10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10‑Q

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

SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2017

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 001‑08359
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, smaller reporting company or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b‑2 of the Exchange Act.

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

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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 May 2, 2017 was 86,438,897.

New Jersey Resources Corporation

TABLE OF CONTENTS

			Page
Glossary of Key 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	13
		Note 4. Derivative Instruments	15
		Note 5. Fair Value	20
		Note 6. Investments in Equity Investees	22
		Note 7. Earnings Per Share	23
		Note 8. Common Stock Equity	23
		Note 9. Debt	25
		Note 10. Employee Benefit Plans	26
		Note 11. Income Taxes	26
		Note 12. Commitments and Contingent Liabilities	27
		Note 13. Business Segment and Other Operations Data	29
		Note 14. Related Party Transactions	32
	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	32
	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	58
	ITEM 4.	Controls and Procedures	61
PART II. OTHER INFORMATION
	ITEM 1.	Legal Proceedings	62
	ITEM 1A.	Risk Factors	62
	ITEM 2.	Unregistered Sale of Equity Securities and Use of Proceeds	62
	ITEM 6.	Exhibits	63
		Signatures	64

New Jersey Resources Corporation

GLOSSARY OF KEY TERMS                                                                                                                                                        

AFUDC	Allowance for Funds Used During Construction
AOCI	Accumulated Other Comprehensive Income
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 Bond
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
ISDA	The International Swaps and Derivatives Association
ITC	Federal Investment Tax Credit
LNG	Liquefied Natural Gas
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
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

1

New Jersey Resources Corporation

GLOSSARY OF KEY TERMS (cont.)
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
PTC	Federal Production Tax Credit
RA	Remediation Adjustment
REC	Renewable Energy Certificate
S&P	Standard & Poor's Financial Services, LLC
SAFE	Safety Acceleration and Facility Enhancement
SAVEGREEN	The SAVEGREEN Project®
SBC	Societal Benefits Charge
SEC	U.S. Securities and Exchange Commission
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, assumptions 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 Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and 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,” “could,” “might,” “intend,” “expect,” “believe,” “will” “plan,” or “should,” or comparable terminology and are made based upon management's current expectations, assumptions and beliefs as of this date concerning future developments and their potential effect on us. There can be no assurance that future developments will be in accordance with management's expectations, assumptions or beliefs, or that the effect of future developments on us will be those anticipated by management.

We caution readers that the expectations, assumptions and beliefs that form the basis for forward-looking statements regarding customer growth, customer usage, qualifications for ITCs, PTCs and SRECs, future rate case proceedings, financial condition, results of operations, cash flows, capital requirements, future capital expenditures, market risk, effective tax rate and other matters for fiscal 2017 and thereafter include many factors that are beyond our 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 our expectations, assumptions and beliefs include, but are not limited to, those discussed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the fiscal year ended September 30, 2016, as well as the following:

• weather and economic conditions;

• demographic changes in NJR's service territory and their effect on NJR'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 our risk management efforts;

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

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

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

• the ability to obtain governmental and regulatory approvals and land use rights, such as those necessary for the PennEast pipeline project, land-use rights, electric grid connection (in the case of clean energy projects) and/or financing for the construction, development and operation of our unregulated energy investments and NJNG's infrastructure projects in a timely manner;

• risks associated with the management of our joint ventures and partnerships, and investment in a master limited partnership;

• risks associated with our investments in clean energy projects, including the availability of regulatory and tax incentives, the availability of viable projects, our eligibility for ITCs and PTCs, the future market for SRECs and electricity prices, 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 and expenses are incurred and the extent to which they are allowed to be recovered from customers through the regulatory process, including through future base rate case filings;

• 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;

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

• environmental-related and other litigation and other uncertainties;

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

• the impact of natural disasters, terrorist activities and other extreme events on our operations and customers.

While we periodically reassess material trends and uncertainties affecting our results of operations and financial condition in connection with the preparation of management's discussion and analysis of results of operations and financial condition contained in our Quarterly and Annual Reports on Form 10-Q and Form 10-K, respectively, we do 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				Six Months Ended
	March 31,				March 31,
(Thousands, except per share data)	2017		2016		2017		2016
OPERATING REVENUES
Utility	$	295,546	$	242,536	$	481,102	$	394,142
Nonutility	438,000		331,657		793,472		624,309
Total operating revenues	733,546		574,193		1,274,574		1,018,451
OPERATING EXPENSES
Gas purchases:
Utility	112,445		82,374		173,765		129,039
Nonutility	367,328		287,883		705,260		541,971
Related parties	2,072		2,077		4,183		4,151
Operation and maintenance	52,342		53,125		104,570		99,358
Regulatory rider expenses	19,893		21,215		32,494		30,843
Depreciation and amortization	20,328		17,744		39,588		34,226
Energy and other taxes	19,485		15,842		33,586		25,479
Total operating expenses	593,893		480,260		1,093,446		865,067
OPERATING INCOME	139,653		93,933		181,128		153,384
Other income, net	5,338		2,202		9,114		4,126
Interest expense, net of capitalized interest	11,436		7,369		22,051		14,146
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	133,555		88,766		168,191		143,364
Income tax provision	23,932		17,815		25,950		24,537
Equity in earnings of affiliates	5,079		2,402		7,390		4,808
NET INCOME	$	114,702	$	73,353	$	149,631	$	123,635
EARNINGS PER COMMON SHARE
Basic	$1.33		$0.85		$1.74		$1.44
Diluted	$1.32		$0.84		$1.72		$1.42
DIVIDENDS DECLARED PER COMMON SHARE	$0.255		$0.24		$0.51		$0.48
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic	86,275		85,834		86,182		85,754
Diluted	87,101		86,858		86,993		86,778

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

		Three Months Ended				Six Months Ended
		March 31,				March 31,
(Thousands)		2017		2016		2017		2016
Net income		$	114,702	$	73,353	$	149,631	$	123,635
Other comprehensive income, net of tax
Unrealized gain on available for sale securities, net of tax of $(670), $(3,154), $(4,456), and $(5,768), respectively		$	1,408	$	4,500	6,923		8,201
Net unrealized gain on derivatives, net of tax of $0, $(21), $0 and $(2), respectively	(1)	—		38		—		5
Adjustment to postemployment benefit obligation, net of tax of $(217), $(175), $(434), and $(349) respectively		318		257		635		513
Other comprehensive income		$	1,726	$	4,795	7,558		8,719
Comprehensive income		$	116,428	$	78,148	$	157,189	$	132,354

(1) Effective January 1, 2016, the Company elected not to designate its foreign currency derivatives as accounting hedges and, as a result, changes in fair value of the effective portion of the hedges are no longer recorded in OCI. See Note 4 Derivative Instruments for more information on these transactions.

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)

	Six Months Ended
	March 31,
(Thousands)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	149,631		$	123,635
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) loss on derivative instruments	(26,553		)	2,035
Gain on sale of property and available for sale securities, net	(7,287		)	—
Depreciation and amortization	39,588			34,226
Allowance for equity used during construction	(1,586		)	(2,357		)
Allowance for bad debt expense	519			873
Deferred income taxes	32,202			17,980
Manufactured gas plant remediation costs	(3,704		)	(2,656		)
Distributions received from equity investees, net of equity in earnings	(463		)	2,261
Cost of removal - asset retirement obligations	(242		)	(66		)
Contributions to postemployment benefit plans	(1,884		)	(32,167		)
Tax benefit from stock-based compensation	1,231			1,660
Changes in:
Components of working capital	(31,231		)	(13,788		)
Other noncurrent assets	24,580			(15,794		)
Other noncurrent liabilities	(2,997		)	2,163
Cash flows from operating activities	171,804			118,005
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Expenditures for:
Utility plant	(58,761		)	(76,326		)
Solar and wind equipment	(89,905		)	(70,882		)
Real estate properties and other	(516		)	(1,069		)
Cost of removal	(14,838		)	(20,080		)
Investments in equity investees	(10,538		)	(5,948		)
Distribution from equity investees in excess of equity in earnings	1,273			1,131
Withdrawal from restricted cash construction fund	1,337			1,007
Proceeds from sale of property, net of closing costs	9,443			748
Proceeds from sale of available for sale securities	6,639			—
Cash flows (used in) investing activities	(155,866		)	(171,419		)
CASH FLOWS FROM FINANCING ACTIVITIES
Net proceeds from short-term debt	116,200			86,150
Payments of long-term debt	(41,660		)	(5,807		)
Proceeds from sale-leaseback transaction	9,587			7,107
Payments of common stock dividends	(43,898		)	(41,115		)
Proceeds from issuance of common stock	9,731			8,220
Purchases of treasury stock	(6,355		)	(1,008		)
Tax withholding payments related to net settled stock compensation	(4,354		)	(3,181		)
Cash flows from financing activities	39,251			50,366
Change in cash and cash equivalents	55,189			(3,048		)
Cash and cash equivalents at beginning of period	37,546			4,928
Cash and cash equivalents at end of period	$	92,735		$	1,880
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	(137,408	)	$	(16,750	)
Inventories	62,321			43,479
Recovery of gas costs	(9,616		)	(20,396		)
Gas purchases payable	21,156			(31,324		)
Gas purchases payable - related parties	3			(409		)
Prepaid and accrued taxes	25,829			43,154
Accounts payable and other	(10,027		)	(25,026		)
Restricted broker margin accounts	28,432			(12,478		)
Customers' credit balances and deposits	(12,765		)	226
Other current assets	844			5,736
Total	$	(31,231	)	$	(13,788	)
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid (received) for:
Interest (net of amounts capitalized)	$	21,578		$	15,647
Income taxes	$	(6,431	)	$	688
Accrued capital expenditures	$	23,284		$	21,663

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)	March 31, 2017			September 30, 2016
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	2,167,728		$	2,107,375
Construction work in progress	108,373			122,268
Solar and wind equipment, real estate properties and other, at cost	758,864			631,696
Construction work in progress	31,464			93,791
Total property, plant and equipment	3,066,429			2,955,130
Accumulated depreciation and amortization, utility plant	(475,075		)	(467,702		)
Accumulated depreciation and amortization, solar and wind equipment, real estate properties and other	(95,050		)	(79,776		)
Property, plant and equipment, net	2,496,304			2,407,652
CURRENT ASSETS
Cash and cash equivalents	92,735			37,546
Customer accounts receivable
Billed	242,698			142,658
Unbilled revenues	42,657			5,744
Allowance for doubtful accounts	(4,929		)	(4,865		)
Regulatory assets	43,344			54,286
Gas in storage, at average cost	143,514			206,251
Materials and supplies, at average cost	11,194			10,778
Prepaid and accrued taxes	15,528			34,179
Derivatives, at fair value	32,103			29,964
Restricted broker margin accounts	23,604			47,644
Asset held for sale	—			7,660
Other	35,509			35,419
Total current assets	677,957			607,264
NONCURRENT ASSETS
Investments in equity method investees	152,891			141,148
Regulatory assets	396,924			441,294
Derivatives, at fair value	6,347			5,227
Available for sale securities	65,884			55,789
Other	61,052			60,196
Total noncurrent assets	683,098			703,654
Total assets	$	3,857,359		$	3,718,570

See Notes to Unaudited Condensed Consolidated Financial Statements

6

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                      

CAPITALIZATION AND LIABILITIES

(Thousands)	March 31, 2017			September 30, 2016
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding March 31, 2017 — 86,363,986; September 30, 2016 — 86,086,355	$	222,235		$	221,654
Premium on common stock	219,074			215,580
Accumulated other comprehensive loss, net of tax	(7,597		)	(15,155		)
Treasury stock at cost and other; shares March 31, 2017 — 2,529,817; September 30, 2016 — 2,575,139	(78,616		)	(81,044		)
Retained earnings	931,184			825,556
Common stock equity	1,286,280			1,166,591
Long-term debt	1,023,968			1,055,038
Total capitalization	2,310,248			2,221,629
CURRENT LIABILITIES
Current maturities of long-term debt	60,723			61,452
Short-term debt	237,900			121,700
Gas purchases payable	160,605			139,452
Gas purchases payable to related parties	1,156			1,150
Accounts payable and other	70,981			107,184
Dividends payable	22,023			21,975
Accrued taxes	8,258			1,080
Regulatory liabilities	5,747			9,469
New Jersey clean energy program	6,239			14,232
Derivatives, at fair value	32,559			61,080
Customers' credit balances and deposits	20,069			32,834
Total current liabilities	626,260			571,608
NONCURRENT LIABILITIES
Deferred income taxes	507,111			473,847
Deferred investment tax credits	4,458			4,619
Deferred gain	28,121			28,519
Derivatives, at fair value	6,105			25,252
Manufactured gas plant remediation	165,849			172,000
Postemployment employee benefit liability	141,797			141,604
Regulatory liabilities	28,457			41,411
Asset retirement obligation	29,924			28,379
Other	9,029			9,702
Total noncurrent liabilities	920,851			925,333
Commitments and contingent liabilities (Note 12)
Total capitalization and liabilities	$	3,857,359		$	3,718,570

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 528,000 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 Clean Energy Ventures Corporation, the Company's clean energy subsidiary, comprises the Clean Energy Ventures segment and consists of the Company's capital investments in commercial and residential solar projects located throughout New Jersey and onshore wind investments in Montana, Iowa, Kansas, Wyoming and Pennsylvania;

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 in the U.S. and Canada;

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, located in Pennsylvania, and NJR Pipeline Company, which holds the Company's 20 percent ownership interest in PennEast and NJNR Pipeline Company, which holds the Company's1.84 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, which provides heating, central air conditioning, standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey, and Commercial Realty & Resources Corporation, which owns commercial real estate. NJR Retail Holdings Corporation is included in Home Services and Other operations. NJR Energy Corporation, a subsidiary of CR&R, was dissolved on November 28, 2016, and all assets were moved to CR&R during the first quarter of fiscal 2017.

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 SEC and GAAP. The September 30, 2016 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 2016 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 ending September 30, 2017. Intercompany transactions and accounts have been eliminated.

Gas in Storage

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

	March 31, 2017				September 30, 2016
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJRES		$	128,281	46.4		$	130,493	62.0
NJNG		15,233		4.3		75,758		21.3
Total		$	143,514	50.7		$	206,251	83.3

8

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Sales Tax Accounting

Sales tax that is collected from customers is presented in both operating revenues and operating expenses on the Unaudited Condensed Consolidated Statements of Operations was $16.9 million and $28.1 million during the three and six months endedMarch 31, 2017, respectively, and $13.5 million and $20.7 million during the three and six months endedMarch 31, 2016, respectively. Effective January 1, 2017, the New Jersey sales tax rate decreased from 7 percent to 6.875 percent.

Sale of Asset

On March 8, 2017, CR&R sold an approximately 56,400 square foot office building on five acres of land located in Monmouth County for $9.4 million, net of closing costs, generating a pre-tax gain of $1.9 million, which was recognized in O&M on the Unaudited Condensed Consolidated Statements of Operations.

Available for Sale Securities

Included in available for sale securities on the Unaudited Condensed Consolidated Balance Sheets are investments in two publicly traded energy companies. The Company's available for sale securities had a fair value of $65.9 million and $55.8 million as of March 31, 2017 and September 30, 2016, respectively. Total unrealized gains associated with these investments are included as a part of accumulated other comprehensive income, a component of common stock equity and were $18.5 million, $11.1 million after tax, and $7.2 million, $4.2 million after tax, as of March 31, 2017 and September 30, 2016, respectively.

