$	6,745
NJNG
Financial commodity contracts		$	11,088		$	(207	)		$	(10,881	)		$	—
Interest rate contracts		4,228			—				—				4,228
Total NJNG		$	15,316		$	(207	)		$	(10,881	)		$	4,228

(1) Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.

(2) Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.

(3) Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties.

(4) Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.

Offsetting Liabilities

The following table summarizes the reported gross amounts, the amounts that NJR has the right to offset but elects not to, financial collateral, as well as the net amounts NJR could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(Thousands)	Amounts Presented in Balance Sheets (1)			Offsetting Derivative Instruments (2)				Financial Collateral Received/Pledged (3)				Net Amounts (4)
As of December 31, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	12,889		$	(809	)		$	(1,000	)		$	11,080
Financial commodity contracts		49,010			(13,004		)		(25,136		)		10,870
Total NJRES		$	61,899		$	(13,813	)		$	(26,136	)		$	21,950
NJNG
Financial commodity contracts		$	820		$	(820	)		$	—			$	—
Total NJNG		820			(820		)		—				—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	22,983		$	(809	)		$	(1,200	)		$	20,974
Financial commodity contracts		15,770			(13,004		)		(2,766		)		—
Foreign currency contracts		52			—				—				52
Total NJRES		$	38,805		$	(13,813	)		$	(3,966	)		$	21,026
NJNG
Financial commodity contracts		$	13,819		$	(820	)		$	(12,999	)		$	—
Interest rate contracts		$	1,861		$	—			$	—			$	1,861
Total NJNG		$	15,680		$	(820	)		$	(12,999	)		$	1,861
As of September 30, 2015:
Derivative assets:
NJRES
Physical forward commodity contracts		$	6,562		$	(1,326	)		$	—			$	5,236
Financial commodity contracts		38,308			(13,734		)		3,841				28,415
Total NJRES		$	44,870		$	(15,060	)		$	3,841			$	33,651
NJNG
Financial commodity contracts		$	207		$	(207	)		$	—			$	—
Derivative liabilities:
NJRES
Physical forward commodity contracts		$	9,271		$	(1,326	)		$	(1,200	)		$	6,745
Financial commodity contracts		13,733			(13,733		)		—				—
Total NJRES		$	23,004		$	(15,059	)		$	(1,200	)		$	6,745
NJNG
Financial commodity contracts		$	11,088		$	(207	)		$	(10,881	)		$	—
Interest rate contracts		4,228			—				—				4,228
Total NJNG		$	15,316		$	(207	)		$	(10,881	)		$	4,228

(1) Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.

(2) Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.

(3) Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties.

(4) Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.

Effect of Derivative Instruments on Consolidated Statements of Operations

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
		December 31,
Derivatives not designated as hedging instruments:		2015			2014
NJRES:
Physical commodity contracts	Operating revenues	$	11,874		$	16,091
Physical commodity contracts	Gas purchases	(21,237		)	(19,856		)
Financial commodity contracts	Gas purchases	41,276			117,721
Total unrealized and realized gains		$	31,913		$	113,956

Effect of Derivative Instruments Designated as Cash Flow Hedges on OCI

The following table reflects the effect of derivative instruments designated as cash flow hedges on OCI as of December 31:

(Thousands)	Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)						Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)					Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
	Three Months Ended						Three Months Ended					Three Months Ended
	December 31,						December 31,					December 31,
Derivatives in cash flow hedging relationships:	2015			2014			2015		2014			2015		2014
Foreign currency contracts	$	(64	)	$	(24	)	$	12	$	(25	)	$	—	$	—

Schedule of Outstanding Long (Short) Derivatives

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

		Volume (Bcf)
		December 31, 2015		September 30, 2015
NJNG	Futures(1)	19.5		25.8
NJRES	Futures	(120.8	)	(91.1	)
	Options	5.8		1.2
	Physical	111.7		48.2

(1) Not included is the notional amount of $125 million related to NJNG’s treasury lock agreement.

Schedule of Broker Margin Accounts by Company

The balances by company, are as follows:

(Thousands)	Balance Sheet Location	December 31, 2015			September 30, 2015
NJNG	Broker margin - Current assets	$	17,487		$	12,990
NJRES	Broker margin - Current assets	$	3,847		$	—
	Broker margin - Current (liabilities)	$	(19,307	)	$	(4,103	)

Summary of Gross Credit Exposures

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of December 31, 2015. 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 and NJRCEV residential solar installations.

(Thousands)	Gross Credit Exposure
Investment grade		$	99,405
Noninvestment grade		9,693
Internally rated investment grade		22,507
Internally rated noninvestment grade		7,815
Total		$	139,420

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FAIR VALUE (Tables)

3 Months Ended

Dec. 31, 2015

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)	December 31, 2015		September 30, 2015
Carrying value (1)	$	807,845	$	807,845
Fair market value	$	809,107	$	817,319

(1) Excludes capital leases of $51.3 million and $46.9 million as of December 31, 2015 and September 30, 2015, respectively.

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 December 31, 2015:
Assets:
Physical forward commodity contracts		$	—		$	12,889		$	—	$	12,889
Financial derivative contracts - natural gas		49,830			—			—		49,830
Available for sale equity securities - energy industry(1)		65,790			—			—		65,790
Other (2)		1,809			—			—		1,809
Total assets at fair value		$	117,429		$	12,889		$	—	$	130,318
Liabilities:
Physical forward commodity contracts		$	—		$	22,983		$	—	$	22,983
Financial commodity contracts - natural gas		29,589			—			—		29,589
Financial commodity contracts - foreign exchange		—			52			—		52
Interest rate contracts		—			1,861			—		1,861
Total liabilities at fair value		$	29,589		$	24,896		$	—	$	54,485
As of September 30, 2015:
Assets:
Physical forward commodity contracts		$	—		$	6,572		$	—	$	6,572
Financial derivative contracts - natural gas		38,515			—			—		38,515
Available for sale equity securities - energy industry(1)		59,475			—			—		59,475
Other (2)		1,572			—			—		1,572
Total assets at fair value		$	99,562		$	6,572		$	—	$	106,134
Liabilities:
Physical forward commodity contracts		$	—		$	9,281		$	—	$	9,281
Financial commodity contracts - natural gas		24,821			—			—		24,821
Interest rate contracts		—			4,228			—		4,228
Total liabilities at fair value		$	24,821		$	13,509		$	—	$	38,330

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

(2) Includes various money market funds in Level 1.