During the three and six months endedMarch 31, 2017, NJR received proceeds of approximately $3.4 million and $6.6 million, respectively, from the sale of available for sale securities and realized a pre-tax gain of $2.8 million and $5.4 million, respectively, which is included in other income, net in the Unaudited Condensed Consolidated Statements of Operations. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

Customer Accounts Receivable

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

(Thousands)	March 31, 2017				September 30, 2016
NJRES	$	135,199	56	%	$	102,884	72	%
NJNG (1)	100,449		41		30,951		22
NJRCEV	2,405		1		1,807		1
NJRHS and other	4,645		2		7,016		5
Total	$	242,698	100	%	$	142,658	100	%

(1) Does not include unbilled revenues of $42.7 million and $5.7 million as of March 31, 2017 and September 30, 2016, respectively.

Loans Receivable

NJNG provides 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 recorded $8.2 million and $7.8 million in other current assets and $40.7 million and $39.5 million in other noncurrent assets as of March 31, 2017 and September 30, 2016, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans.

NJNG's policy is to establish an allowance for doubtful accounts when loan balances are in arrears for more than 60 days. As of March 31, 2017 and September 30, 2016, there was no allowance for doubtful accounts established for the SAVEGREEN loans.

Stock Based Compensation

Effective January 25, 2017, the shareholders of NJR approved the NJR 2017 Stock Award and Incentive Plan, which replaced the NJR 2007 Stock Award and Incentive Plan. The 2007 plan had 2,367,338 and 4,223 shares available for future issuance to employees and directors, respectively, which were transferred into the 2017 plan. In addition, the 2017 plan increases the total shares available for issuance to 3,135,000.

9

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Recently Adopted Updates to the Accounting Standards Codification

Stock Compensation

In March 2016, the FASB issued ASU 2016-09, an amendment to ASC 718, Compensation - Stock Compensation, which simplifies several aspects of the accounting for employee share-based compensation, including the accounting for income taxes and forfeitures. The new guidance also increased the threshold for tax withholding to the maximum statutory rate, as applicable, to maintain equity classification and amended the classification of certain tax transactions within the statement of cash flows.

The Company elected to early adopt the amended guidance during the third quarter of fiscal 2016 and applied the new provisions as of the beginning of the year of adoption on a retrospective or prospective basis depending on each amendment’s transition requirements. As such, effective October 1, 2015, NJR is recognizing forfeitures as they occur and is recognizing excess tax benefits (deficiencies) as a component of income tax (benefit) provision in its Unaudited Condensed Consolidated Statements of Operations on a prospective basis. All related information for prior periods has been adjusted throughout this report on a retrospective basis to reflect the effects of the adoption. See Note 11. Income Taxes for more information on these transactions.

In addition, the following amounts on the Unaudited Condensed Consolidated Financial Statements have been adjusted retrospectively during the three and six months endedMarch 31, 2016:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Three Months Ended
Statements of Operations
Income tax provision	$	17,840	$	(25	)	$	17,815
Net income	$	73,328	$	25		$	73,353
Earnings per common share
Basic	$	0.85	$	—		$	0.85
Diluted	$	0.84	$	—		$	0.84
Six Months Ended
Statements of Operations
Income tax provision	$	26,197	$	(1,660	)	$	24,537
Net income	$	121,975	$	1,660		$	123,635
Earnings per common share
Basic	$	1.42	$	0.02		$	1.44
Diluted	$	1.41	$	0.01		$	1.42
Cash flows from operating activities
Net income	$	121,975	$	1,660		$	123,635
Tax benefit from stock based compensation	$	—	$	1,660		$	1,660
Other noncurrent liabilities	$	2,302	$	(139	)	$	2,163
Net cash flows from operating activities	$	114,824	$	3,181		$	118,005
Cash flows from financing activities
Tax withholding payments related to net settled stock compensation	$	—	$	(3,181	)	$	(3,181	)
Cash flows from financing activities	$	53,547	$	(3,181	)	$	50,366

There was no impact to the Unaudited Condensed Consolidated Balance Sheets upon adoption of the new guidance.

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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.

10

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis, which did not impact its financial position, results of operations or 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 on the balance sheet as a deduction from the carrying amount of the liability. The amendment does 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 amendment contained within ASU No. 2015-03 does not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis.

In addition, the following amounts on the Unaudited Condensed Consolidated Balance Sheets have been adjusted, retrospectively, as of September 30, 2016.

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Other noncurrent assets	$	68,708	$	(8,512	)	$	60,196
Total noncurrent assets	$	712,166	$	(8,512	)	$	703,654
Total assets	$	3,727,082	$	(8,512	)	$	3,718,570
Capitalization and Liabilities
Long-term debt	$	1,063,550	$	(8,512	)	$	1,055,038
Total capitalization	$	2,230,141	$	(8,512	)	$	2,221,629
Total capitalization and liabilities	$	3,727,082	$	(8,512	)	$	3,718,570

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 amendment provides 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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.

Other 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 the Company’s fiscal year ending September 30, 2019, and interim periods within that year. The Company continues to evaluate the provisions of ASC 606, however, based on the review of customer contracts to date, it is not anticipating a material impact to its financial position, results of operations or cash flows upon adoption. The Company anticipates significant new disclosures as a result of the new standard and currently expects to transition to the new guidance using the modified retrospective approach. The Company is also monitoring industry specific developments that may have an impact, including our ability to recognize revenue for contracts where collectability is uncertain.

11

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 or 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 the Company’s fiscal year ending September 30, 2018, and interim periods within that year. Upon adoption, the amendment will be applied on a prospective basis. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Financial Instruments

In January 2016, the FASB issued ASU 2016-01, an amendment to ASC 825, Financial Instruments, to address certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certain fair value changes for financial liabilities measured at fair value. It also simplifies the impairment assessment of equity investments without a readily determinable fair value by requiring a qualitative assessment. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year. Upon adoption, the amendment will be applied on a modified-retrospective basis. The Company evaluated the amendment and noted that, upon adoption, subsequent changes to the fair value of the Company’s available for sale securities will be recorded in the Consolidated Statement of Operations as opposed to other comprehensive income. The Company does not expect any other material impacts to its financial position, results of operations or cash flows upon adoption.

In June 2016, the FASB issued ASU 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. The guidance is effective for the Company’s fiscal year ending September 30, 2021, and interim periods within that year, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.

Leases

In February 2016, the FASB issued ASU 2016-02, an amendment to ASC 842, Leases, which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption. The guidance is effective for the Company’s fiscal year ending September 30, 2020, and interim periods within that year, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Statement of Cash Flows

In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. The Company is currently evaluating the amendment to understand the impact on its consolidated statements of cash flows upon adoption.

In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company’s fiscal year ending September 30, 2019, with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its financial position, results of operations or cash flows upon adoption.

12

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Business Combinations

In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on what accounting to apply to acquisitions.

Gains and Losses from the Derecognition of Nonfinancial Assets

In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. ASU No. 2017-05 may be applied retrospectively for all periods presented or retrospectively with a cumulative-effect adjustment at the date of adoption. The Company is currently evaluating the amendment to understand the impact on its financial position, results from operations, and cash flows upon adoption.

Compensation - Retirement Benefits

In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis for presentation and changes to capitalization of costs will be applied on a prospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on its financial position, results of operations and cash flows upon adoption. The Company is also monitoring industry specific developments on the new guidance to determine the appropriate treatment of these changes in a rate regulated environment.

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 capital investments 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 rates, BGSS and other regulatory tariff riders. NJNG is required to make an annual filing to the BPU by June 1 of each year for review of its BGSS, CIP and various other programs and related rates. Annual rate changes are requested to be effective at the beginning of the following fiscal year. In addition, NJNG is also permitted to request approval of certain rate or program changes on an interim basis. All rate and program changes are subject to proper notification and BPU review and approval.

In September 2016, the BPU approved NJNG's base rate case, effective October 1, 2016, which included an increase in base rates in the amount of $45 million. The base rate increase includes a return on common equity of 9.75 percent, a common equity ratio of 52.5 percent and a depreciation rate of 2.4 percent. The approval also included the five-year extension of SAFE II, rate recovery of NJ RISE capital investment costs through June 30, 2016, recovery of NJNG’s SAFE I, NGV and LNG capital investments and recovery of other costs previously deferred in regulatory assets.

13

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

(Thousands)	March 31, 2017		September 30, 2016
Regulatory assets-current
Conservation Incentive Program	$	23,834	$	36,957
New Jersey Clean Energy Program	6,239		14,232
Underrecovered gas costs	13,271		—
Derivatives at fair value, net	—		3,097
Total current regulatory assets	$	43,344	$	54,286
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	19,067	$	19,595
Liability for future expenditures	165,849		172,000
Deferred income taxes	21,209		20,273
Derivatives at fair value, net	4,392		23,384
SAVEGREEN	15,604		25,208
Postemployment and other benefit costs	151,414		157,027
Deferred Superstorm Sandy costs	14,116		15,201
Other noncurrent regulatory assets	5,273		8,606
Total noncurrent regulatory assets	$	396,924	$	441,294
Regulatory liability-current
Derivatives at fair value, net	$	5,747	$	—
Overrecovered gas costs	—		9,469
Total current regulatory liabilities	$	5,747	$	9,469
Regulatory liabilities-noncurrent
Cost of removal obligation	$	17,224	$	30,549
New Jersey Clean Energy Program	10,269		10,657
Other noncurrent regulatory liabilities	964		205
Total noncurrent regulatory liabilities	$	28,457	$	41,411

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

• On March 31, 2017, NJNG filed its annual petition with the BPU requesting a base rate change in the amount of $4.3 million for the recovery of NJ RISE and SAFE II capital investment costs related to the period ending June 30, 2017, pursuant to the base rate case order dated September 23, 2016. The filing will be updated to reflect actual results in July 2017, with changes to base rates effective October 1, 2017.

14

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 to hedge Canadian dollar denominated gas purchases and/or sales. Therefore, the Company's primary underlying risks include commodity prices, interest rates and foreign currency. These contracts 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.

NJRES

Since NJRES chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, the changes in the fair value of these derivatives 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 exchange rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are typically used to hedge demand fee payments on pipeline capacity, storage and gas purchase agreements. Accordingly, changes in the fair value of foreign exchange contracts are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations. For transactions occurring on or before December 31, 2015, NJRES' foreign exchange contracts were designated as cash flow hedges, and the effective portion of the hedges were recorded in OCI.

As a result of NJRES entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating 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.

Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. The Company applies NPNS accounting to SREC forward and futures contracts entered into on or before December 31, 2015. Effective for contracts executed on or after January 1, 2016, NJRES no longer elects NPNS accounting treatment on all SREC forward sales contracts and recognizes changes in the fair value of these derivatives as a component of operating revenues. Upon settlement of the contract, the related revenue is recognized when the SREC is transferred to the counterparty.

NPNS is a contract-by-contract election and, where it makes sense to do so, we can and may elect normal accounting for certain contracts.

15

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NJNG

Changes in fair value of NJNG's financial commodity derivatives are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis. Accordingly, physical natural gas 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 charged to expense in the current period earnings based on the BGSS factor times the therm sales. Effective for contracts executed on or after January 1, 2016, NJNG no longer elects NPNS accounting treatment on all physical forward commodity contracts. However, since NPNS is a contract-by-contract election, where it makes sense to do so, we can and may elect certain contracts to be normal. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets.

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 a 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 recovered in future rates. Upon settlement, any gain or loss will be amortized into earnings over the life of the future underlying 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
			March 31, 2017						September 30, 2016
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives not designated as hedging instruments:
NJNG:
Physical commodity contracts	Derivatives - current		$	64		$	17		$	235		$	1,154
Financial commodity contracts	Derivatives - current		2,240			928			805			2,979
	Derivatives - noncurrent		—			—			75			386
Interest rate contracts	Derivatives - noncurrent		—			4,392			—			23,073
NJRES:
Physical commodity contracts	Derivatives - current		4,080			2,460			5,994			11,660
	Derivatives - noncurrent		6,084			588			3,987			1,212
Financial commodity contracts	Derivatives - current		25,717			29,127			22,929			45,255
	Derivatives - noncurrent		263			1,125			1,165			581
Foreign currency contracts	Derivatives - current		2			27			1			32
Fair value of derivatives not designated as hedging instruments			$	38,450		$	38,664		$	35,191		$	86,332
Total fair value of derivatives			$	38,450		$	38,664		$	35,191		$	86,332

16

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 at the contract level unit of account 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 March 31, 2017:
Derivative assets:
NJRES
Physical commodity contracts		$	10,164		$	(540	)		$	(200	)		$	9,424
Financial commodity contracts		25,980			(25,068		)		—				912
Foreign currency contracts		2			(2		)		—				—
Total NJRES		$	36,146		$	(25,610	)		$	(200	)		$	10,336
NJNG
Physical commodity contracts		$	64		$	(2	)		$	—			$	62
Financial commodity contracts		2,240			(928		)		(1,312		)		—
Total NJNG		$	2,304		$	(930	)		$	(1,312	)		$	62
Derivative liabilities:
NJRES
Physical commodity contracts		$	3,048		$	(540	)		$	—			$	2,508
Financial commodity contracts		30,252			(25,068		)		(5,184		)		—
Foreign currency contracts		27			(2		)		—				25
Total NJRES		$	33,327		$	(25,610	)		$	(5,184	)		$	2,533
NJNG
Physical commodity contracts		$	17		$	(2	)		$	—			$	15
Financial commodity contracts		928			(928		)		—				—
Interest rate contracts		4,392			—				—				4,392
Total NJNG		$	5,337		$	(930	)		$	—			$	4,407
As of September 30, 2016:
Derivative assets:
NJRES
Physical commodity contracts		$	9,981		$	(2,837	)		$	(755	)		$	6,389
Financial commodity contracts		24,094			(17,945		)		(6,149		)		—
Foreign currency contracts		1			(1		)		—				—
Total NJRES		$	34,076		$	(20,783	)		$	(6,904	)		$	6,389
NJNG
Physical commodity contracts		$	235		$	(31	)		$	—			$	204
Financial commodity contracts		880			(880		)		—				—
Total NJNG		$	1,115		$	(911	)		$	—			$	204
Derivative liabilities:
NJRES
Physical commodity contracts		$	12,872		$	(2,837	)		$	1,200			$	11,235
Financial commodity contracts		45,836			(17,945		)		(27,891		)		—
Foreign currency contracts		32			(1		)		—				31
Total NJRES		$	58,740		$	(20,783	)		$	(26,691	)		$	11,266
NJNG
Physical commodity contracts		$	1,154		$	(31	)		$	—			$	1,123
Financial commodity contracts		3,365			(880		)		(2,485		)		—
Interest rate contracts		23,073			—				—				23,073
Total NJNG		$	27,592		$	(911	)		$	(2,485	)		$	24,196

(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) Includes transactions with NAESB netting election, transactions held by FCMs 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.

17

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NJRES utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical gas to be used for storage injection and its subsequent sale 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 delivered. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments creates volatility in the results of NJRES, although the Company's intended economic results relating to the entire transaction are unaffected.