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INVESTMENTS IN EQUITY INVESTEES (Tables)

3 Months Ended

Dec. 31, 2015

Investments, All Other Investments [Abstract]

Schedule of Equity Method Investments

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

(Thousands)	December 31, 2015		September 30, 2015
Steckman Ridge (1)	$	125,058	$	125,649
PennEast	9,222		6,353
Total	$	134,280	$	132,002

(1) Includes loans with a total outstanding principal balance of $70.4 million for both December 31, 2015 and September 30, 2015. The loans accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

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EARNINGS PER SHARE (Tables)

3 Months Ended

Dec. 31, 2015

Earnings Per Share [Abstract]

Schedule of Earnings Per Share Basic and Diluted

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

	Three Months Ended
	December 31,
(Thousands, except per share amounts)	2015		2014
Net income, as reported	$	48,647	$	123,320
Basic earnings per share
Weighted average shares of common stock outstanding-basic	85,675		84,552
Basic earnings per common share	$0.57		$1.46
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	85,675		84,552
Incremental shares (1)	1,001		1,022
Weighted average shares of common stock outstanding-diluted	86,676		85,574
Diluted earnings per common share (2)	$0.56		$1.44

(1) Incremental shares consist primarily of stock awards and performance shares.

(2) There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three months endedDecember 31, 2015, and 2014.

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COMMON STOCK EQUITY (Tables)

3 Months Ended

Dec. 31, 2015

Equity [Abstract]

Changes in Common Stock Equity

Changes in common stock equity during the three months endedDecember 31, 2015, are as follows:

(Thousands)	Number of Shares		Common Stock		Premium on Common Stock			Accumulated Other Comprehensive (Loss) Income				Treasury Stock And Other			Retained Earnings			Total
Balance at September 30, 2015	85,531		$	220,838	$	209,931			$	(9,394	)	$	(92,164	)	$	777,745		$	1,106,956
Net income															48,647			48,647
Other comprehensive income									3,924									3,924
Common stock issued:
Incentive plan	286		717		4,782													5,499
Dividend reinvestment plan	127				(1,339		)					5,144						3,805
Cash dividend declared ($.24 per share)															(20,594		)	(20,594		)
Treasury stock and other	(135	)			(23		)					(4,270		)				(4,293		)
Balance at December 31, 2015	85,809		$	221,555	$	213,351			$	(5,470	)	$	(91,290	)	$	805,798		$	1,143,944

Components of Accumulated Other Comprehensive Income, Net of Tax

The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects:

(Thousands)	Available for Sale Securities		Cash Flow Hedges				Postemployment Benefit Obligation				Total
Balance at September 30, 2015	$	6,385	$	—			$	(15,779	)		$	(9,394	)
Other comprehensive income, net of tax
Other comprehensive income (loss), before reclassifications, net of tax of ($2,614), $23, $0, ($2,591)	3,701		(41		)		—				3,660
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, ($4), ($174), ($178)	—		8			(1)	256			(2)	264
Net current-period other comprehensive income, net of tax of ($2,614), $19, $(174), $(2,769)	3,701		(33		)		256				3,924
Balance at December 31, 2015	$	10,086	$	(33	)		$	(15,523	)		$	(5,470	)
Balance at September 30, 2014	$	4,782	$	(93	)		$	(10,283	)		$	(5,594	)
Other comprehensive income (loss), net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(455), $9, $0, $(446)	659		(15		)		—				644
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $9, $(169), $(160)	—		(16		)	(1)	247			(2)	231
Net current-period other comprehensive income (loss), net of tax of $(455), $18, $(169), $(606)	659		(31		)		247				875
Balance at December 31, 2014	$	5,441	$	(124	)		$	(10,036	)		$	(4,719	)

(1) Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

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

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DEBT (Tables)

3 Months Ended

Dec. 31, 2015

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

A summary of NJR's credit facility and NJNG's commercial paper program and credit facility are as follows:

(Thousands)	December 31, 2015			September 30, 2015			Expiration Dates
NJR
Bank revolving credit facilities(1)	$	425,000		$	425,000		September 2020
Notes outstanding at end of period	$	135,000		$	39,350
Weighted average interest rate at end of period	1.24		%	1.17		%
Amount available at end of period (2)	$	267,055		$	369,176
Bank revolving credit facilities(3)	$	—		$	100,000		October 2015
Amount available at end of period	$	—		$	100,000
NJNG
Bank revolving credit facilities (1)	$	250,000		$	250,000		May 2019
Commercial paper outstanding at end of period	$	76,000		$	27,000
Weighted average interest rate at end of period	.28		%	.20		%
Amount available at end of period (4)	$	173,269		$	222,269

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

(2) Letters of credit outstanding total $22.9 million and $16.5 million as of December 31, 2015 and September 30, 2015, respectively, which reduces amount available by the same amount.

(3) Uncommitted credit facilities, which require no commitment fees.

(4) Letters of credit outstanding total $731,000 and $731,000 as of December 31, 2015 and September 30, 2015, respectively, which reduces the amount available by the same amount.

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EMPLOYEE BENEFIT PLANS (Tables)

3 Months Ended

Dec. 31, 2015

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						Three Months Ended
	December 31,						December 31,
(Thousands)	2015			2014			2015			2014
Service cost	$	1,898		$	1,871		$	1,130		$	1,063
Interest cost	2,836			2,550			1,564			1,435
Expected return on plan assets	(5,029		)	(4,272		)	(1,211		)	(1,244		)
Recognized actuarial loss	1,820			1,745			819			736
Prior service cost amortization	28			28			(91		)	(91		)
Net periodic benefit cost	$	1,553		$	1,922		$	2,211		$	1,899

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COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

3 Months Ended

Dec. 31, 2015

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment

Commitments as of December 31, 2015, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2016		2017		2018		2019		2020		Thereafter
NJRES:
Natural gas purchases	$	212,469	$	94,896	$	84,187	$	51,029	$	—	$	—
Storage demand fees	20,288		13,290		8,565		4,960		3,672		3,270
Pipeline demand fees	74,404		51,024		16,673		7,508		4,253		3,894
Sub-total NJRES	$	307,161	$	159,210	$	109,425	$	63,497	$	7,925	$	7,164
NJNG:
Natural gas purchases	$	41,962	$	63,953	$	39,885	$	40,976	$	43,775	$	98,948
Storage demand fees	21,815		25,328		15,871		11,079		5,345		—
Pipeline demand fees	36,684		67,858		93,474		90,226		89,459		783,107
Sub-total NJNG	$	100,461	$	157,139	$	149,230	$	142,281	$	138,579	$	882,055
Total(1)	$	407,622	$	316,349	$	258,655	$	205,778	$	146,504	$	889,219

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

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA (Tables)

3 Months Ended

Dec. 31, 2015

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
	December 31,
(Thousands)	2015			2014
Operating revenues
Natural Gas Distribution
External customers	$	151,606		$	208,727
Energy Services
External customers (1)	276,182			600,562
Intercompany	2,511			3,126
Clean Energy Ventures
External customers	7,794			6,235
Subtotal	438,093			818,650
Home Services and Other
External customers	8,676			8,600
Intercompany	897			411
Eliminations	(3,408		)	(3,537		)
Total	$	444,258		$	824,124
Depreciation and amortization
Natural Gas Distribution	$	11,238		$	10,545
Energy Services	23			22
Clean Energy Ventures	5,110			3,591
Midstream	1			2
Subtotal	16,372			14,160
Home Services and Other	227			238
Eliminations	(117		)	(12		)
Total	$	16,482		$	14,386
Interest income (2)
Natural Gas Distribution	$	68		$	90
Energy Services	72			—
Midstream	264			239
Subtotal	404			329
Home Services and Other	37			—
Eliminations	(371		)	(239		)
Total	$	70		$	90

(1) Includes sales to Canada, which accounted for 3.5 and 4.7 percent of total operating revenues during the three months endedDecember 31, 2015 and 2014.

(2) Included in other income, net on the Unaudited Condensed Consolidated Statements of Operations.

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Interest expense, net of capitalized interest
Natural Gas Distribution	$	4,588		$	4,609
Energy Services	208			513
Clean Energy Ventures	2,053			1,817
Midstream	42			250
Subtotal	6,891			7,189
Home Services and Other	—			6
Eliminations	(114		)	—
Total	$	6,777		$	7,195
Income tax provision (benefit)
Natural Gas Distribution	$	13,863		$	14,166
Energy Services	5,195			45,877
Clean Energy Ventures	(11,587		)	(19,721		)
Midstream	1,640			1,492
Subtotal	9,111			41,814
Home Services and Other	(288		)	(452		)
Eliminations	(466		)	(495		)
Total	$	8,357		$	40,867
Equity in earnings of affiliates
Midstream	$	3,545		$	3,775
Eliminations	(1,139		)	(980		)
Total	$	2,406		$	2,795
Net financial earnings
Natural Gas Distribution	$	30,570		$	28,186
Energy Services	10,014			16,436
Clean Energy Ventures	7,505			9,008
Midstream	2,344			2,120
Subtotal	50,433			55,750
Home Services and Other	(583		)	(592		)
Eliminations	(218		)	(49		)
Total	$	49,632		$	55,109
Capital expenditures
Natural Gas Distribution	$	49,040		$	36,748
Clean Energy Ventures	45,006			55,345
Subtotal	94,046			92,093
Home Services and Other	797			11
Total	$	94,843		$	92,104
Investments in equity investees
Midstream	$	2,846		$	547
Total	$	2,846		$	547

Reconciliation of Consolidated NFE to Consolidated Net Income

A reconciliation of consolidated NFE to consolidated net income is as follows:

	Three Months Ended
	December 31,
(Thousands)	2015			2014
Consolidated NFE	$	49,632		$	55,109
Less:
Unrealized (gain) on derivative instruments and related transactions	(1,135		)	(88,673		)
Effects of economic hedging related to natural gas inventory	3,813			(8,765		)
Tax adjustments	(1,693		)	29,227
Consolidated net income	$	48,647		$	123,320

Reconciliation of Assets from Segment to Consolidated

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

(Thousands)	December 31, 2015			September 30, 2015
Assets at end of period:
Natural Gas Distribution	$	2,357,063		$	2,305,293
Energy Services	310,364			260,021
Clean Energy Ventures	597,897			504,885
Midstream	191,292			182,007
Subtotal	3,456,616			3,252,206
Home Services and Other	90,012			88,880
Intercompany assets(1)	(69,390		)	(56,729		)
Total	$	3,477,238		$	3,284,357

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

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NATURE OF THE BUSINESS (Details) shares in Thousands	3 Months Ended
	Dec. 31, 2015 subsidiary customer	Sep. 29, 2015 shares
Common Units [Member]
Nature of Business [Line Items]
Ownership interest exchanged (in shares) | shares		1,840
Steckman Ridge [Member]
Nature of Business [Line Items]
Equity method investment, ownership percentage	50.00%
PennEast [Member]
Nature of Business [Line Items]
Equity method investment, ownership percentage	20.00%
NJNG [Member]
Nature of Business [Line Items]
Total retail customers | customer	516,300
NJR Retail Holdings Corporation [Member]
Nature of Business [Line Items]
Number of principal subsidiaries | subsidiary	2

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - GAS IN STORAGE (Details) $ in Thousands	Dec. 31, 2015 USD ($) Bcf	Sep. 30, 2015 USD ($) Bcf
Inventory [Line Items]
Gas in Storage | $	$ 189,907	$ 163,905
Bcf | Bcf	85.0	66.0
NJRES [Member]
Inventory [Line Items]
Gas in Storage | $	$ 119,401	$ 93,696
Bcf | Bcf	62.0	44.6
NJNG [Member]
Inventory [Line Items]
Gas in Storage | $	$ 70,506	$ 70,209
Bcf | Bcf	23.0	21.4

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SALES TAX ACCOUNTING (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Sales tax	$ 7.2	$ 11.8

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - AVAILABLE FOR SALE SECURITIES (Details) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended	12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Sep. 29, 2015
Investment [Line Items]
Available for sale securities	$ 65,790	$ 59,475
Total unrealized gains	6,800	7,500
Accumulated other comprehensive income, available-for-sale securities adjustment, net of tax	4,000	4,400
Common Stock [Member]
Investment [Line Items]
Available for sale securities	9,408	10,100
Common Units [Member]
Investment [Line Items]
Available for sale securities	56,400	49,400
Ownership interest exchanged (in shares)			1,840
Unrealized gain	10,300	3,300
Unrealized gain, net of tax	$ 6,100	$ 1,900

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - COMMON STOCK SPLIT (Details)	Jan. 20, 2015	Dec. 31, 2015 shares	Sep. 30, 2015 shares	Mar. 03, 2015 shares	Mar. 02, 2015 shares
Accounting Policies [Abstract]
Stock split ratio	2
Common stock, shares outstanding		85,809,094	85,531,423	85,400,000	42,700,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - CUSTOMER ACCOUNTS RECEIVABLE (Details) - USD ($) $ in Thousands		Dec. 31, 2015	Sep. 30, 2015
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed		$ 168,729	$ 155,273
Receivable by subsidiary, percentage		100.00%	100.00%
Unbilled revenues		$ 19,883	$ 6,372
NJRES [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed		$ 113,332	$ 107,461
Receivable by subsidiary, percentage		67.00%	69.00%
NJNG [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed	[1]	$ 49,664	$ 41,130
Receivable by subsidiary, percentage	[1]	29.00%	26.00%
NJRCEV [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed		$ 1,471	$ 1,084
Receivable by subsidiary, percentage		1.00%	1.00%
NJRHS and Other [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed		$ 4,262	$ 5,598
Receivable by subsidiary, percentage		3.00%	4.00%