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

(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended						Six Months Ended
		March 31,						March 31,
Derivatives not designated as hedging instruments:		2017			2016			2017			2016
NJRES:
Physical commodity contracts	Operating revenues	$	4,982		$	9,128		$	6,725		$	21,002
Physical commodity contracts	Gas purchases	(3,982		)	(5,583		)	(12,781		)	(26,820		)
Financial commodity contracts	Gas purchases	38,121			21,820			7,510			63,096
Foreign currency contracts	Gas purchases	53			—			(33		)	—
Total unrealized and realized gains (losses)		$	39,174		$	25,365		$	1,421		$	57,278

NJRES designated its foreign exchange contracts entered into prior to January 1, 2016, as cash flow hedges and, as a result, changes in fair value of the effective portion of the hedges were recorded in OCI and, upon settlement of the contracts, realized gains and (losses) were reclassified from AOCI to gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

The following table reflects the effect of derivative instruments that were designated as cash flow hedges on OCI during the three and six months endedMarch 31, 2016:

(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)
March 31, 2016	Three Months Ended		Six Months Ended			Three Months Ended		Six Months Ended
Foreign currency contracts	$	29	$	(35	)	$	30	$	42

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 approval. At settlement, the resulting gains and/or losses are payable to or recoverable from utility customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings.

The following table reflects the gains (losses) associated with NJNG's derivative instruments as of:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
NJNG:
Physical commodity contracts	$	(3,780	)	$	(14,528	)	$	(2,730	)	$	(14,528	)
Financial commodity contracts	(418		)	(5,151		)	10,760			(10,786		)
Interest rate contracts	(1,690		)	(11,071		)	18,681			(8,705		)
Total unrealized and realized (losses) gains	$	(5,888	)	$	(30,750	)	$	26,711		$	(34,019	)

18

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

		Volume (Bcf)
		March 31, 2017		September 30, 2016
NJNG	Futures	24.6		23.6
	Physical	5.7		9.2
NJRES	Futures	(64.2	)	(79.1	)
	Options	—		1.2
	Physical	64.0		94.6

Not included in the previous table are NJRES' gross notional amount of foreign currency transactions of approximately $2.2 million, NJNG’s treasury lock agreement as previously discussed and 314,500 SRECs at NJRES that are open as of March 31, 2017.

Broker Margin

Futures exchanges have contract specific performance bond requirements, also known as margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily marked-to-market relative to maintenance margin requirements. The Company maintains separate broker margin accounts for NJNG and NJRES. The balances by company are as follows:

(Thousands)	Balance Sheet Location	March 31, 2017		September 30, 2016
NJNG	Broker margin - Current assets	$	3,354	$	4,822
NJRES	Broker margin - Current assets	$	20,250	$	42,822

Due to CME rulebook changes that took effect in January 2017, variation margin is being treated as a settlement payment, rather than collateral. As a result, the Company is now required to present variation margin net with the related derivative assets and/or liabilities on the Unaudited Condensed Consolidated Balance Sheets for any derivatives the Company clears through the CME. This change is being applied on a prospective basis. In September 30, 2016, prior to the rule change, the Company reported the variation margin as a separate unit of account within restricted broker margin on the Unaudited Condensed Consolidated Balance Sheets. There was no impact to the Company’s derivative gains or losses in the Unaudited Condensed Consolidated Statements of Operations as a result of the CME rule amendment.

Wholesale Credit Risk

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

NJR monitors and manages the credit risk of its wholesale 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.

19

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Internally-rated exposure applies to counterparties that are not rated by S&P or Moody's. In these cases, the counterparty'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 March 31, 2017. 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		$	155,318
Noninvestment grade		35,381
Internally rated investment grade		8,974
Internally rated noninvestment grade		27,114
Total		$	226,787

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

Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company's credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on March 31, 2017 and September 30, 2016, was $4.5 million and $23.1 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on March 31, 2017 and September 30, 2016, the Company would have been required to post an additional $4.5 million and $23.1 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.

5. FAIR VALUE

Fair Value of Assets and Liabilities

The fair value of cash and cash equivalents, 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 at NJNG and NJR, including current maturities, excluding capital leases and debt issuance costs, is as follows:

(Thousands)	March 31, 2017		September 30, 2016
Carrying value (1)	$	1,047,045	$	1,082,845
Fair market value	$	1,041,750	$	1,131,077

(1) Excludes capital leases of $45.9 million and $42.2 million as of March 31, 2017 and September 30, 2016, respectively.

20

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NJR utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific issue and the Company's credit rating. As of March 31, 2017, 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 natural gas 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, SREC forward sales 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 the data is:

• widely accepted and public;

• non-proprietary and sourced from an independent third party; and

• 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.

21

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of March 31, 2017:
Assets:
Physical commodity contracts		$	—		$	10,228		$	—	$	10,228
Financial commodity contracts		28,220			—			—		28,220
Financial commodity contracts - foreign exchange		—			2			—		2
Available for sale equity securities - energy industry		65,884			—			—		65,884
Money market funds		65,115			—			—		65,115
Other		1,249			—			—		1,249
Total assets at fair value		$	160,468		$	10,230		$	—	$	170,698
Liabilities:
Physical commodity contracts		$	—		$	3,065		$	—	$	3,065
Financial commodity contracts		31,180			—			—		31,180
Financial commodity contracts - foreign exchange		—			27			—		27
Interest rate contracts		—			4,392			—		4,392
Total liabilities at fair value		$	31,180		$	7,484		$	—	$	38,664
As of September 30, 2016:
Assets:
Physical commodity contracts		$	—		$	10,216		$	—	$	10,216
Financial commodity contracts		24,974			—			—		24,974
Financial commodity contracts - foreign exchange		—			1			—		1
Available for sale equity securities - energy industry		55,789			—			—		55,789
Money market funds		34,072			—			—		34,072
Other		1,444			—			—		1,444
Total assets at fair value		$	116,279		$	10,217		$	—	$	126,496
Liabilities:
Physical commodity contracts		$	—		$	14,026		$	—	$	14,026
Financial commodity contracts		49,201			—			—		49,201
Financial commodity contracts - foreign exchange		—			32			—		32
Interest rate contracts		—			23,073			—		23,073
Total liabilities at fair value		$	49,201		$	37,131		$	—	$	86,332

6. INVESTMENTS IN EQUITY METHOD INVESTEES

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

(Thousands)	March 31, 2017		September 30, 2016
Steckman Ridge (1)	$	121,809	$	123,155
PennEast	31,082		17,993
Total	$	152,891	$	141,148

(1) Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2017 and September 30, 2016. The loans accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

22

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NJR, through a subsidiary, NJR Pipeline Company, formed PennEast with five other investors, and plans to construct and operate a 120-mile pipeline that will extend from northeast Pennsylvania to western New Jersey, which is estimated to be in service by the first quarter of fiscal 2019.

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. 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				Six Months Ended
	March 31,				March 31,
(Thousands, except per share amounts)	2017		2016		2017		2016
Net income, as reported	$	114,702	$	73,353	$	149,631	$	123,635
Basic earnings per share
Weighted average shares of common stock outstanding-basic	86,275		85,834		86,182		85,754
Basic earnings per common share	$1.33		$0.85		$1.74		$1.44
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	86,275		85,834		86,182		85,754
Incremental shares (1)	826		1,024		811		1,024
Weighted average shares of common stock outstanding-diluted	87,101		86,858		86,993		86,778
Diluted earnings per common share (2)	$1.32		$0.84		$1.72		$1.42

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

(2) There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and six months endedMarch 31, 2017 and 2016.

8. COMMON STOCK EQUITY

Changes in common stock equity during the six months endedMarch 31, 2017, were 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, 2016	86,086		$	221,654	$	215,580			$	(15,155	)	$	(81,044	)	$	825,556		$	1,166,591
Net income															149,631			149,631
Other comprehensive income									7,558									7,558
Common stock issued:
Incentive plan	232		581		4,788													5,369
Dividend reinvestment plan (1)	279				(1,266		)					10,994						9,728
Cash dividend declared ($.51 per share)															(44,003		)	(44,003		)
Treasury stock and other	(233	)			(28		)					(8,566		)				(8,594		)
Balance at March 31, 2017	86,364		$	222,235	$	219,074			$	(7,597	)	$	(78,616	)	$	931,184		$	1,286,280

(1) Shares sold through the DRP are issued from treasury stock at average cost, which may differ from the actual market price paid.

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. In December 2015, NJR registered 5 million shares of NJR common stock for issuance under the DRP. NJR raised $9.7 million and $8.2 million of equity through the DRP, by issuing approximately 279,000 and 260,000 shares of treasury stock, during the six months endedMarch 31, 2017 and 2016, respectively.

23

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Accumulated Other Comprehensive Income (Loss)

The following table presents the changes in the components of accumulated other comprehensive income (loss), net of related tax effects during the three months ended March 31, 2017 and 2016:

(Thousands)	Available for Sale Securities			Cash Flow Hedges			Postemployment Benefit Obligation				Total
Balance at December 31, 2016	$	9,713		$	—		$	(19,036	)		$	(9,323	)
Other comprehensive income (loss), net of tax
Other comprehensive income, before reclassifications, net of tax of $(1,808), $0, $0, $(1,808)	3,054			—			—				3,054
Amounts reclassified from accumulated other comprehensive income, net of tax of $1,138, $0, $(217), $921	(1,646		)	—			318			(2)	(1,328		)
Net current-period other comprehensive income, net of tax of $(670), $0, $(217), $(887)	1,408			—			318				1,726
Balance at March 31, 2017	$	11,121		$	—		$	(18,718	)		$	(7,597	)
Balance as of December 31, 2015	$	10,086		$	(33	)	$	(15,523	)		$	(5,470	)
Other comprehensive income, net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(3,154), $(10), $0, $(3,164)	4,500			19			—				4,519
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(11), $(175), $(186)	—			19			257				276
Net current-period other comprehensive income, net of tax of ($3,154), $(21), $(175), $(3,350)	4,500			38			257				4,795
Balance as of March 31, 2016	$	14,586		$	5		$	(15,266	)		$	(675	)

The following table presents the changes in the components of accumulated other comprehensive income (loss), net of related tax effects during the six months ended March 31, 2017 and 2016:

(Thousands)	Available for Sale Securities			Cash Flow Hedges				Postemployment Benefit Obligation				Total
Balance at September 30, 2016	$	4,198		$	—			$	(19,353	)		$	(15,155	)
Other comprehensive income (loss), net of tax
Other comprehensive income, before reclassifications, net of tax of $(6,648), $0, $0, $(6,648)	10,096			—				—				10,096
Amounts reclassified from accumulated other comprehensive income, net of tax of $2,192, $0, $(434), $1,758	(3,173		)	—				635			(2)	(2,538		)
Net current-period other comprehensive income, net of tax of $(4,456), $0, $(434), $(4,890)	6,923			—				635				7,558
Balance at March 31, 2017	$	11,121		$	—			$	(18,718	)		$	(7,597	)
Balance as of September 30, 2015	$	6,385		$	—			$	(15,779	)		$	(9,394	)
Other comprehensive income (loss), net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(5,768), $13, $0, $(5,755)	8,201			(22		)		—				8,179
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(15), $(349), $(364)	—			27			(1)	513			(2)	540
Net current-period other comprehensive income, net of tax of ($5,768), $(2), $(349), $(6,119)	8,201			5				513				8,719
Balance as of March 31, 2016	$	14,586		$	5			$	(15,266	)		$	(675	)

(1) Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Unaudited Condensed Consolidated Statements of Operations. Effective January 1, 2016, the Company elected not to designate its foreign currency derivatives as accounting hedges and, as a result, changes in fair value of the effective portion of the hedges are no longer recorded in OCI.

(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.

24

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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.

Credit Facilities

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

(Thousands)	March 31, 2017			September 30, 2016			Expiration Dates
NJR
Bank revolving credit facilities(1)	$	425,000		$	425,000		September 2020
Notes outstanding at end of period	$	237,900		$	121,700
Weighted average interest rate at end of period	1.75		%	1.43		%
Amount available at end of period (2)	$	173,686		$	288,910
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		May 2019
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2) Letters of credit outstanding total $13.4 million and $14.4 million for March 31, 2017 and September 30, 2016, 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 for both March 31, 2017 and September 30, 2016, which reduces the amount available by the same amount.

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.

Long-term Debt

NJNG

On January 17, 2017, the Company completed the purchase of three FMBs in lieu of redemption with an aggregate principal amount totaling $35.8 million. The FMBs bore interest at rates ranging from 4.5 percent to 4.9 percent. The bonds purchased in lieu of redemption are being held by the Company to provide an opportunity to evaluate remarketing alternatives.

NJNG received $9.6 million and $7.1 million in December 2016 and 2015, 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. NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1 million during the six months endedMarch 31, 2017. NJNG did not exercise early purchase options during the six months endedMarch 31, 2016.

25

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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						Six Months Ended						Three Months Ended						Six Months Ended
	March 31,						March 31,						March 31,						March 31,
(Thousands)	2017			2016			2017			2016			2017			2016			2017			2016
Service cost	$	2,087		$	1,898		$	4,174		$	3,796		$	1,095		$	1,131		$	2,190		$	2,261
Interest cost	2,442			2,835			4,885			5,671			1,387			1,564			2,773			3,128
Expected return on plan assets	(4,828		)	(5,030		)	(9,656		)	(10,059		)	(1,191		)	(1,211		)	(2,383		)	(2,422		)
Recognized actuarial loss	2,206			1,821			4,413			3,641			1,092			818			2,185			1,637
Prior service cost amortization	28			27			55			55			(91		)	(91		)	(182		)	(182		)
Net periodic benefit cost	$	1,935		$	1,551		$	3,871		$	3,104		$	2,292		$	2,211		$	4,583		$	4,422

The Company made a discretionary contribution of $30 million during the first quarter of fiscal 2016, to improve the funded status of the pension plans based on then current actuarial assumptions, which included the adoption of the most recent mortality table. The Company does not expect to be required to make additional contributions to fund the pension plans during fiscal 2017 or 2018 based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets 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 six months endedMarch 31, 2017.

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 six months endedMarch 31, 2017 and 2016, 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 forecasted pre-tax book income and estimated permanent book versus tax differences, as well as 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 forecasted effective tax rates for the six months endedMarch 31, 2017 and 2016, were 15.6 percent and 17.7 percent, respectively. The decreased effective tax rate is due primarily to an increase in forecasted tax credits for the fiscal year ending September 30, 2017, compared with the prior fiscal year. Forecasted tax credits, net of deferred taxes, were $34.6 million and $27.1 million for fiscal 2017 and 2016, respectively.

To the extent there are discrete tax items that are not included in the forecasted effective tax rate, the actual effective tax rate will differ from the estimated annual effective tax rate. The Company recognized $1.5 million and $1.7 million during the six months endedMarch 31, 2017 and 2016, respectively, in additional tax benefits associated with the vesting of share-based awards and the release of a valuation allowance associated with state tax net operating losses, as a component of income tax provision in its Unaudited Condensed Consolidated Statements of Operations. Since the tax effects of the awards and the valuation allowance are treated as discrete items, NJR’s actual effective tax rate was 14.8 percent and 16.6 percent as of March 31, 2017and 2016, respectively.

26

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

As of March 31, 2017, the Company has federal and state income tax net operating losses of approximately $78.7 million and $344.7 million, respectively, which generally have a life of 20 years. The Company has recorded federal and state income tax receivables and deferred tax assets of approximately $27.5 million and $20.2 million, respectively, on the Unaudited Condensed Consolidated Balance Sheets, reflecting the tax benefits associated with these net operating losses. As of September 30, 2016, the Company had federal and state income tax net operating losses of approximately $78.7 million and $310.6 million, respectively, deferred federal and state tax assets of approximately $27.5 million and $18.2 million, respectively.