[1] Does not include unbilled revenues of $19.9 million and $6.4 million as of December 31, 2015 and September 30, 2015, respectively.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - LOAN RECEIVABLE (Details) - USD ($)	3 Months Ended
	Dec. 31, 2015	Sep. 30, 2015
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loans receivable in other current assets	$ 7,000,000	$ 6,200,000
Loans receivable in other noncurrent assets	$ 39,200,000	36,200,000
Threshold period in establishing allowance for doubtful accounts	60 days
Allowance for doubtful accounts	$ 0	$ 0
Minimum [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loan term	2 years
Maximum [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loan term	10 years

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - NEW ACCOUNTING STANDARD (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Sep. 30, 2015
Assets
Deferred taxes (current)		$ 0
Total current assets	$ 588,939	488,215
Other noncurrent assets	65,057	61,915
Total noncurrent assets	692,200	667,881
Total assets	3,477,238	3,284,357
Capitalization and Liabilities
Deferred income taxes	491,522	444,935
Total noncurrent liabilities	910,106	897,706
Total capitalization and liabilities	$ 3,477,238	3,284,357
As Previously Reported [Member]
Assets
Deferred taxes (current)		56,296
Total current assets		544,511
Other noncurrent assets		60,300
Total noncurrent assets		666,266
Total assets		3,339,038
Capitalization and Liabilities
Deferred income taxes		499,616
Total noncurrent liabilities		952,387
Total capitalization and liabilities		3,339,038
Effect of Change [Member]
Assets
Deferred taxes (current)		(56,296)
Total current assets		(56,296)
Other noncurrent assets		1,615
Total noncurrent assets		1,615
Total assets		(54,681)
Capitalization and Liabilities
Deferred income taxes		(54,681)
Total noncurrent liabilities		(54,681)
Total capitalization and liabilities		$ (54,681)

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REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Sep. 30, 2015
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	$ 26,739	$ 24,258
Regulatory assets-noncurrent	423,332	410,155
Regulatory liability-current	1,091	12,154
Regulatory liabilities-noncurrent	63,311	67,533
Conservation Incentive Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liability-current	0	5,167
Overrecovered Gas Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liability-current	1,091	6,987
Cost of Removal Obligation [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	48,683	54,880
New Jersey Clean Energy Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	14,512	11,956
Other Noncurrent Regulatory Liabilities [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	116	697
Conservation Incentive Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	819	0
Regulatory assets-noncurrent	17,552	0
New Jersey Clean Energy Program [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	12,907	14,293
Derivative at Fair Value, Net [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	13,013	9,965
Regulatory assets-noncurrent	1,861	5,153
Environmental Remediation Costs Expended, Net of Recoveries [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	17,963	18,886
Environmental Remediation Costs Liability for Future Expenditures [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	180,400	180,400
Deferred Income Taxes [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	18,233	17,460
SAVEGREEN [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	27,968	26,882
Postemployment and Other Benefit Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	138,491	140,636
Deferred Superstorm Sandy Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	15,201	15,201
Other Noncurrent Regulatory Assets [Member]
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	$ 5,663	$ 5,537

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REGULATION - REGULATORY FILINGS (Details) - USD ($) $ in Millions	Dec. 24, 2015	Nov. 13, 2015	Oct. 27, 2015	Oct. 15, 2015
Schedule of Regulatory [Line Items]
Increase in base tariff rates		$ 147.6
NJ RISE Program [Member]
Schedule of Regulatory [Line Items]
Increase (decrease) in approved rate, percentage				0.07%
BGSS [Member]
Schedule of Regulatory [Line Items]
Increase (decrease) in approved rate, percentage			(17.00%)
Annual bill credits issued			$ 76.0
NJCEP [Member]
Schedule of Regulatory [Line Items]
Increase (decrease) in approved rate, percentage	(0.80%)

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DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Sep. 30, 2015	Jun. 01, 2015
Derivatives, Fair Value [Line Items]
Benchmark interest rate			3.26%
Notional amount of foreign currency derivatives			$ 125,000
Fair Value
Derivative assets, current	$ 58,978	$ 40,743
Derivative liabilities, current	51,879	32,791
Derivative assets, noncurrent	3,741	4,334
Derivative liabilities, noncurrent	2,606	5,529
Derivative assets	62,719	45,087
Derivative liabilities	54,485	38,330
Designated as Hedging Instrument [Member] | NJRES [Member] | Foreign Currency Contracts [Member]
Fair Value
Derivative assets, current	0	0
Derivative liabilities, current	52	0
Derivative assets	0	0
Derivative liabilities	52	0
Not Designated as Hedging Instrument [Member]
Fair Value
Derivative assets	62,719	45,087
Derivative liabilities	54,433	38,330
Not Designated as Hedging Instrument [Member] | NJRES [Member] | Financial Commodity Contracts [Member]
Fair Value
Derivative assets, current	48,314	35,682
Derivative liabilities, current	15,675	13,347
Derivative assets, noncurrent	696	2,626
Derivative liabilities, noncurrent	95	386
Not Designated as Hedging Instrument [Member] | NJRES [Member] | Physical Forward Commodity Contracts [Member]
Fair Value
Derivative assets, current	9,844	4,854
Derivative liabilities, current	22,333	9,281
Derivative assets, noncurrent	3,045	1,718
Derivative liabilities, noncurrent	650	0
Not Designated as Hedging Instrument [Member] | NJNG [Member] | Financial Commodity Contracts [Member]
Fair Value
Derivative assets, current	820	207
Derivative liabilities, current	13,819	10,163
Derivative assets, noncurrent	0	0
Derivative liabilities, noncurrent	0	925
Not Designated as Hedging Instrument [Member] | NJNG [Member] | Interest Rate Contracts [Member]
Fair Value
Derivative assets, noncurrent	0	0
Derivative liabilities, noncurrent	1,861	$ 4,228
First Mortgage [Member] | Series Ll [Member] | NJNG [Member]
Derivatives, Fair Value [Line Items]
Debt issued	$ 125,000
Interest rate, stated percentage	5.60%

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DERIVATIVE INSTRUMENTS - OFFSETTING OF ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands		Dec. 31, 2015	Sep. 30, 2015
NJRES [Member]
Derivative assets:
Amounts Presented in Balance Sheets	[1]	$ 61,899	$ 44,870
Offsetting Derivative Instruments	[2]	(13,813)	(15,060)
Financial Collateral Received/Pledged	[3]	(26,136)	3,841
Net Amounts	[4]	21,950	33,651
Derivative liabilities:
Amounts Presented in Balance Sheets	[1]	38,805	23,004
Offsetting Derivative Instruments	[2]	(13,813)	(15,059)
Financial Collateral Received/Pledged	[3]	(3,966)	(1,200)
Net Amounts	[4]	21,026	6,745
NJRES [Member] | Physical Forward Commodity Contracts [Member]
Derivative assets:
Amounts Presented in Balance Sheets	[1]	12,889	6,562
Offsetting Derivative Instruments	[2]	(809)	(1,326)
Financial Collateral Received/Pledged	[3]	(1,000)	0
Net Amounts	[4]	11,080	5,236
Derivative liabilities:
Amounts Presented in Balance Sheets	[1]	22,983	9,271
Offsetting Derivative Instruments	[2]	(809)	(1,326)
Financial Collateral Received/Pledged	[3]	(1,200)	(1,200)
Net Amounts	[4]	20,974	6,745
NJRES [Member] | Financial Commodity Contracts [Member]
Derivative assets:
Amounts Presented in Balance Sheets	[1]	49,010	38,308
Offsetting Derivative Instruments	[2]	(13,004)	(13,734)
Financial Collateral Received/Pledged	[3]	(25,136)	3,841
Net Amounts	[4]	10,870	28,415
Derivative liabilities:
Amounts Presented in Balance Sheets	[1]	15,770	13,733
Offsetting Derivative Instruments	[2]	(13,004)	(13,733)
Financial Collateral Received/Pledged	[3]	(2,766)	0
Net Amounts	[4]	0	0
NJRES [Member] | Foreign Currency Contracts [Member]
Derivative liabilities:
Amounts Presented in Balance Sheets	[1]	52
Offsetting Derivative Instruments	[2]	0
Financial Collateral Received/Pledged	[3]	0
Net Amounts	[4]	52
NJNG [Member]
Derivative assets:
Amounts Presented in Balance Sheets	[1]	820
Offsetting Derivative Instruments	[2]	(820)
Financial Collateral Received/Pledged	[3]	0
Net Amounts	[4]	0
Derivative liabilities:
Amounts Presented in Balance Sheets	[1]	15,680	15,316
Offsetting Derivative Instruments	[2]	(820)	(207)
Financial Collateral Received/Pledged	[3]	(12,999)	(10,881)
Net Amounts	[4]	1,861	4,228
NJNG [Member] | Financial Commodity Contracts [Member]
Derivative assets:
Amounts Presented in Balance Sheets	[1]	820	207
Offsetting Derivative Instruments	[2]	(820)	(207)
Financial Collateral Received/Pledged	[3]	0	0
Net Amounts	[4]	0	0
Derivative liabilities:
Amounts Presented in Balance Sheets	[1]	13,819	11,088
Offsetting Derivative Instruments	[2]	(820)	(207)
Financial Collateral Received/Pledged	[3]	(12,999)	(10,881)
Net Amounts	[4]	0	0
NJNG [Member] | Interest Rate Contracts [Member]
Derivative liabilities:
Amounts Presented in Balance Sheets	[1]	1,861	4,228
Offsetting Derivative Instruments	[2]	0	0
Financial Collateral Received/Pledged	[3]	0	0
Net Amounts	[4]	$ 1,861	$ 4,228

[1] Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20.

[2] Offsetting derivative instruments include: transactions with NAESB netting election, transactions held by FCM's with net margining and transactions with ISDA netting.

[3] Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties.

[4] Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.

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DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Foreign Currency Contracts [Member] | Gas Purchases [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)	$ (64)	$ (24)
Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)	12	(25)
Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0
NJRES [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	31,913	113,956
NJRES [Member] | Not Designated as Hedging Instrument [Member] | Physical Commodity Contracts [Member] | Operating Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	11,874	16,091
NJRES [Member] | Not Designated as Hedging Instrument [Member] | Physical Commodity Contracts [Member] | Gas Purchases [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	(21,237)	(19,856)
NJRES [Member] | Not Designated as Hedging Instrument [Member] | Financial Commodity Contracts [Member] | Gas Purchases [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	41,276	117,721
NJNG [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments, gain (loss) recognized in regulatory assets and liabilities net	(5,600)	$ (19,000)
NJNG [Member] | Treasury Lock [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments, gain (loss) recognized in regulatory assets and liabilities net	$ 2,400

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DERIVATIVE INSTRUMENTS - VOLUME (Details) $ in Millions		Dec. 31, 2015 USD ($) Bcf	Sep. 30, 2015 USD ($) Bcf	Jun. 01, 2015 USD ($)
Derivative [Line Items]
Notional amount | $				$ 125
Treasury Lock [Member]
Derivative [Line Items]
Notional amount | $		$ 125	$ 125
NJNG [Member] | Futures [Member] | Long [Member]
Derivative [Line Items]
Volume (Bcf)	[1]	19.5	25.8
NJRES [Member] | Futures [Member] | Short [Member]
Derivative [Line Items]
Volume (Bcf)		(120.8)	(91.1)
NJRES [Member] | Options [Member] | Long [Member]
Derivative [Line Items]
Volume (Bcf)		5.8	1.2
NJRES [Member] | Physical [Member] | Long [Member]
Derivative [Line Items]
Volume (Bcf)		111.7	48.2

[1] Not included is the notional amount of $125 million related to NJNG’s treasury lock agreement.

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DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Sep. 30, 2015
Derivative [Line Items]
Broker margin - Current assets	$ 21,334	$ 12,990
Broker margin - Current (liabilities)	(19,307)	(4,103)
NJNG [Member]
Derivative [Line Items]
Broker margin - Current assets	17,487	12,990
NJRES [Member]
Derivative [Line Items]
Broker margin - Current assets	3,847	0
Broker margin - Current (liabilities)	$ (19,307)	$ (4,103)

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DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2015	Sep. 30, 2015
Credit Risk Exposure [Line Items]
Derivative, net liability position, aggregate fair value	$ 1,900	$ 4,200
Additional collateral, aggregate fair value	1,900	$ 4,200
NJNG [Member]
Credit Risk Exposure [Line Items]
Gross Credit Exposure	139,420
NJNG [Member] | Investment Grade [Member]
Credit Risk Exposure [Line Items]
Gross Credit Exposure	99,405
NJNG [Member] | Noninvestment Grade [Member]
Credit Risk Exposure [Line Items]
Gross Credit Exposure	9,693
NJNG [Member] | Internally Rated Investment Grade [Member]
Credit Risk Exposure [Line Items]
Gross Credit Exposure	22,507
NJNG [Member] | Internally Rated Noninvestment Grade [Member]
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 7,815

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FAIR VALUE - DEBT (Details) - USD ($) $ in Thousands		Dec. 31, 2015	Sep. 30, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Capital leases		$ 51,300	$ 46,900
Level 2 [Member] | Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	[1]	807,845	807,845
Level 2 [Member] | Fair Market Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		$ 809,107	$ 817,319

[1] Excludes capital leases of $51.3 million and $46.9 million as of December 31, 2015 and September 30, 2015, respectively.