As of September 30, 2016, the Company recorded a valuation allowance in the amount of $262,000 associated with state net operating loss carryforwards at CR&R. As a result of taxable income generated from the sale of property and available for sale securities during the six months ended March 31, 2017, the Company determined the benefits resulting from the state net operating loss carryforwards at CR&R are more likely than not to be realized prior to their expiration. Accordingly, the Company released the related valuation allowance against these state net operating loss carryforwards. There were no other valuation allowances needed for the Company as of March 31, 2017.

In addition, as of March 31, 2017 and September 30, 2016, the Company had an ITC/PTC carryforward of approximately $111 million and $74 million, respectively, which has a life of 20 years. The Company expects to utilize this entire carryforward, which would begin to expire in fiscal 2034.

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 during 2020 and to 22 percent for property under construction during 2021. For any property that is under construction before 2022, but not placed in service before 2024, the ITC will be reduced to 10 percent. In addition, the PTC was extended 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 2033, for the supply, storage and transportation of natural gas. These contracts include fixed charges of approximately $40 million at current contract rates and volumes for the remainder of the fiscal year, 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 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 March 31, 2017, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2017		2018		2019		2020		2021		Thereafter
NJRES:
Natural gas purchases	$	179,517	$	121,391	$	55,395	$	—	$	—	$	—
Storage demand fees	19,525		28,869		16,195		12,913		8,822		8,580
Pipeline demand fees	38,347		48,509		19,057		8,137		7,605		10,403
Sub-total NJRES	$	237,389	$	198,769	$	90,647	$	21,050	$	16,427	$	18,983
NJNG:
Natural gas purchases	$	45,266	$	11,250	$	—	$	—	$	—	$	—
Storage demand fees	14,568		29,187		25,772		14,476		7,802		11,705
Pipeline demand fees	25,400		81,229		116,976		112,555		90,106		732,538
Sub-total NJNG (1)	$	85,234	$	121,666	$	142,748	$	127,031	$	97,908	$	744,243
Total	$	322,623	$	320,435	$	233,395	$	148,081	$	114,335	$	763,226

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

27

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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 June 2016, the BPU approved NJNG’s December 2015 filing, which requested approval of its MGP expenditures incurred through June 30, 2015, with recovery of $9.4 million annually related to the SBC RA factor with rates effective July 9, 2016. As of March 31, 2017, $19.1 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 $143.9 million to $231.6 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, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets of $172 million as of September 30, 2016, based on the most likely amount at year end and $165.8 million as of March 31, 2017, which includes adjustments for actual expenditures during fiscal 2017. 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

In February 2015, a natural gas fire and explosion occurred in Stafford Township, New Jersey as a result of a natural gas leak emanating from an underground pipe. There were no fatalities, although several employees of NJNG were injured and several homes were damaged. NJNG notified its insurance carrier and believes that any costs associated with the incident, including attorneys’ fees, property damage and other losses, will be substantially covered by insurance. The Company believes the resolution of any potential claims associated with the incident will not have a material effect on its financial condition, results of operations or cash flows. As of March 31, 2017, NJNG estimates that liabilities associated with claims will range between $600,000 and $3.2 million and has accrued the lower end of the range, as we do not believe there is an amount within the range that is more probable than any other.

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.

28

New Jersey Resources Corporation

Part I

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 its 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 Clean Energy Ventures segment consists of capital investments in clean energy projects; the Energy Services segment consists of unregulated wholesale energy operations; 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						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Operating revenues
Natural Gas Distribution
External customers	$	295,546		$	242,536		$	481,102		$	394,142
Clean Energy Ventures
External customers	12,943			7,662			20,510			15,456
Energy Services
External customers (1)	417,608			316,703			756,538			592,885
Intercompany	2,679			3,255			930			5,766
Subtotal	728,776			570,156			1,259,080			1,008,249
Home Services and Other
External customers	7,449			7,292			16,424			15,968
Intercompany	1,055			639			2,086			1,536
Eliminations	(3,734		)	(3,894		)	(3,016		)	(7,302		)
Total	$	733,546		$	574,193		$	1,274,574		$	1,018,451
Depreciation and amortization
Natural Gas Distribution	$	12,263		$	11,598		$	24,293		$	22,836
Clean Energy Ventures	7,923			5,876			14,964			10,986
Energy Services	17			23			33			46
Midstream	2			2			3			3
Subtotal	20,205			17,499			39,293			33,871
Home Services and Other	199			237			420			464
Eliminations	(76		)	8			(125		)	(109		)
Total	$	20,328		$	17,744		$	39,588		$	34,226
Interest income (2)
Natural Gas Distribution	$	97		$	60		$	172		$	128
Energy Services	—			—			—			72
Midstream	512			450			974			714
Subtotal	609			510			1,146			914
Home Services and Other	132			123			253			160
Eliminations	(633		)	(580		)	(1,216		)	(951		)
Total	$	108		$	53		$	183		$	123

(1) Includes sales to Canada, which accounted for 1.5 and 2.9 percent of total operating revenues during the six months endedMarch 31, 2017 and 2016.

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

29

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Interest expense, net of capitalized interest
Natural Gas Distribution	$	6,392		$	4,690		$	13,216		$	9,278
Clean Energy Ventures	4,055			2,552			7,379			4,605
Energy Services	716			168			1,287			376
Midstream	414			130			470			172
Subtotal	11,577			7,540			22,352			14,431
Home Services and Other	123			105			197			105
Eliminations	(264		)	(276		)	(498		)	(390		)
Total	$	11,436		$	7,369		$	22,051		$	14,146
Income tax provision (benefit)
Natural Gas Distribution	$	30,499		$	22,704		$	45,386		$	36,211
Clean Energy Ventures	(24,756		)	(13,916		)	(36,643		)	(25,650		)
Energy Services	16,277			7,805			13,101			12,710
Midstream	1,502			1,530			3,151			3,170
Subtotal	23,522			18,123			24,995			26,441
Home Services and Other	1,066			(1,474		)	821			(2,604		)
Eliminations	(656		)	1,166			134			700
Total	$	23,932		$	17,815		$	25,950		$	24,537
Equity in earnings of affiliates
Midstream	$	6,119		$	3,508		$	9,450		$	7,053
Eliminations	(1,040		)	(1,106		)	(2,060		)	(2,245		)
Total	$	5,079		$	2,402		$	7,390		$	4,808
Net financial earnings
Natural Gas Distribution	$	60,233		$	48,967		$	90,581		$	79,893
Clean Energy Ventures	22,743			11,807			25,585			19,459
Energy Services	15,746			17,005			19,233			27,309
Midstream	4,948			2,228			7,335			4,572
Subtotal	103,670			80,007			142,734			131,233
Home Services and Other	708			(2,022		)	2,250			(1,763		)
Eliminations	(272		)	(80		)	(495		)	(298		)
Total	$	104,106		$	77,905		$	144,489		$	129,172
Capital expenditures
Natural Gas Distribution	$	34,744		$	47,366		$	73,599		$	96,406
Clean Energy Ventures	43,120			25,876			89,905			70,882
Subtotal	77,864			73,242			163,504			167,288
Home Services and Other	345			272			516			1,069
Total	$	78,209		$	73,514		$	164,020		$	168,357
Investments in equity investees
Midstream	$	5,902		$	3,102		$	10,538		$	5,948
Total	$	5,902		$	3,102		$	10,538		$	5,948

30

New Jersey Resources Corporation

Part I

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						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Net financial earnings	$	104,106		$	77,905		$	144,489		$	129,172
Less:
Unrealized (gain) loss on derivative instruments and related transactions	(54,855		)	3,170			(26,553		)	2,035
Tax effect	19,679			(1,152		)	9,922			(739		)
Effects of economic hedging related to natural gas inventory	34,328			(1,054		)	16,389			2,759
Tax effect	(12,334		)	384			(6,130		)	(1,001		)
Net income to NFE tax adjustment	2,586			3,204			1,230			2,483
Net income	$	114,702		$	73,353		$	149,631		$	123,635

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

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

(Thousands)	March 31, 2017			September 30, 2016
Assets at end of period:
Natural Gas Distribution	$	2,572,576		$	2,517,401
Clean Energy Ventures	709,289			665,696
Energy Services	328,372			327,626
Midstream	212,439			186,259
Subtotal	3,822,676			3,696,982
Home Services and Other	126,255			109,487
Intercompany assets(1)	(91,572		)	(87,899		)
Total	$	3,857,359		$	3,718,570

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

31

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

14. RELATED PARTY TRANSACTIONS

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 as a component of regulatory assets.

NJRES may periodically enter into storage or park and loan agreements with its affiliated FERC-jurisdictional natural gas storage facility, Steckman Ridge. As of March 31, 2017, NJRES has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 2020.

Demand fees, net of eliminations, associated with Steckman Ridge were as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
NJNG	$	1,383	$	1,385	$	2,793	$	2,774
NJRES	689		692		1,390		1,377
Total	$	2,072	$	2,077	$	4,183	$	4,151

The following table summarizes demand fees payable to Steckman Ridge as of:

(Thousands)	March 31, 2017		September 30, 2016
NJNG	$	780	$	775
NJRES	376		375
Total	$	1,156	$	1,150

NJNG and NJRES have entered into various asset management agreements, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to NJRES. As of March 31, 2017, NJNG and NJRES had three asset management agreements with expiration dates ranging from October 2017 through March 2018.

NJNG has entered into a 15-year transportation precedent agreement for committed capacity of 180,000 Dths per day with PennEast, which is estimated to be in service by the first quarter of fiscal 2019.

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

OPERATIONS                                                                                                                                                                                   

Critical Accounting Policies

A summary of our critical accounting policies is included in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10-K for the period ended September 30, 2016. Our critical accounting policies have not changed from those reported in the 2016 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 United States and Canada, through its subsidiaries NJNG and NJRES. In addition, we invest in clean energy projects, midstream assets and provide various repair, sales and installations services. A more detailed description of our organizational structure can be found in Item 1. Business of our 2016 Annual Report on Form 10-K.

32

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Business Segments

We have four primary business segments as presented in the chart below:

In addition to the four business segments noted above, we have 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; and commercial real estate holdings at CR&R.

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

	Three Months Ended										Six Months Ended
	March 31,										March 31,
(Thousands)	2017					2016					2017					2016
Net Income (Loss)
Natural Gas Distribution	$	60,233		52	%	$	48,967		66	%	$	90,581		61	%	$	79,893		65	%
Clean Energy Ventures	20,157			18		8,603			12		24,355			16		16,976			14
Energy Services	30,032			26		13,578			19		25,242			17		22,974			18
Midstream	4,948			4		2,228			3		7,335			5		4,572			4
Home Services and Other	708			1		(2,022		)	(3	)	2,250			1		(1,763		)	(2	)
Eliminations (1)	(1,376		)	(1	)	1,999			3		(132		)	—		983			1
Total	$	114,702		100	%	$	73,353		100	%	$	149,631		100	%	$	123,635		100	%

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

The increase in net income during the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016, was driven primarily by increases in gross margin at NJNG due primarily to increased base rates resulting from the settlement of the base rate case, tax credits recognized at NJRCEV and gross margin at NJRES related to increased natural gas prices and an increase in unrealized gains on derivative instruments. The primary drivers of the changes noted above are described in more detail in the individual segment discussions.

33

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Assets by business segment and operations are as follows:

(Thousands)	March 31, 2017					September 30, 2016
Assets
Natural Gas Distribution	$	2,572,576		67	%	$	2,517,401		68	%
Clean Energy Ventures	709,289			18		665,696			18
Energy Services	328,372			9		327,626			9
Midstream	212,439			5		186,259			5
Home Services and Other	126,255			3		109,487			3
Intercompany assets(1)	(91,572		)	(2	)	(87,899		)	(3	)
Total	$	3,857,359		100	%	$	3,718,570		100	%

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

The increase in assets during the six months endedMarch 31, 2017, was due primarily to increased cash and receivables due to seasonality and additional utility plant expenditures at NJNG, additional wind and solar expenditures at NJRCEV and an increase in the market value of the DM Common Units along with increased PennEast capital contributions at Midstream.

Non-GAAP Financial Measures

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. To the extent the Company utilizes forwards, futures, or other derivatives to hedge forecasted SREC production, unrealized gains and losses are also eliminated for NFE purposes.

GAAP requires us, during the interim periods, to estimate our annual effective tax rate and use this rate to calculate the year-to-date tax provision. We also determine an annual estimated effective tax rate for NFE purposes and calculate a quarterly tax adjustment based on the differences between our forecasted net income and our forecasted NFE for the fiscal year. Since the annual estimated effective tax rate is based on certain forecasted assumptions, including estimates surrounding completion of NJRCEV projects, the rate and resulting NFE are subject to change. Since this adjustment is made to reflect the forecasted tax rate, no adjustment is needed at year end.

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 or a replacement of, the comparable GAAP measure and should be read in conjunction with those GAAP results. The following is a reconciliation of consolidated net (loss) income, the most directly comparable GAAP measure, to NFE:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
($ in Thousands)	2017			2016			2017			2016
Net income	$	114,702		$	73,353		$	149,631		$	123,635
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(54,855		)	3,170			(26,553		)	2,035
Tax effect	19,679			(1,152		)	9,922			(739		)
Effects of economic hedging related to natural gas inventory	34,328			(1,054		)	16,389			2,759
Tax effect	(12,334		)	384			(6,130		)	(1,001		)
NFE tax adjustment	2,586			3,204			1,230			2,483
Net financial earnings	$	104,106		$	77,905		$	144,489		$	129,172
Basic earnings per share	$	1.33		$	.85		$	1.74		$	1.44
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(0.64		)	0.04			(0.31		)	0.03
Tax effect	0.23			(0.01		)	0.12			(0.01		)
Effects of economic hedging related to natural gas inventory	0.40			(0.01		)	0.19			0.03
Tax effect	(0.14		)	—			(0.07		)	(0.01		)
NFE tax adjustment	0.03			0.04			0.01			0.03
Basic NFE per share	$	1.21		$	0.91		$	1.68		$	1.51

(1) Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period.

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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										Six Months Ended
	March 31,										March 31,
($ in Thousands)	2017					2016					2017					2016
Net Financial Earnings
Natural Gas Distribution	$	60,233		58	%	$	48,967		63	%	$	90,581		63	%	$	79,893		62	%
Clean Energy Ventures	22,743			22		11,807			15		25,585			18		19,459			15
Energy Services	15,746			15		17,005			22		19,233			13		27,309			21
Midstream	4,948			4		2,228			3		7,335			5		4,572			4
Home Services and Other	708			1		(2,022		)	(3	)	2,250			1		(1,763		)	(2	)
Eliminations(1)	(272		)	—		(80		)	—		(495		)	—		(298		)	—
Total	$	104,106		100	%	$	77,905		100	%	$	144,489		100	%	$	129,172		100	%

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

The increase in NFE during the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016, was due primarily to increased gross margin at NJNG as previously discussed, an increase in tax credits recognized at NJRCEV, an increase at Home Services and Other due primarily to the gain on sale of available for sale securities and property, partially offset by lower financial margin at NJRES due primarily to fewer market opportunities related to transportation assets and timing of certain transactions related to storage withdrawals along with warmer than normal weather during the six months endedMarch 31, 2017.