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FAIR VALUE - HIERARCHY (Details) - USD ($) $ in Thousands		Dec. 31, 2015	Sep. 30, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		$ 62,719	$ 45,087
Liabilities		54,485	38,330
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	[1]	65,790	59,475
Other	[2]	1,809	1,572
Total assets at fair value		130,318	106,134
Total liabilities at fair value		54,485	38,330
Fair Value, Measurements, Recurring [Member] | Physical Forward Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		12,889	6,572
Liabilities		22,983	9,281
Fair Value, Measurements, Recurring [Member] | Financial Commodity/Derivative Contracts - Natural Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		49,830	38,515
Liabilities		29,589	24,821
Fair Value, Measurements, Recurring [Member] | Financial Commodity/Derivative Contracts - Natural Gas [Member] | Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities		52
Fair Value, Measurements, Recurring [Member] | Interest Rate Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities		1,861	4,228
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	[1]	65,790	59,475
Other	[2]	1,809	1,572
Total assets at fair value		117,429	99,562
Total liabilities at fair value		29,589	24,821
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 Commodity/Derivative Contracts - Natural Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		49,830	38,515
Liabilities		29,589	24,821
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Financial Commodity/Derivative Contracts - Natural Gas [Member] | Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities		0
Fair Value, Measurements, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets, (Level 1) [Member] | Interest Rate Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
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	[1]	0	0
Other	[2]	0	0
Total assets at fair value		12,889	6,572
Total liabilities at fair value		24,896	13,509
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		12,889	6,572
Liabilities		22,983	9,281
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Financial Commodity/Derivative Contracts - Natural Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		0	0
Liabilities		0	0
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Financial Commodity/Derivative Contracts - Natural Gas [Member] | Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities		52
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities		1,861	4,228
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	[1]	0	0
Other	[2]	0	0
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 Commodity/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 Commodity/Derivative Contracts - Natural Gas [Member] | Foreign Exchange [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities		0
Fair Value, Measurements, Recurring [Member] | Significant Unobservable Inputs (Level 3) [Member] | Interest Rate Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities		$ 0	$ 0

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

[2] Includes various money market funds in Level 1.

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INVESTMENTS IN EQUITY INVESTEES (Details) $ in Thousands		3 Months Ended
		Dec. 31, 2015 USD ($) mi	Sep. 30, 2015 USD ($)
Schedule of Equity Method Investments [Line Items]
Investments in equity investees		$ 134,280	$ 132,002
Steckman Ridge [Member]
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	[1]	125,058	125,649
Steckman Ridge [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Total outstanding principal balance of loans		70,400	70,400
PennEast [Member]
Schedule of Equity Method Investments [Line Items]
Investments in equity investees		$ 9,222	$ 6,353
Construction plan, project area (in miles) | mi		118

[1] Includes loans with a total outstanding principal balance of $70.4 million for both December 31, 2015 and September 30, 2015. The loans accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

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EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Earnings Per Share [Abstract]
Net income, as reported		$ 48,647	$ 123,320
Basic earnings per share
Weighted average shares of common stock outstanding-basic (shares)		85,675,000	84,552,000
Basic earnings per common share (usd per share)		$ 0.57	$ 1.46
Diluted earnings per share
Weighted average shares of common stock outstanding-basic (shares)		85,675,000	84,552,000
Incremental shares	[1]	1,001,000	1,022,000
Weighted average shares of common stock outstanding-diluted (shares)		86,676,000	85,574,000
Diluted earnings per common share (usd per share)	[2]	$ 0.56	$ 1.44
Anti-dilutive shares excluded from the calculation of diluted earnings per share		0	0

[1] Incremental shares consist primarily of stock awards and performance shares.

[2] There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three months ended December 31, 2015, and 2014.

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COMMON STOCK EQUITY - CHANGE IN COMMON STOCK EQUITY (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended
	Dec. 14, 2015	Dec. 31, 2015	Dec. 31, 2014
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period (shares)		85,531,423
Balance as of beginning of period		$ 1,106,956
Net income		48,647	$ 123,320
Other comprehensive income		3,924	$ 875
Common stock issued:
Incentive plan		$ 5,499
Dividend reinvestment plan (in shares)	5,000,000	127,000	148,000
Dividend reinvestment plan		$ 3,805
Cash dividend declared ($.24 per share)		(20,594)
Treasury stock and other		$ (4,293)
Balance as of end of period (shares)		85,809,094
Balance as of end of period		$ 1,143,944
Cash dividend declared per share (usd per share)		$ 0.24	$ 0.225
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period (shares)		85,531,000
Balance as of beginning of period		$ 220,838
Common stock issued:
Incentive plan (in shares)		286,000
Incentive plan		$ 717
Dividend reinvestment plan (in shares)		127,000
Treasury stock and other (shares)		(135,000)
Balance as of end of period (shares)		85,809,000
Balance as of end of period		$ 221,555
Premium on Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period		209,931
Common stock issued:
Incentive plan		4,782
Dividend reinvestment plan		(1,339)
Treasury stock and other		(23)
Balance as of end of period		213,351
Accumulated Other Comprehensive (Loss) Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period		(9,394)
Other comprehensive income		3,924
Common stock issued:
Balance as of end of period		(5,470)
Treasury Stock And Other [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period		(92,164)
Common stock issued:
Dividend reinvestment plan		5,144
Treasury stock and other		(4,270)
Balance as of end of period		(91,290)
Retained Earnings [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period		777,745
Net income		48,647
Common stock issued:
Cash dividend declared ($.24 per share)		(20,594)
Balance as of end of period		$ 805,798

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COMMON STOCK EQUITY - DIVIDEND REINVESTMENT PLAN (Details) - USD ($) $ in Millions		3 Months Ended
	Dec. 14, 2015	Dec. 31, 2015	Dec. 31, 2014
Equity [Abstract]
Number of treasury shares issued from raising of equity through the DRP	5,000,000	127,000	148,000
Equity raised through the DRP		$ 3.8	$ 3.8
Additional equity raised			$ 19.8
Additional shares issued through the waiver discount feature of the DRP		0	688,000