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 528,000 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, which can negatively impact customer growth, operating and financing costs, fluctuations in commodity prices and customer conservation efforts. These risks include, but are not limited to, adverse economic conditions, 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 natural 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 capital investments and operating costs.

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 to provide safe and reliable service throughout NJNG's territory;

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

• managing its customer growth rate, which NJNG expects will be approximately 1.7 percent annually through fiscal 2019;

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

-    planning and authorization of infrastructure investments;

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OPERATIONS (Continued)

-    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 with the NJDEP and BPU to manage its financial obligations related to remediation activities associated with its former MGP sites.

Base Rate Case

In September 2016, the BPU approved NJNG's base rate case, effective October 1, 2016, which included the following:

• an increase in base rates in the amount of $45 million. The base rate increase includes a return on common equity of 9.75 percent, a common equity ratio of 52.5 percent and an increase in the overall depreciation rate from 2.34 percent to 2.4 percent;

• the five-year extension of SAFE II and estimated cost, excluding AFUDC, is approximately $200 million and related costs to be recovered on an accelerated basis are approximately $157.5 million. The remaining $42.5 million in capital expenditures will be requested for recovery in a future base rate case. As a condition of the extension approval, NJNG is required to file a base rate case no later than November 2019;

• rate recovery of NJ RISE capital investment costs through June 30, 2016, and the filing for recovery of future NJ RISE capital investment costs to be recovered, will occur in conjunction with SAFE II, commencing with the rate recovery filing to be submitted in March 2017;

• recovery of NJNG’s NGV and LNG plant investments; and

• recovery of other costs previously deferred in regulatory assets over seven years.

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 NJNG's capital expenditures, including accruals, for the six months endedMarch 31, 2017, and estimates of expected investments for fiscal 2017 and 2018:

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.

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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)

SAFE and NJ RISE

NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability and integrity of NJNG's gas distribution system.

The BPU approved recovery of SAFE I capital investments through September 30, 2016, and approved the extension of SAFE II for an additional five years to replace the remaining unprotected steel mains and services from its natural gas distribution system at an estimated cost of approximately $200 million, excluding AFUDC. The cost recovery methodology for the $157.5 million associated with the extension of SAFE II was approved in NJNG’s new base rates. The remaining $42.5 million in capital expenditures will be requested for recovery in a future base rate case.

The BPU approved 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. Recovery of NJ RISE investments through June 30, 2016, is included in NJNG’s base rates.

On March 31, 2017, NJNG filed its annual petition with the BPU requesting a base rate change in the amount of $4.3 million for the recovery of NJ RISE and SAFE II capital investment costs, with a weighted cost of capital of 6.9 percent including a return on equity of 9.75 percent, related to the period ending June 30, 2017, pursuant to the base rate case order dated September 23, 2016. The filing will be updated to reflect actual results in July 2017, with changes to base rates effective October 1, 2017.

Southern Reliability Link

The SRL is an approximate 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG's service territory, estimated to cost between $175 million and $180 million. In January 2016, the BPU issued an order approving NJNG's proposed SRL pipeline installation, operation and route selection, as modified by NJNG, including specific requirements regarding permitting, safety and integrity assessment. In March 2016, the BPU issued an order designating the SRL route and exempting the SRL from municipal land use ordinances, regulations, permits and license requirements. The two BPU orders have been appealed by third parties. As construction has not yet commenced, rate treatment for SRL was not included in NJNG’s new base rates. NJNG expects to request rate treatment in a future rate proceeding.

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.

NJNG's total customers include the following:

	March 31, 2017	March 31, 2016
Firm customers
Residential	454,464	443,932
Commercial, industrial & other	28,623	27,722
Residential transport	35,019	37,146
Commercial transport	9,818	10,227
Total firm customers	527,924	519,027
Other	48	65
Total customers	527,972	519,092

During the six months endedMarch 31, 2017 and 2016, respectively, NJNG added 4,130 and 3,655 new customers and converted 406 and 400 existing customers to natural gas heat and other services. This customer growth, as well as commercial customers who switched from interruptible to firm natural gas service, will contribute approximately $2.6 million annually to utility gross margin.

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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)

In addition, NJNG currently expects to add approximately 26,000 to 28,000 new customers during the three-year period of fiscal 2017 to 2019. Based on information from municipalities and developers, as well as external industry analysts and management's experience, NJNG estimates that approximately 55 percent of the growth will come from new construction markets and 45 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 $5.2 million annually, as calculated under NJNG's CIP tariff. See the Natural Gas Distribution Operating Results section of Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations that follows 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.

Since inception, the BPU has approved total SAVEGREEN investments of approximately $219.3 million, of which $143.5 million in grants, rebates and loans has been provided to customers, with a total annual recovery of approximately $20 million. In June 2016, the BPU approved NJNG's extension of SAVEGREEN through December 31, 2018. On October 31, 2016, the BPU approved NJNG’s filing to maintain the existing SAVEGREEN recovery rate. The recovery includes a weighted average cost of capital that ranges from 6.69 percent to 7.76 percent, with a return on equity of 9.75 percent to 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 rate filing. In June 2016, NJNG filed a petition with the BPU to increase its CIP rates effective October 1, 2016, resulting in an 8.2 percent increase to the average residential heat customer’s bill.

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

	Three Months Ended					Six Months Ended
	March 31,					March 31,
(Thousands)	2017			2016		2017			2016
Weather (1)	$	12,943		$	9,431	$	15,928		$	27,593
Usage	(575		)	1,806		(700		)	6,098
Total	$	12,368		$	11,237	$	15,228		$	33,691

(1) Compared with the CIP 20-year average, weather was 11.1 percent and 11.9 percentwarmer-than-normal during the three months ended March 31, 2017 and 2016, respectively, and 9.1 percent and 20.4 percentwarmer-than-normal during the six months endedMarch 31, 2017 and 2016, respectively.

As of March 31, 2017, NJNG has $23.8 million in regulatory assets related to CIP to be collected from customers in future periods on the Unaudited Condensed Consolidated Balance Sheets. As of September 30, 2016, NJNG had $37 million in regulatory assets related to CIP to be collected from customers in future periods on the Unaudited Condensed Consolidated Balance Sheets.

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.

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

OPERATIONS (Continued)

The graph below, which illustrates the daily natural gas prices,⁽¹⁾ shows the change in natural gas commodity prices for the six months endedMarch 31, 2017 and 2016 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 $8.71 and $4.74 and the minimum daily price was $0.36 and $0.74 for the six months endedMarch 31, 2017 and 2016, 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 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 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 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 rate. BGSS rates for its large commercial customers are adjusted monthly based on NYMEX prices.

In June 2016, NJNG filed a petition to decrease its BGSS rate for residential and small commercial customers effective October 1, 2016, resulting in a 5.5 percent decrease to the average residential heat customer’s bill. When combined with the proposed CIP increase, the impact of these rate changes would result in an approximate 2.7 percent increase to the average residential heat customer's bill. This petition included proposed bill credits to be issued during the months of November 2016 through February 2017, as a result of a decline in the wholesale price of natural gas. In September 2016, NJNG notified the BPU that the estimated bill credits would be approximately $48 million. Due to weather being approximately 9.1 percent warmer than normal during the months of November 2016 through February 2017, a total of $42 million in bill credits were issued during fiscal 2017, compared with $61.6 million issued during fiscal 2016.

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New Jersey Resources Corporation

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

OPERATIONS (Continued)

BGSS Incentive Programs

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. 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. Utility gross margin from incentive programs was $6.7 million and $8.3 million during the six months endedMarch 31, 2017 and 2016, respectively. A more detailed discussion of the impacts to utility gross margin can be found in the Natural Gas Distribution Operating Results 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 periodic BGSS gas sales volumes hedged by each November 1 and at least 25 percent of the projected BGSS gas sales 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, significant changes in interest rates can impact NJNG's results. NJNG entered into a treasury lock transaction to fix a benchmark treasury rate associated with debt issuance expected in May 2018. The 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.

Societal Benefits Charge

USF

On September 23, 2016, the BPU approved NJNG's annual USF compliance filing proposing to increase the statewide USF rate, resulting in a .2 percent increase to the average residential heat customer’s bill, effective October 1, 2016.

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 quarterly and adjusts its liability and corresponding regulatory asset as necessary to reflect its expected future remediation obligation. Accordingly, NJNG recognized a regulatory asset and an obligation of $165.8 million as of March 31, 2017, a decrease of $6.2 million, compared with September 30, 2016.

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.

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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)

Operating Results

NJNG's operating results are as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
Operating revenues	$	295,546	$	242,536	$	481,102	$	394,142
Less:
Gas purchases (1)	115,723		86,266		179,909		131,509
Energy and other taxes	17,938		14,496		30,087		22,658
Regulatory rider expense	19,893		21,215		32,494		30,843
Operation and maintenance	33,768		33,882		66,986		63,510
Depreciation and amortization	12,263		11,598		24,293		22,836
Operating income	95,961		75,079		147,333		122,786
Other income, net	1,163		1,282		1,850		2,596
Interest expense, net of capitalized interest	6,392		4,690		13,216		9,278
Income tax provision	30,499		22,704		45,386		36,211
Net income	$	60,233	$	48,967	$	90,581	$	79,893

(1) Includes related party transactions of approximately $3.3 million and $3.9 million for the three months ended March 31, 2017 and 2016, respectively, and $6.1 million and $2.5 million for the six months endedMarch 31, 2017 and 2016, respectively, a portion of which is eliminated in consolidation.

Operating Revenues and Gas Purchases

During the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016, operating revenues increased by 21.9 percent and 22.1 percent, respectively, and gas purchases increased34.1 percent and 36.8 percent, respectively. The factors contributing to the increases (decreases) in operating revenues and gas purchases are as follows:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2017 v. 2016						2017 v. 2016
(Millions)	Operating revenues			Gas purchases			Operating revenues			Gas purchases
Firm sales	$	5.6		$	3.9		$	47.9		$	23.3
Base rate impact	21.9			—			30.0			—
Bill credits (1)	19.3			18.0			19.6			18.3
Off-system sales	8.3			8.4			13.5			13.7
CIP adjustments	1.1			—			(18.5		)	—
Average BGSS rates (2)	(5.9		)	(5.4		)	(12.3		)	(11.5		)
Other (3)	2.7			4.6			6.8			4.6
Total increase	$	53.0		$	29.5		$	87.0		$	48.4

(1) Operating revenues includes changes in sales tax of $1.3 million during both the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016, respectively.

(2) Operating revenues includes changes in sales tax of $(500,000) and $(800,000) during the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016, respectively.

(3) Other includes changes in rider rates, including those related to NJCEP and other programs.

The increases in operating revenues and gas purchases during the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016 were due primarily to:

• increased firm sales due primarily to customer growth and higher usage during the six months endedMarch 31, 2017, related to weather being 11.7 percentcolder;

• increased base rates resulting from the settlement of the base rate case;

• a decrease in bill credits issued to residential and small commercial customers during the months of November 2016 through February 2017 compared with the same period last year;

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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)

• higher off-system sales due primarily to an increase of 66.7 percent and 58.4 percent, respectively, in the average price of gas sold, partially offset by a reduction in volumes of 24.2 percent and 21 percent, respectively; partially offset by

• a decrease in CIP due primarily to weather, partially offset by changes in the CIP as a result of the settlement of the base rate case.

Non-GAAP Financial Measures

Management uses utility gross margin, a non-GAAP financial measure, when evaluating the operating results of NJNG. NJNG's utility gross margin is 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 meaningful basis 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.

Utility Gross Margin

A reconciliation of operating revenues, the closest GAAP financial measure, to NJNG's utility gross margin is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
Operating revenues	$	295,546	$	242,536	$	481,102	$	394,142
Less:
Gas purchases	115,723		86,266		179,909		131,509
Energy and other taxes	16,706		13,246		27,588		20,154
Regulatory rider expense	19,893		21,215		32,494		30,843
Utility gross margin	$	143,224	$	121,809	$	241,111	$	211,636

Utility gross margin consists of three components:

• utility firm gross margin generated from only the delivery component of either a sales tariff or a transportation tariff from residential and commercial customers who receive natural gas service from NJNG;

• BGSS incentive programs, where revenues generated or savings achieved from BPU-approved off-system sales, capacity release or storage incentive programs are shared between customers and NJNG; and

• utility gross margin generated from off-tariff customers, as well as interruptible customers.

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						Six Months Ended
	March 31,						March 31,
	2017			2016			2017			2016
($ in thousands)	Margin		Bcf	Margin		Bcf	Margin		Bcf	Margin		Bcf
Utility gross margin/throughput
Residential	$	96,599	19.7	$	78,673	19.3	$	159,097	32.3	$	133,749	28.2
Commercial, industrial and other	21,119		4.4	18,238		3.7	34,815		6.8	31,517		5.4
Firm transportation	21,165		5.6	19,984		6.2	37,450		10.1	35,531		9.6
Total utility firm gross margin/throughput	138,883		29.7	116,895		29.2	231,362		49.2	200,797		43.2
BGSS incentive programs	2,924		42.5	3,748		55.8	6,708		86.1	8,283		111.7
Interruptible/off-tariff agreements	1,417		11.6	1,166		12.5	3,041		24.9	2,556		28.5
Total utility gross margin/throughput	$	143,224	83.8	$	121,809	97.5	$	241,111	160.2	$	211,636	183.4

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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)

Utility Firm Gross Margin

Utility firm gross margin increased $22 million and $30.6 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the base rate increase of $20.5 million and $28.1 million, respectively. The remaining increase was due to customer growth.

BGSS Incentive Programs

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017 v. 2016				2017 v. 2016
Capacity release		$	(517	)		$	(1,015	)
Storage		(185		)		(395		)
Off-system sales		(122		)		(165		)
Total decrease		$	(824	)		$	(1,575	)

The decrease during the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016, was due primarily to a decrease in the value and volume of capacity release.

Operation and Maintenance Expense

The factors contributing to the (decreases) increases in O&M expense is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017 v. 2016				2017 v. 2016
Compensation and benefits		$	936			$	2,231
Base rate amortization		782				1,528
Shared corporate costs		10				1,201
Donations		(1,000		)		(1,000		)
Other		(842		)		(484		)
Total (decrease) increase		$	(114	)		$	3,476

O&M expense remained relatively flat during the three months ended March 31, 2017, compared with the three months ended March 31, 2016. The increase in O&M expense during the six months endedMarch 31, 2017, compared with the six months endedMarch 31, 2016, was due primarily to:

• increased compensation costs due primarily to increases in headcount, incentives, as well as the timing of capitalized labor, healthcare premiums and increased pension/OPEB benefit costs related to changes in actuarial assumptions, partially offset by implementation of the spot rate method to measure interest and service cost components;

• an increase due to the additional amortization of regulatory assets resulting from the settlement of the base rate case; and

• increased shared corporate costs resulting primarily from increases in headcount, incentives and healthcare premiums; partially offset by

• decreased charitable donations.

Depreciation Expense

Depreciation expense increased$665,000 and $1.5 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, as a result of additional utility plant being placed into service, as well as an increase in the overall depreciation rate from 2.34 percent to 2.4 percent resulting from the settlement of the base rate case.