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COMMON STOCK EQUITY - ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Thousands		3 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period		$ (9,394)	$ (5,594)
Other comprehensive income (loss), before reclassifications, net of tax		3,660	644
Amounts reclassified from accumulated other comprehensive income, net of tax		264	231
Other comprehensive income		3,924	875
Balance as of end of period		(5,470)	(4,719)
Tax on other comprehensive income (loss) before reclassifications		2,591	446
Tax on amounts reclassified from accumulated other comprehensive income		178	160
Tax on net current-period other comprehensive income (loss)		2,769	606
Available for Sale Securities [Member]
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period		6,385	4,782
Other comprehensive income (loss), before reclassifications, net of tax		3,701	659
Amounts reclassified from accumulated other comprehensive income, net of tax		0	0
Other comprehensive income		3,701	659
Balance as of end of period		10,086	5,441
Tax on other comprehensive income (loss) before reclassifications		2,614	455
Tax on amounts reclassified from accumulated other comprehensive income		0	0
Tax on net current-period other comprehensive income (loss)		2,614	455
Cash Flow Hedges [Member]
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period		0	(93)
Other comprehensive income (loss), before reclassifications, net of tax		(41)	(15)
Amounts reclassified from accumulated other comprehensive income, net of tax	[1]	8	(16)
Other comprehensive income		(33)	(31)
Balance as of end of period		(33)	(124)
Tax on other comprehensive income (loss) before reclassifications		(23)	(9)
Tax on amounts reclassified from accumulated other comprehensive income		4	(9)
Tax on net current-period other comprehensive income (loss)		(19)	(18)
Postemployment Benefit Obligation [Member]
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period		(15,779)	(10,283)
Other comprehensive income (loss), before reclassifications, net of tax		0	0
Amounts reclassified from accumulated other comprehensive income, net of tax	[2]	256	247
Other comprehensive income		256	247
Balance as of end of period		(15,523)	(10,036)
Tax on other comprehensive income (loss) before reclassifications		0	0
Tax on amounts reclassified from accumulated other comprehensive income		174	169
Tax on net current-period other comprehensive income (loss)		$ 174	$ 169

[1] Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

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

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DEBT - CREDIT FACILITIES (Details) - USD ($)		Dec. 31, 2015	Sep. 30, 2015
NJR [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount		$ 22,900,000	$ 16,500,000
NJR [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Bank revolving credit facilities	[1]	425,000,000	425,000,000
Amount outstanding at end of period		$ 135,000,000	$ 39,350,000
Weighted average interest rate at end of period		1.24%	1.17%
Amount available at end of period	[2]	$ 267,055,000	$ 369,176,000
NJR [Member] | Term Loan [Member]
Line of Credit Facility [Line Items]
Bank revolving credit facilities	[3]	0	100,000,000
Amount available at end of period		0	100,000,000
NJNG [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Amount outstanding at end of period		$ 76,000,000	$ 27,000,000
Weighted average interest rate at end of period		0.28%	0.20%
NJNG [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount		$ 731,000	$ 731,000
NJNG [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Bank revolving credit facilities	[1]	250,000,000	250,000,000
NJNG [Member] | Revolving Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Amount available at end of period	[4]	$ 173,269,000	$ 222,269,000

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

[2] Letters of credit outstanding total $22.9 million and $16.5 million as of December 31, 2015 and September 30, 2015, respectively, which reduces amount available by the same amount.

[3] Uncommitted credit facilities, which require no commitment fees.

[4] Letters of credit outstanding total $731,000 and $731,000 as of December 31, 2015 and September 30, 2015, respectively, which reduces the amount available by the same amount.

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DEBT - SCHEDULE OF LONG TERM DEBT (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Proceeds from sale-leaseback transaction	$ 7,107	$ 7,216
NJNG [Member]
Debt Instrument [Line Items]
Proceeds from sale-leaseback transaction	$ 7,100	$ 7,200

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EMPLOYEE BENEFIT PLANS (Details) - USD ($)	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Components of net periodic cost
Discretionary contribution	$ 30,000,000	$ 0
Pension [Member]
Components of net periodic cost
Service cost	1,898,000	1,871,000
Interest cost	2,836,000	2,550,000
Expected return on plan assets	(5,029,000)	(4,272,000)
Recognized actuarial loss	1,820,000	1,745,000
Prior service cost amortization	28,000	28,000
Net periodic benefit cost	1,553,000	1,922,000
OPEB [Member]
Components of net periodic cost
Service cost	1,130,000	1,063,000
Interest cost	1,564,000	1,435,000
Expected return on plan assets	(1,211,000)	(1,244,000)
Recognized actuarial loss	819,000	736,000
Prior service cost amortization	(91,000)	(91,000)
Net periodic benefit cost	$ 2,211,000	$ 1,899,000

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INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Effective income tax rate	14.70%	24.90%
Forecasted tax credits, net of deferred tax	$ 26,800	$ 27,100
Operating Loss Carryforwards [Line Items]
Tax benefit associated with the loss carryforwards	13,000		$ 12,800
ITC carryforward, expiration period			20 years
NJRCEV [Member]
Operating Loss Carryforwards [Line Items]
ITC carryforward			$ 22,100
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	$ 222,600		218,100
Net operating loss carryforwards, expiration term	20 years
Valuation allowance	$ 271		$ 176

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COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) $ in Thousands	3 Months Ended
	Dec. 31, 2015 USD ($)
Long-term Purchase Commitment [Line Items]
Current charges recoverable through BGSS	$ 58,500
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	407,622	[1]
2017	316,349	[1]
2018	258,655	[1]
2019	205,778	[1]
2020	146,504	[1]
Thereafter	889,219	[1]
NJRES [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	307,161
2017	159,210
2018	109,425
2019	63,497
2020	7,925
Thereafter	7,164
NJRES [Member] | Natural Gas Purchases [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	212,469
2017	94,896
2018	84,187
2019	51,029
2020	0
Thereafter	0
NJRES [Member] | Storage Demand Fees [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	20,288
2017	13,290
2018	8,565
2019	4,960
2020	3,672
Thereafter	3,270
NJRES [Member] | Pipeline Demand Fees [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	74,404
2017	51,024
2018	16,673
2019	7,508
2020	4,253
Thereafter	$ 3,894
NJRES [Member] | Minimum [Member]
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, contract term	1 year
NJRES [Member] | Maximum [Member]
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, contract term	10 years
NJNG [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	$ 100,461
2017	157,139
2018	149,230
2019	142,281
2020	138,579
Thereafter	882,055
NJNG [Member] | Natural Gas Purchases [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	41,962
2017	63,953
2018	39,885
2019	40,976
2020	43,775
Thereafter	98,948
NJNG [Member] | Storage Demand Fees [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	21,815
2017	25,328
2018	15,871
2019	11,079
2020	5,345
Thereafter	0
NJNG [Member] | Pipeline Demand Fees [Member]
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2016	36,684
2017	67,858
2018	93,474
2019	90,226
2020	89,459
Thereafter	$ 783,107