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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)

Operating Income

Operating income increased$20.9 million and $24.5 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the increase in total utility gross margin of $21.4 million and $29.5 million, respectively, partially offset by the increase in depreciation for the three and six months endedMarch 31, 2017, along with the increase in O&M for the six months endedMarch 31, 2017, as previously discussed.

Income Tax Provision

Income tax provision increased$7.8 million and $9.2 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to an increase in pre-tax income, as well as an increase in the forecasted effective tax rate resulting from an increase in forecasted pre-tax income.

Net Income

Net income increased$11.3 million and $10.7 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the increase in operating income, as previously discussed, partially offset by an increase in the tax provision, as previously discussed, an increase in interest expense associated with higher long-term debt outstanding and a decrease in other income related to AFUDC interest earned on infrastructure projects.

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.

Solar

Since its inception, Clean Energy Ventures has placed a total of 156 MW of solar capacity into service and as of March 31, 2017, had 25.5 MW under construction. We estimate total solar-related capital expenditures for ITC eligible projects during fiscal 2017 to be between $97 million and $110 million. There were no commercial projects placed into service during the six months endedMarch 31, 2017 or 2016.

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 3.5 MW of capacity on 374 homes and 1.8 MW of capacity on 207 homes during the three months ended March 31, 2017 and 2016, respectively, and 6.3 MW of capacity on 688 homes and 2.5 MW of capacity on 291 homes during the six months endedMarch 31, 2017 and 2016, respectively.

Once a solar installation has received the proper certifications and commences operations, 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, predominantly load-serving entities that are required to comply with the solar requirements under New Jersey's renewable portfolio standard. NJRCEV hedges a portion of its expected SREC production through the use of forward sales contracts. 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. The credit will decline to 26 percent for property under construction during 2020 and to 22 percent for property under construction during 2021. The ITC will be reduced to 10 percent for any property that is under construction before 2022, but not placed in service before 2024.

Onshore Wind

Clean Energy Ventures invests in small to mid-size onshore wind projects that fit its investment profile and has a total of 126.6 MW of wind capacity as of March 31, 2017. The wind projects are eligible for PTCs for a 10-year period following commencement of operations and have PPAs of various terms in place, which typically govern the sale of energy, capacity and/or renewable energy credits. A $88.9 million, 39.9 MW wind project in Somerset County, Pennsylvania was completed in December 2016.

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New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Clean Energy Ventures' investments are subject to a variety of factors, such as timing of construction schedules, permitting and regulatory processes, uncertainty of energy prices, as well as solar and wind equipment prices, the ability to secure PPAs, 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 changes in prices on the unhedged portion of SREC production could have a significant adverse impact on earnings with some offset expected from higher wind energy market prices due to the PTC phase out and/or improved efficiencies from lower costs for related turbine technology. Wind projects for which construction of a 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. PTCs will be phased out from 100 percent in 2016 to 80 percent in 2017, 60 percent in 2018, 40 percent in 2019 and zero thereafter. In addition, since the primary contributors toward the value of qualifying clean energy 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 clean energy credits, could also significantly affect earnings.

Operating Results

The financial results of NJRCEV are summarized as follows:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Operating revenues	$	12,943		$	7,662		$	20,510		$	15,456
Less:
Operation and maintenance	6,145			4,775			10,549			8,632
Depreciation and amortization	7,923			5,876			14,964			10,986
Other taxes	234			203			649			456
Operating loss	(1,359		)	(3,192		)	(5,652		)	(4,618		)
Other income, net	815			431			743			549
Interest expense, net	4,055			2,552			7,379			4,605
Income tax benefit	(24,756		)	(13,916		)	(36,643		)	(25,650		)
Net income	$	20,157		$	8,603		$	24,355		$	16,976

Operating Revenues

Operating revenues increased$5.3 million and $5.1 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, and is comprised of the following:

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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)

SREC activity consisted of the following:

	Six Months Ended
	March 31,
	2017		2016
Beginning balance as of October 1,	24,135		33,203
SRECs generated	69,436		57,595
SRECs delivered	(42,669	)	(37,232	)
Ending balance as of March 31,	50,902		53,566

During the six months endedMarch 31, 2017, SRECs generated increased20.6 percent, compared with the six months endedMarch 31, 2016. The average SREC sales price was $217 and $205 during the three months ended March 31, 2017, and 2016, respectively, and $223 and $212 during the six months endedMarch 31, 2017, and 2016, respectively.

The following table reflects the hedged percentage of SREC inventory and projected SREC production related to its in-service commercial and residential assets:

Energy Year (1)	Percent of SRECs Hedged
2017	95%
2018	88%

(1) Energy years are compliance periods for New Jersey's renewable portfolio standard that run from June 1 to May 31.

There are no direct costs associated with the production of SRECs/RECs by our solar and wind 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.

Operation and Maintenance Expense

O&M expense increased$1.4 million and $1.9 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to additional maintenance and administrative costs associated with wind and solar projects placed in service and higher shared corporate costs resulting primarily from increases in headcount, incentives and healthcare premiums.

Depreciation Expense

Depreciation expense increased $2 million and $4 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, as a result of increases in solar and wind capital additions.

Income Tax (Benefit)

Our effective tax rate is significantly impacted by the amount of tax credits forecast to be earned during the fiscal year. GAAP requires us to estimate our 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, our estimated annual effective tax rate for fiscal 2017 is 15.6 percent and $22.4 million and $29.8 million related to tax credits, net of deferred taxes, were recognized during the three and six months endedMarch 31, 2017, respectively. The annual effective tax rate as of March 31, 2016, was 17.7 percent and $11.7 million and $21.9 million related to tax credits, net of deferred taxes, were recognized during the three and six months endedMarch 31, 2016, respectively.

Net Income

Net income increased$11.6 million and $7.4 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to an increase in tax benefits recognized due primarily to a lower estimated annual effective tax rate, as well as higher consolidated pre-tax income, an increase in operating revenues as described above, partially offset by increased costs related to depreciation and O&M as discussed above and an increase in interest expense due to higher debt associated with capital expenditures.

46

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Non-GAAP Financial Measures

Management of the Company uses NFE, a non-GAAP financial measure, when evaluating the operating results of Clean Energy Ventures. GAAP requires us, during the interim periods, to estimate our annual effective tax rate and use this rate to calculate the year-to-date tax provision. We also determine an annual estimated effective tax rate for NFE purposes and calculate a quarterly tax adjustment based on the differences between our forecasted net income and our forecasted NFE for the fiscal year. This adjustment is applied to NJRCEV, as such adjustment is primarily related to tax credits generated by NJRCEV. Since this adjustment is made to reflect the forecasted tax rate, no adjustment is needed at year end.

Accordingly, for NFE purposes, the annual estimated effective tax rate for fiscal 2017 is 12.7 percent and $32.7 million and $39.8 million of tax credits, net of deferred taxes, were recognized during the three and six months endedMarch 31, 2017, respectively. During the three and six months endedMarch 31, 2016, the annual estimated effective tax rate for fiscal 2016 was 16.6 percent and $14.9 million and $24.5 million of tax credits, net of deferred taxes, were recognized during the three and six months endedMarch 31, 2016, respectively.

Since the annual estimated effective tax rate is based on certain forecasted assumptions, including estimates surrounding completion of projects, the rate and resulting NFE are subject to change. The details of such tax adjustments can be found in the table below. 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 measure to NFE is as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
Net income	$	20,157	$	8,603	$	24,355	$	16,976
Add:
Net income to NFE tax adjustment	2,586		3,204		1,230		2,483
Net financial earnings	$	22,743	$	11,807	$	25,585	$	19,459

Energy Services Segment

Overview

NJRES markets and sells natural gas to wholesale customers and manages natural gas storage and transportation assets throughout major market areas across North America. NJRES maintains a strategic portfolio of natural gas storage and transportation contracts that it utilizes in conjunction with its market expertise to provide service and value to its customers. Availability of these storage and transportation contracts from a time and location perspective allows NJRES to generate market opportunities by capturing price differentials over specific time horizons and between geographic market locations.

NJRES also provides management of storage and transportation assets for natural gas producers and regulated utilities, as well as commodity supply for various end-users. These management transactions typically involve the release of producer/utility owned storage and/or transportation capacity in combination with either an obligation to purchase and/or deliver physical natural gas. In addition to the contractual purchase and/or sale of physical natural gas, NJRES generates or pays fee-based margin in exchange for its active management and may provide the producer and/or utility with additional margin based on actual results.

In conjunction with the active management of these contracts, NJRES generates financial margin by identifying market opportunities and simultaneously entering into natural gas purchase/sale, storage or transportation contracts and financial derivative contracts. In cases where storage is utilized to fulfill these contracts, these forecast sales and/or purchases are economically hedged through the use of financial derivative contracts. The financial derivative contracts consist primarily of exchange-traded futures, options, and swap contracts, and are frequently used to lock in transactional cash flows and to help manage volatility in natural gas market prices. Generally, when its storage and transportation contracts are exposed to periods of increased market volatility, NJRES is able to implement strategies that allow them to capture margin by improving the respective time or geographic spreads on a forward basis.

47

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

NJRES accounts for its physical and financial derivative instruments at fair value on the Unaudited Condensed Consolidated Balance Sheets. Changes in fair value 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, SRECs and foreign currency from the original transaction price compared with the market price of natural gas at each reporting date. Volatility in earnings can also occur as a result of timing differences between derivative settlements and the sale of the underlying physical commodity. For example, when a financial instrument settles and the physical natural gas is injected into storage, the realized gains and losses associated with the financial instrument are recognized in earnings. However, the gains and losses associated with the physical natural gas are not recognized in earnings until the natural gas inventory is withdrawn, at which time NJRES realizes the entire margin on the transaction.

Operating Results

The financial results of NJRES are summarized as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
Operating revenues (1)	$	420,287	$	319,958	$	757,468	$	598,651
Less:
Gas purchases (including demand charges (2)(3))	368,482		293,994		707,569		554,233
Operation and maintenance	4,451		4,174		9,469		7,931
Depreciation and amortization	17		23		33		46
Other taxes	312		216		767		453
Operating income	47,025		21,551		39,630		35,988
Other income	—		—		—		72
Interest expense, net	716		168		1,287		376
Income tax provision	16,277		7,805		13,101		12,710
Net income	$	30,032	$	13,578	$	25,242	$	22,974

(1) Includes related party transactions of approximately $2.7 million and $3.3 million for the three months ended March 31, 2017 and 2016, respectively, and $930,000 and $5.8 million for the six months endedMarch 31, 2017 and 2016, respectively, which is eliminated in consolidation.

(2) 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.

(3) Includes related party transactions of approximately $1.2 million and $6.1 million for the three months ended March 31, 2017 and 2016, respectively, and $2.3 million and $12.3 million for the six months endedMarch 31, 2017 and 2016, respectively, a portion of which is eliminated in consolidation.

NJRES' portfolio of financial derivative instruments are composed of:

	Six Months Ended
	March 31,
(in Bcf)	2017	2016
Net short futures contracts	64.2	88.6
Net long options	—	3.6

Operating Revenues and Gas Purchases

Operating revenues increased$100.3 million and gas purchases increased$74.5 million during the three months ended March 31, 2017, compared with the three months ended March 31, 2016, due primarily to an approximate 58.9 percentincrease in the average price of natural gas, as well as an increase of $63 million in unrealized gains on derivative instruments, partially offset by an increase of $35.4 million related to changes in the economic hedging of natural gas inventory and a 12.4 percentdecrease in sales volumes.

Operating revenues increased$158.8 million and gas purchases increased$153.3 million during the six months endedMarch 31, 2017, compared with the six months endedMarch 31, 2016, due primarily to an approximate 44.5 percentincrease in the average price of natural gas and an increase of $30 million in unrealized gains on derivative instruments, partially offset by a decrease of $13.6 million related to changes in the economic hedging of natural gas inventory and a 8.9 percentdecrease in sales volumes.

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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)

Future results at NJRES are contingent upon natural gas market price volatility driven by variations in both the supply and demand balances caused by weather and other factors. As a result, variations in weather patterns in the key market areas served may affect earnings during the fiscal year. Changes in market fundamentals such as an increase in supply and decrease in demand due to milder temperatures, and reduced volatility can negatively impact NJRES' earnings. See Item 2. Management's Discussion and Analysisof Financial Condition and Results of Operations - Natural Gas Distribution Segment forTetco M-3 Daily Prices, which illustrates the daily natural gas prices in the Northeast market region.

Operation and Maintenance Expense

O&M expense increased$277,000 and $1.5 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to increases in compensation and shared corporate costs.

Net Income

Net income increased$16.5 million and $2.3 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to higher gross margin as previously discussed, partially offset by an increase in the tax provision related primarily to the increase in unrealized gains on derivative instruments, an increase in interest expense due primarily to increased borrowing and higher O&M as previously discussed.

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 based on removing timing differences associated with certain derivative instruments, as discussed above. Management views these measures as 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 the settlement of derivative instruments. To the extent that there are unanticipated impacts from changes in the market value related to the effectiveness of economic hedges, NJRES' actual non-GAAP results can differ from the results anticipated at the outset 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 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 withdrawn from storage, 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						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Operating revenues (1)	$	420,287		$	319,958		$	757,468		$	598,651
Less: Gas purchases	368,482			293,994			707,569			554,233
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(56,581		)	6,432			(25,989		)	4,045
Effects of economic hedging related to natural gas inventory (2)	34,328			(1,054		)	16,389			2,759
Financial margin	$	29,552		$	31,342		$	40,299		$	51,222

(1) Includes unrealized (gains) related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $1.7 million and $(3.3) million for the three months endedMarch 31, 2017 and 2016, respectively, and $(564,000) and $(2) million for thesix months endedMarch 31, 2017 and 2016, respectively.

(2) Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period.

49

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

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

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Operating income	$	47,025		$	21,551		$	39,630		$	35,988
Add:
Operation and maintenance	4,451			4,174			9,469			7,931
Depreciation and amortization	17			23			33			46
Other taxes	312			216			767			453
Subtotal	51,805			25,964			49,899			44,418
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(56,581		)	6,432			(25,989		)	4,045
Effects of economic hedging related to natural gas inventory	34,328			(1,054		)	16,389			2,759
Financial margin	$	29,552		$	31,342		$	40,299		$	51,222

Financial margin decreased$1.8 million and $10.9 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to fewer market opportunities related to transportation assets and timing of certain transactions related to storage withdrawals along with warmer than normal weather during the six months endedMarch 31, 2017.

Net Financial Earnings

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

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Net income	$	30,032		$	13,578		$	25,242		$	22,974
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(56,581		)	6,432			(25,989		)	4,045
Tax effect (1)	20,301			(2,335		)	9,721			(1,468		)
Effects of economic hedging related to natural gas inventory	34,328			(1,054		)	16,389			2,759
Tax effect	(12,334		)	384			(6,130		)	(1,001		)
Net financial earnings	$	15,746		$	17,005		$	19,233		$	27,309

(1) Includes taxes related to an intercompany transaction between NJNG and NJRES that have been eliminated in consolidation of approximately $622,000 and $1.2 million during the three months ended March 31, 2017 and 2016, respectively, and $201,000 and $729,000 for thesix months endedMarch 31, 2017 and 2016, respectively.

NFE decreased$1.3 million and $8.1 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to lower financial margin and higher O&M, as previously discussed, partially offset by a decrease in the tax provision related to the decrease in financial margin.

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 in an active and liquid natural marketplace, volatility in the natural gas market due to weather or other fundamental market factors impacting supply and/or demand, transportation, storage and/or other market arbitrage opportunities, sufficient liquidity in the overall energy trading market, and continued access to liquidity in the capital markets.

Midstream Segment

Overview

Our Midstream segment invests in natural gas assets, such as natural gas transportation and storage facilities. We believe 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 us. To that end, we have 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 is estimated to be in service by the first quarter of fiscal 2019. As of March 31, 2017, our net investments in Steckman Ridge and PennEast were $121.8 million and $31.1 million, respectively.

50

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Operating Results

The financial results of our Midstream segment are summarized as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
Equity in earnings of affiliates	$	6,119	$	3,508	$	9,450	$	7,053
Other income, net	$	991	$	843	$	1,908	$	1,475
Income tax provision	$	1,502	$	1,530	$	3,151	$	3,170
Net income	$	4,948	$	2,228	$	7,335	$	4,572

Equity in earnings of affiliates increased$2.6 million and $2.4 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the AFUDC interest earned at PennEast.

Other income increased$148,000 and $433,000 for the three and six months endedMarch 31, 2017, compared with the three and six months endedMarch 31, 2016, respectively, due primarily to increased dividend income from the DM Common Units.

Net income increased$2.7 million and $2.8 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the increase in equity in earnings of affiliates, as discussed above.

Home Services and Other Operations

Overview

The financial results of Home Services and Other consist primarily of the operating results of NJRHS and CR&R. NJRHS provides service, sales and installation of appliances to approximately 113,000 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 undeveloped land. Home Services and Other also includes organizational expenses incurred at NJR. NJR Energy, a subsidiary of CR&R, which invested in other energy-related ventures, was dissolved on November 28, 2016, and all assets were moved to CR&R during the first quarter of fiscal 2017.

Operating Results

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

	Three Months Ended					Six Months Ended
	March 31,					March 31,
(Thousands)	2017		2016			2017		2016
Operating revenues	$	8,504	$	7,931		$	18,510	$	17,504
Operation and maintenance	$	8,417	$	10,383		$	18,581	$	19,776
Energy and other taxes	$	993	$	927		$	2,069	$	1,910
Other income, net	$	3,001	$	225		$	5,828	$	384
Income tax provision (benefit)	$	1,066	$	(1,474	)	$	821	$	(2,604	)
Net income (loss)	$	708	$	(2,022	)	$	2,250	$	(1,763	)

Operating revenue increased$573,000 and $1 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to increased furnace/air conditioner combination installations at NJRHS related to increased marketing promotions as well as increased solar installations.

O&M expense decreased$2 million and $1.2 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to a pre-tax gain of $1.9 million, associated with the sale of a 56,400 square foot office building on five acres of land located in Monmouth County in March 2017, partially off set by increased labor costs resulting from higher headcount and incentives as well as increased healthcare premiums.

51

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)

Other income increased $2.8 million and $5.4 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the sale of available for sale securities, which resulted in a pre-tax gain of $2.8 million and $5.4 million, respectively.

The income tax provision increased $2.5 million and $3.4 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the increase in other income as described above.

Net income increased$2.7 million and $4 million during the three and six months endedMarch 31, 2017, respectively, compared with the three and six months endedMarch 31, 2016, due primarily to the increase in other income and operating revenue along with the decrease in O&M, partially offset by the increase in the income tax provision discussed above.

Liquidity and Capital Resources

Our 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.

Our consolidated capital structure was as follows:

	March 31, 2017		September 30, 2016
Common stock equity	50	%	48	%
Long-term debt	39		44
Short-term debt	11		8
Total	100	%	100	%

Common Stock Equity

We satisfy our external common equity requirements, if any, through issuances of our common stock, including the proceeds from stock issuances under our DRP. The DRP allows us, at our option, to use treasury shares or newly issued shares to raise capital. On December 14, 2015, we registered an additional 5 million shares of our common stock for issuance under the DRP. We raised $9.7 million and $8.2 million of equity through the DRP, by issuing approximately 279,000 and 260,000 shares of treasury stock, during the six months endedMarch 31, 2017 and 2016, respectively.

In 1996, the Board of Directors authorized us to implement a share repurchase program, which was expanded seven times since the inception of the program, authorizing a total of 19.5 million shares of common stock for repurchase. As of March 31, 2017, we repurchased a total of approximately 17 million of those shares and may repurchase an additional 2.4 million shares under the approved program. There were 105,000 and 34,700 shares repurchased during the six months endedMarch 31, 2017 and 2016, 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.

We believe that our existing borrowing availability, equity proceeds and cash flow from operations will be sufficient to satisfy our and our 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 our DRP, including utilizing the waiver discount feature.

We believe that as of March 31, 2017, NJR and NJNG were, and currently are, in compliance with all existing debt covenants, both financial and non-financial.

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

OPERATIONS (Continued)

Short-Term Debt

We use our short-term borrowings primarily to finance NJRES' short-term liquidity needs, Midstream segment's PennEast contributions, share repurchases and, on an initial basis, NJRCEV's investments. 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 March 31, 2017, NJR had a revolving credit facility totaling $425 million, as described below, with $173.7 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 March 31, 2017, 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 $249.3 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 in November and December.

Short-term borrowings were as follows:

	Three Months Ended			Six Months Ended
(Thousands)	March 31, 2017
NJR
Notes Payable to banks:
Balance at end of period	$	237,900			$	237,900
Weighted average interest rate at end of period	1.75		%		1.75		%
Average balance for the period	$	253,768			$	227,466
Weighted average interest rate for average balance	1.70		%		1.58		%
Month end maximum for the period	$	258,500			$	284,600

NJR

As noted above, based on its average borrowings during the six months endedMarch 31, 2017, NJR's average interest rate was 1.58 percent, resulting in interest expense of $1.8 million.

As of March 31, 2017, NJR had six letters of credit outstanding totaling $13.4 million, which reduced 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.

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

NJNG

NJNG had no outstanding short-term borrowings during the six months endedMarch 31, 2017.

As of March 31, 2017, NJNG had two letters of credit outstanding for $731,000, which reduced 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.

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

OPERATIONS (Continued)

Short-Term Debt Covenants

Borrowings under the NJR Credit Facility and the 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;

•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

As of March 31, 2017, NJR has the following outstanding:

•$50 million of 6.05 percent senior notes due September 2017;

•$25 million of 2.51 percent senior notes due September 15, 2018;

•$50 million of 3.25 percent senior notes due September 2022;

•$100 million of 3.48 percent senior notes due November 7, 2024;

•$50 million of 3.2 percent senior notes due August 18, 2023; and

•$100 million of 3.54 percent senior notes due August 18, 2026.

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

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

OPERATIONS (Continued)

NJNG

As of March 31, 2017, NJNG's long-term debt consisted of $575 million in fixed-rate debt issuances secured by the Mortgage Indenture, with maturities ranging from 2018 to 2046, $97 million in secured variable rate debt with maturities ranging from 2027 to 2041 and $34.2 million in capital leases with various maturities ranging from 2017 to 2025.

On January 17, 2017, the Company completed the purchase of three FMBs in lieu of redemption with an aggregate principal amount totaling $35.8 million. The FMBs bore interest at rates ranging from 4.5 percent to 4.9 percent. The bonds purchased in lieu of redemption are being held by the Company to provide an opportunity to evaluate remarketing alternatives.

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

Long-Term Debt Covenants and Default Provisions

The NJR and NJNG long-term debt instruments contain customary representations and warranties for transactions 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;

•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 FMBs 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.

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

OPERATIONS (Continued)

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 NJNG, may sell the trust estate, or proceed to foreclose the lien pursuant to the Mortgage Indenture. The interest rate on defaulted principal and interest, to the extent permitted by law, on the FMBs 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 $9.6 million and $7.1 million in December 2016 and 2015, respectively, in connection with the sale-leaseback of its natural gas meters. NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1 million during the six months endedMarch 31, 2017. NJNG did not exercise early purchase options during the six months endedMarch 31, 2016. NJNG continues to evaluate this sale-leaseback program based on current market conditions.

Contractual Obligations

NJNG's total capital expenditures are projected to be $177.6 million and $337.2 million, in fiscal 2017 and 2018, respectively. Total capital expenditures spent or accrued during the six months endedMarch 31, 2017 were $74.1 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 and the issuance of long-term debt. As of March 31, 2017, NJNG's future MGP expenditures are estimated to be $165.8 million. For a more detailed description of MGP expenditures 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.

NJRCEV's expenditures include clean energy projects that support our goal to promote renewable energy. Accordingly, NJRCEV enters into agreements to install solar equipment involving both residential and commercial projects. During the six months endedMarch 31, 2017, capital expenditures related to the purchase and installation of solar equipment were $57.6 million. An additional $40.7 million has been committed for solar projects to be placed into service during fiscal 2017 and beyond. We estimate solar-related capital expenditures for ITC eligible projects in fiscal 2017 to be between $97 million and $110 million.

During the first quarter of fiscal 2017, NJRCEV completed construction of a $88.9 million, 39.9 MW onshore wind project in Somerset County, Pennsylvania. NJRCEV continues to seek additional wind investment opportunities.

Capital expenditures related to clean energy 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 $25 million and $35 million in fiscal 2017.

NJRES does not currently anticipate any significant capital expenditures in fiscal 2017 and 2018.

More detailed information regarding contractual obligations is contained in Liquidity and Capital Resources - Contractual Obligations section of Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10-K for the period ended September 30, 2016.

Off-Balance-Sheet Arrangements

Our off-balance-sheet arrangements consist of guarantees covering approximately $268.8 million of natural gas purchases, SREC sales and demand fee commitments and outstanding letters of credit totaling $14.1 million.

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

OPERATIONS (Continued)

Cash Flow

Operating Activities

Cash flows from operating activities during the six months endedMarch 31, 2017, totaled $171.8 million compared with $118 million during the six months endedMarch 31, 2016. Operating cash flows are primarily affected by variations in working capital, which can be impacted by several factors, including:

•seasonality of our business;

•fluctuations in wholesale natural gas prices and other energy 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;

•impact of unusual weather patterns on our wholesale business;

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

•volumes of natural gas purchased and sold; and

•timing of SREC deliveries.

The increase of $53.8 million in operating cash flows during the six months endedMarch 31, 2017, compared with the six months endedMarch 31, 2016, was due primarily to a discretionary contribution of $30 million to our pension plan during fiscal 2016 that did not recur in fiscal 2017 and increased recovery of regulatory assets versus the timing of expenditures, partially offset by increased working capital at NJNG due primarily to colder weather and increased customer usage.

Investing Activities

Cash flows used in investing activities totaled $155.9 million during six months endedMarch 31, 2017, compared with $171.4 million during the six months endedMarch 31, 2016. The decrease of $15.6 million was due primarily to a decrease in utility plant expenditures of $22.8 million, proceeds of $6.6 million from the sale of available for sale securities and $9.4 million from the sale of an office building, net of closing costs along with a decrease in wind investment expenditures of $6.9 million, partially offset by an increase of $26 million in solar expenditures and $4.6 million for its investment in PennEast.

Financing Activities

Financing cash flows generally are seasonal in nature and are impacted by the volatility in pricing in the natural gas and other energy 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 clean energy investments at NJRCEV.

Cash flows from financing activities totaled $39.3 million during the six months endedMarch 31, 2017, compared with $50.4 million during the six months endedMarch 31, 2016. The decrease of $11.1 million is due primarily to the call and purchase of three FMBs in lieu of redemption totaling $35.8 million, along with an increase in treasury shares repurchased, partially offset by an increase in short-term borrowings at NJR.

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Part I

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

OPERATIONS (Continued)

Credit Ratings

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

These ratings were reaffirmed by S&P on July 19, 2016 and by Moody’s on October 4, 2016. 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 NJR'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 NJNG'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.

Our regulated and deregulated businesses are subject to market risk due to fluctuations in the price of natural gas. To economically hedge against such fluctuations, we have entered into forwards, futures, options and swap agreements. To manage these derivative instruments, we have well-defined risk management policies and procedures that include daily monitoring of volumetric limits and monetary guidelines. Our natural gas businesses are conducted through two of our operating subsidiaries. NJNG is a regulated utility that uses futures, options and swaps to provide relative price stability, 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.

The following table reflects the changes in the fair market value of financial derivatives related to natural gas purchases and sales:

	Balance				Increase			Less				Balance
(Thousands)	September 30, 2016				(Decrease) in Fair Market Value			Amounts Settled				March 31, 2017
NJNG		$	(2,485	)		$	6,831		$	3,034			$	1,312
NJRES		(21,742		)		5,262			(12,208		)		(4,272		)
Total		$	(24,227	)		$	12,093		$	(9,174	)		$	(2,960	)

There were no changes in methods of valuations during the six months endedMarch 31, 2017.

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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 March 31, 2017, excluding foreign exchange contracts discussed below, by method of valuation and by maturity for each fiscal year period:

(Thousands)	2017			2018			2019 - 2021				After 2021			Total Fair Value
Price based on ICE	(326		)	(2,257		)		(377		)		—			(2,960		)
Total	$	(326	)	$	(2,257	)		$	(377	)		$	—		$	(2,960	)

The following is a summary of financial derivatives by type as of March 31, 2017:

		Volume Bcf		Price per MMBtu(1)	Amounts included in Derivatives (Thousands)
NJNG	Futures	24.6		$2.26-$3.36		$	1,312
NJRES	Futures	(64.2	)	$1.63-$4.76		(4,272		)
Total						$	(2,960	)

(1) Million British thermal unit

The following table reflects the changes in the fair market value of physical commodity contracts:

	Balance				Increase			Less			Balance
(Thousands)	September 30, 2016				(Decrease) in Fair Market Value			Amounts Settled			March 31, 2017
NJNG - Prices based on other external data		$	(919	)		(961	)		(1,927	)		$	47
NJRES - Prices based on other external data		(2,891		)		(2,280	)		(12,287	)		7,116
Total		$	(3,810	)		(3,241	)		(14,214	)		$	7,163

The following table reflects the changes in the fair market value of interest rate contracts:

	Balance				Increase		Less		Balance
(Thousands)	September 30, 2016				(Decrease) in Fair Market Value		Amounts Settled		March 31, 2017
NJNG - Prices based on other external data		$	(23,073	)		18,681		—		$	(4,392	)

Our market price risk is predominately linked with changes in the price of natural gas at the Henry Hub, the delivery point for the NYMEX natural gas futures contracts. Based on price sensitivity analysis, an illustrative 10 percent movement in the natural gas futures contract price, for example, increases (decreases) the reported derivative fair value of all open, unadjusted Henry Hub natural gas futures and fixed price swap positions by approximately $13.9 million. This analysis does not include potential changes to reported credit adjustments embedded in the $(7.1) 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	$	—		$	(6,935	)	$	(13,871	)	$	(20,806	)	$	(27,742	)
Ending derivative fair value	$	(7,081	)	$	(14,016	)	$	(20,952	)	$	(27,887	)	$	(34,823	)
Percent decrease in NYMEX natural gas futures prices	0%			(5)%			(10)%			(15)%			(20)%
Estimated change in derivative fair value	$	—		$	6,935		$	13,871		$	20,806		$	27,742
Ending derivative fair value	$	(7,081	)	$	(146	)	$	6,790		$	13,725		$	20,661

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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 non-investment grade counterparties, as of March 31, 2017. 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 March 31, 2017, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	148,951		$	122,365
Noninvestment grade		35,145			16,767
Internally rated investment grade		8,892			2,432
Internally rated noninvestment grade		11,877			2,926
Total		$	204,865		$	144,490

NJNG's counterparty credit exposure as of March 31, 2017, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	6,367		$	5,501
Noninvestment grade		236			—
Internally rated investment grade		82			—
Internally rated noninvestment grade		15,237			3,829
Total		$	21,922		$	9,330

Due to the inherent volatility in the market price for natural gas, electricity 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 (for example, failed to make payment for natural gas received), we 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 exceeds the original contract price. Any such loss could have a material impact on our 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 our Annual Report on Form 10-K for the period ended September 30, 2016.