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

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COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details) $ in Thousands	1 Months Ended	3 Months Ended
	Sep. 30, 2014 USD ($)	Dec. 31, 2015 USD ($) site	Sep. 30, 2015 USD ($)
Site Contingency [Line Items]
Number of MGP sites | site		5
Recovery of expenditures, including carrying costs, rolling period approved by the BPU		7 years
Regulatory assets		$ 423,332	$ 410,155
Minimum [Member]
Site Contingency [Line Items]
Litigation settlement, gross		150,900
Maximum [Member]
Site Contingency [Line Items]
Litigation settlement, gross		242,100
Environmental Remediation Costs Expended, Net of Recoveries [Member]
Site Contingency [Line Items]
Regulatory assets		17,963	18,886
Environmental Remediation Costs Liability for Future Expenditures [Member]
Site Contingency [Line Items]
Regulatory assets		$ 180,400	$ 180,400
SBC [Member] | September 2014 SBC Filing [Member]
Site Contingency [Line Items]
Requested rate, amount	$ 8,500

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) - USD ($) $ in Thousands		3 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Utility		$ 151,606	$ 208,727
Nonutility		292,652	615,397
Total operating revenues		444,258	824,124
Depreciation and amortization		16,482	14,386
Interest income	[1]	70	90
Interest expense, net of capitalized interest		6,777	7,195
Income tax provision (benefit)		8,357	40,867
Equity in earnings of affiliates		2,406	2,795
Net financial earnings		49,632	55,109
Capital expenditures		94,843	92,104
Investments in equity investees		$ 2,846	$ 547
Canada [Member]
Segment Reporting Information [Line Items]
Percentage to total operating revenues		3.50%	4.70%
Operating Segments [Member]
Segment Reporting Information [Line Items]
Total operating revenues		$ 438,093	$ 818,650
Depreciation and amortization		16,372	14,160
Interest income	[1]	404	329
Interest expense, net of capitalized interest		6,891	7,189
Income tax provision (benefit)		9,111	41,814
Net financial earnings		50,433	55,750
Capital expenditures		94,046	92,093
Operating Segments [Member] | Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization		11,238	10,545
Interest income	[1]	68	90
Interest expense, net of capitalized interest		4,588	4,609
Income tax provision (benefit)		13,863	14,166
Net financial earnings		30,570	28,186
Capital expenditures		49,040	36,748
Operating Segments [Member] | Natural Gas Distribution [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Utility		151,606	208,727
Operating Segments [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization		23	22
Interest income	[1]	72	0
Interest expense, net of capitalized interest		208	513
Income tax provision (benefit)		5,195	45,877
Net financial earnings		10,014	16,436
Operating Segments [Member] | Energy Services [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility	[2]	276,182	600,562
Operating Segments [Member] | Energy Services [Member] | Intercompany [Member]
Segment Reporting Information [Line Items]
Nonutility		2,511	3,126
Operating Segments [Member] | Clean Energy Ventures [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization		5,110	3,591
Interest expense, net of capitalized interest		2,053	1,817
Income tax provision (benefit)		(11,587)	(19,721)
Net financial earnings		7,505	9,008
Capital expenditures		45,006	55,345
Operating Segments [Member] | Clean Energy Ventures [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility		7,794	6,235
Operating Segments [Member] | Home Services and Other [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization		227	238
Interest income	[1]	37	0
Interest expense, net of capitalized interest		0	6
Income tax provision (benefit)		(288)	(452)
Net financial earnings		(583)	(592)
Capital expenditures		797	11
Operating Segments [Member] | Home Services and Other [Member] | External Customers [Member]
Segment Reporting Information [Line Items]
Nonutility		8,676	8,600
Operating Segments [Member] | Home Services and Other [Member] | Intercompany [Member]
Segment Reporting Information [Line Items]
Nonutility		897	411
Operating Segments [Member] | Midstream [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization		1	2
Interest income	[1]	264	239
Interest expense, net of capitalized interest		42	250
Income tax provision (benefit)		1,640	1,492
Equity in earnings of affiliates		3,545	3,775
Net financial earnings		2,344	2,120
Investments in equity investees		2,846	547
Eliminations [Member]
Segment Reporting Information [Line Items]
Nonutility		(3,408)	(3,537)
Depreciation and amortization		(117)	(12)
Interest income	[1]	(371)	(239)
Interest expense, net of capitalized interest		(114)	0
Income tax provision (benefit)		(466)	(495)
Equity in earnings of affiliates		(1,139)	(980)
Net financial earnings		$ (218)	$ (49)

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

[2] Includes sales to Canada, which accounted for 3.5 and 4.7 percent of total operating revenues during the three months ended December 31, 2015 and 2014.

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS LOSS RECONCILIATION (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting [Abstract]
Consolidated NFE	$ 49,632	$ 55,109
Less:
Unrealized (gain) on derivative instruments and related transactions	(1,135)	(88,673)
Effects of economic hedging related to natural gas inventory	3,813	(8,765)
Tax adjustments	(1,693)	29,227
NET INCOME	$ 48,647	$ 123,320

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) - USD ($) $ in Thousands		Dec. 31, 2015	Sep. 30, 2015
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets		$ 3,477,238	$ 3,284,357
Natural Gas Distribution [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets		2,357,063	2,305,293
Energy Services [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets		310,364	260,021
Clean Energy Ventures [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets		597,897	504,885
Midstream [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets		191,292	182,007
Subtotal [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets		3,456,616	3,252,206
Home Services and Other [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets		90,012	88,880
Intercompany Assets [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	[1]	$ (69,390)	$ (56,729)

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

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RELATED PARTY TRANSACTIONS (Details)		3 Months Ended
	Apr. 01, 2010 USD ($) Bcf	Dec. 31, 2015 USD ($) contract	Dec. 31, 2014 USD ($)	Sep. 30, 2014 Bcf / d	Sep. 30, 2015 USD ($)
Related Party Transaction [Line Items]
Number of asset management agreements | contract		4
NJRES to Steckman Ridge Affiliate
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement		$ 685,000	$ 484,000
Due to related parties		376,000			$ 375,000
NJNG to Steckman RIdge Affiliate
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement		1,400,000	$ 1,400,000
Due to related parties		$ 774,900			$ 774,900
Related party agreement term	10 years
Natural gas sold at cost under asset management agreement (in Bcf) | Bcf	3.0
Approximate annual demand fees under agreement from April 1 2010 to March 31 2020	$ 9,300,000
NJNG to PennEast Affiliate [Member]
Related Party Transaction [Line Items]
Transportation precedent agreement, period				15 years
Transportation capacity under precedent agreement from NJNG with PennEast (in bcf per day) | Bcf / d				0.18