Effects of Interest Rate and Foreign Currency Rate Fluctuations

We are also exposed to changes in interest rates on our debt hedges, variable rate debt and changes in foreign currency rates for our business conducted in Canada using Canadian dollars. We do not believe an immediate 10 percent increase or decrease in interest rates or foreign currency rates would have a material effect on our operating results or cash flows.

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 our utility subsidiary. We attempt 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 our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act), as of the end of the period covered by this report. Based on this evaluation, our principal executive officer and principal financial officer concluded that, as of end of the period covered by this report, our disclosure controls and procedures are effective, to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act, is recorded, processed, summarized and reported, within the time periods specified in the U.S. Securities and Exchange Commission's rules and forms, and that such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

There has been no change in internal control over financial reporting (as such term is defined in Exchange Act Rule 13a-15(f)) that occurred during the quarter ended March 31, 2017, 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 our Annual Report on Form 10-K for the year ended September 30, 2016, 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 March 31, 2017, 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 we attempt to identify, manage and mitigate risks and uncertainties associated with our 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 our 2016 Annual Report on Form 10-K includes a detailed discussion of our risk factors. Those risks and uncertainties have the potential to materially affect our 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 2016 Annual Report on Form 10-K.

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

The following table sets forth our repurchase activity for the quarter ended March 31, 2017:

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
1/01/17 - 1/31/17	—	$	—	—	2,431,053
2/01/17 - 2/28/17	—	—		—	2,431,053
3/01/17 - 3/31/17	—	—		—	2,431,053
Total	—	$	—	—	2,431,053

The stock repurchase plan, which was authorized by our Board of Directors, became effective in September 1996 and as of March 31, 2017, included 19.5 million shares of common stock for repurchase, of which, approximately 2.4 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

31.1+	Certification of the Chief Executive Officer pursuant to section 302 of the Sarbanes-Oxley Act of 2002
31.2+	Certification of the Chief Financial Officer pursuant to section 302 of the Sarbanes-Oxley Act of 2002
32.1+ †	Certification of the Chief Executive Officer pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.2+ †	Certification of the Chief Financial Officer pursuant to section 906 of the Sarbanes-Oxley Act of 2002
101+	Interactive Data File (Form 10-Q, for the fiscal period ended March 31, 2017, furnished in XBRL (eXtensible Business Reporting Language)).

_______________________________

+ Filed herewith.

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

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SIGNATURES

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

		NEW JERSEY RESOURCES CORPORATION
		(Registrant)
Date:	May 5, 2017
		By:/s/ Patrick Migliaccio
		Patrick Migliaccio
		Senior Vice President and
		Chief Financial Officer

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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:	May 5, 2017	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:	May 5, 2017	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 (the "Company");

(b) To the best of my knowledge, this quarterly report on Form 10-Q for the fiscal quarter ended March 31, 2017, 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 Company.

Date:	May 5, 2017	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 (the "Company");

(b) To the best of my knowledge, this quarterly report on Form 10-Q for the fiscal quarter ended March 31, 2017, 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 Company.

Date:	May 5, 2017	By:	/s/ Patrick Migliaccio
			Patrick Migliaccio
			Senior Vice President and Chief Financial Officer

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Document and Entity Information - shares	6 Months Ended
	Mar. 31, 2017	May 02, 2017
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 Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		86,438,897
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q2

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
OPERATING REVENUES
Utility	$ 295,546	$ 242,536	$ 481,102	$ 394,142
Nonutility	438,000	331,657	793,472	624,309
Total operating revenues	733,546	574,193	1,274,574	1,018,451
OPERATING EXPENSES
Gas Purchases - Utility	112,445	82,374	173,765	129,039
Gas Purchases - Nonutility	367,328	287,883	705,260	541,971
Gas Purchases - Related parties	2,072	2,077	4,183	4,151
Operation and maintenance	52,342	53,125	104,570	99,358
Regulatory rider expenses	19,893	21,215	32,494	30,843
Depreciation and amortization	20,328	17,744	39,588	34,226
Energy and other taxes	19,485	15,842	33,586	25,479
Total operating expenses	593,893	480,260	1,093,446	865,067
OPERATING INCOME	139,653	93,933	181,128	153,384
Other income, net	5,338	2,202	9,114	4,126
Interest expense, net of capitalized interest	11,436	7,369	22,051	14,146
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	133,555	88,766	168,191	143,364
Income tax provision	23,932	17,815	25,950	24,537
Equity in earnings of affiliates	5,079	2,402	7,390	4,808
NET INCOME	$ 114,702	$ 73,353	$ 149,631	$ 123,635
EARNINGS PER COMMON SHARE
Basic (usd per share)	$ 1.33	$ 0.85	$ 1.74	$ 1.44
Diluted (usd per share)	1.32	0.84	1.72	1.42
DIVIDENDS DECLARED PER COMMON SHARE (usd per share)	$ 0.255	$ 0.24	$ 0.51	$ 0.48
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic (in shares)	86,275	85,834	86,182	85,754
Diluted (in shares)	87,101	86,858	86,993	86,778

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Statement of Comprehensive Income [Abstract]
Net income		$ 114,702	$ 73,353	$ 149,631	$ 123,635
Other comprehensive income, net of tax
Unrealized gain on available for sale securities, net of tax of $(670), $(3,154), $(4,456), and $(5,768), respectively		1,408	4,500	6,923	8,201
Net unrealized gain on derivatives, net of tax of $0, $(21), $0 and $(2), respectively	[1]	0	38	0	5
Adjustment to postemployment benefit obligation, net of tax of $(217), $(175), $(434), and $(349) respectively		318	257	635	513
Other comprehensive income		1,726	4,795	7,558	8,719
Comprehensive income		$ 116,428	$ 78,148	$ 157,189	$ 132,354

[1] Effective January 1, 2016, the Company elected not to designate its foreign currency derivatives as accounting hedges and, as a result, changes in fair value of the effective portion of the hedges are no longer recorded in OCI. See Note 4 Derivative Instruments for more information on these transactions.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Statement of Comprehensive Income [Abstract]
Tax on unrealized (loss) gain on available for sale securities	$ (670)	$ (3,154)	$ (4,456)	$ (5,768)
Tax on net unrealized (loss) gain on derivatives	0	(21)		(2)
Tax on adjustment for postemployment benefit obligation	$ (217)	$ (175)	$ (434)	$ (349)

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 149,631	$ 123,635
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) loss on derivative instruments	(26,553)	2,035
Gain on sale of property and available for sale securities, net	7,287	0
Depreciation and amortization	39,588	34,226
Allowance for equity used during construction	(1,586)	(2,357)
Allowance for bad debt expense	519	873
Deferred income taxes	32,202	17,980
Manufactured gas plant remediation costs	(3,704)	(2,656)
Distributions received from equity investees, net of equity in earnings	(463)	2,261
Cost of removal - asset retirement obligations	(242)	(66)
Contributions to postemployment benefit plans	(1,884)	(32,167)
Tax benefit from stock-based compensation	1,231	1,660
Changes in:
Components of working capital	(31,231)	(13,788)
Other noncurrent assets	24,580	(15,794)
Other noncurrent liabilities	(2,997)	2,163
Cash flows from operating activities	171,804	118,005
CASH FLOWS (USED IN) INVESTING ACTIVITIES
Utility plant	(58,761)	(76,326)
Solar and wind equipment	(89,905)	(70,882)
Real estate properties and other	(516)	(1,069)
Cost of removal	(14,838)	(20,080)
Investments in equity investees	(10,538)	(5,948)
Distribution from equity investees in excess of equity in earnings	1,273	1,131
Withdrawal from restricted cash construction fund	1,337	1,007
Proceeds from sale of property, net of closing costs	9,443	748
Proceeds from sale of available for sale securities	6,639	0
Cash flows (used in) investing activities	(155,866)	(171,419)
CASH FLOWS FROM FINANCING ACTIVITIES
Net proceeds from short-term debt	116,200	86,150
Payments of long-term debt	(41,660)	(5,807)
Proceeds from sale-leaseback transaction	9,587	7,107
Payments of common stock dividends	(43,898)	(41,115)
Proceeds from issuance of common stock	9,731	8,220
Purchases of treasury stock	(6,355)	(1,008)
Tax withholding payments related to net settled stock compensation	(4,354)	(3,181)
Cash flows from financing activities	39,251	50,366
Change in cash and cash equivalents	55,189	(3,048)
Cash and cash equivalents at beginning of period	37,546	4,928
Cash and cash equivalents at end of period	92,735	1,880
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	(137,408)	(16,750)
Inventories	62,321	43,479
Recovery of gas costs	(9,616)	(20,396)
Gas purchases payable	21,156	(31,324)
Gas purchases payable - related parties	3	(409)
Prepaid and accrued taxes	25,829	43,154
Accounts payable and other	(10,027)	(25,026)
Restricted broker margin accounts	28,432	(12,478)
Customers' credit balances and deposits	(12,765)	226
Other current assets	844	5,736
Components of working capital	(31,231)	(13,788)
Cash paid (received) for:
Interest (net of amounts capitalized)	21,578	15,647
Income taxes	(6,431)	688
Accrued capital expenditures	$ 23,284	$ 21,663

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 2,167,728	$ 2,107,375
Construction work in progress	108,373	122,268
Solar and wind equipment, real estate properties and other, at cost	758,864	631,696
Construction work in progress	31,464	93,791
Total property, plant and equipment	3,066,429	2,955,130
Accumulated depreciation and amortization, utility plant	(475,075)	(467,702)
Accumulated depreciation and amortization, solar and wind equipment, real estate properties and other	(95,050)	(79,776)
Property, plant and equipment, net	2,496,304	2,407,652
CURRENT ASSETS
Cash and cash equivalents	92,735	37,546
Customer accounts receivable
Billed	242,698	142,658
Unbilled revenues	42,657	5,744
Allowance for doubtful accounts	(4,929)	(4,865)
Regulatory assets	43,344	54,286
Gas in storage, at average cost	143,514	206,251
Materials and supplies, at average cost	11,194	10,778
Prepaid and accrued taxes	15,528	34,179
Derivatives, at fair value	32,103	29,964
Restricted broker margin accounts	23,604	47,644
Asset held for sale	0	7,660
Other	35,509	35,419
Total current assets	677,957	607,264
NONCURRENT ASSETS
Investments in equity method investees	152,891	141,148
Regulatory assets	396,924	441,294
Derivatives, at fair value	6,347	5,227
Available for sale securities	65,884	55,789
Other	61,052	60,196
Total noncurrent assets	683,098	703,654
Total assets	3,857,359	3,718,570
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding March 31, 2017 — 86,363,986; September 30, 2016 — 86,086,355	222,235	221,654
Premium on common stock	219,074	215,580
Accumulated other comprehensive loss, net of tax	(7,597)	(15,155)
Treasury stock at cost and other; shares March 31, 2017 — 2,529,817; September 30, 2016 — 2,575,139	(78,616)	(81,044)
Retained earnings	931,184	825,556
Common stock equity	1,286,280	1,166,591
Long-term debt	1,023,968	1,055,038
Total capitalization	2,310,248	2,221,629
CURRENT LIABILITIES
Current maturities of long-term debt	60,723	61,452
Short-term debt	237,900	121,700
Gas purchases payable	160,605	139,452
Gas purchases payable to related parties	1,156	1,150
Accounts payable and other	70,981	107,184
Dividends payable	22,023	21,975
Accrued taxes	8,258	1,080
Regulatory liabilities	5,747	9,469
New Jersey clean energy program	6,239	14,232
Derivatives, at fair value	32,559	61,080
Customers' credit balances and deposits	20,069	32,834
Total current liabilities	626,260	571,608
NONCURRENT LIABILITIES
Deferred income taxes	507,111	473,847
Deferred investment tax credits	4,458	4,619
Deferred gain	28,121	28,519
Derivatives, at fair value	6,105	25,252
Manufactured gas plant remediation	165,849	172,000
Postemployment employee benefit liability	141,797	141,604
Regulatory liabilities	28,457	41,411
Asset retirement obligation	29,924	28,379
Other	9,029	9,702
Total noncurrent liabilities	920,851	925,333
Commitments and contingent liabilities (Note 12)
Total capitalization and liabilities	$ 3,857,359	$ 3,718,570

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Mar. 31, 2017	Sep. 30, 2016
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	86,363,986	86,086,355
Treasury stock at cost and other, shares	2,529,817	2,575,139

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NATURE OF THE BUSINESS

6 Months Ended

Mar. 31, 2017

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 528,000 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 Clean Energy Ventures Corporation, the Company's clean energy subsidiary, comprises the Clean Energy Ventures segment and consists of the Company's capital investments in commercial and residential solar projects located throughout New Jersey and onshore wind investments in Montana, Iowa, Kansas, Wyoming and Pennsylvania;

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 in the U.S. and Canada;

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, located in Pennsylvania, and NJR Pipeline Company, which holds the Company's 20 percent ownership interest in PennEast and NJNR Pipeline Company, which holds the Company's1.84 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, which provides heating, central air conditioning, standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey, and Commercial Realty & Resources Corporation, which owns commercial real estate. NJR Retail Holdings Corporation is included in Home Services and Other operations. NJR Energy Corporation, a subsidiary of CR&R, was dissolved on November 28, 2016, and all assets were moved to CR&R during the first quarter of fiscal 2017.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Mar. 31, 2017

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 SEC and GAAP. The September 30, 2016 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 2016 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 ending September 30, 2017. Intercompany transactions and accounts have been eliminated.

Gas in Storage

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

	March 31, 2017				September 30, 2016
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJRES		$	128,281	46.4		$	130,493	62.0
NJNG		15,233		4.3		75,758		21.3
Total		$	143,514	50.7		$	206,251	83.3

Sales Tax Accounting

Sales tax that is collected from customers is presented in both operating revenues and operating expenses on the Unaudited Condensed Consolidated Statements of Operations was $16.9 million and $28.1 million during the three and six months endedMarch 31, 2017, respectively, and $13.5 million and $20.7 million during the three and six months endedMarch 31, 2016, respectively. Effective January 1, 2017, the New Jersey sales tax rate decreased from 7 percent to 6.875 percent.

Sale of Asset

On March 8, 2017, CR&R sold an approximately 56,400 square foot office building on five acres of land located in Monmouth County for $9.4 million, net of closing costs, generating a pre-tax gain of $1.9 million, which was recognized in O&M on the Unaudited Condensed Consolidated Statements of Operations.

Available for Sale Securities

Included in available for sale securities on the Unaudited Condensed Consolidated Balance Sheets are investments in two publicly traded energy companies. The Company's available for sale securities had a fair value of $65.9 million and $55.8 million as of March 31, 2017 and September 30, 2016, respectively. Total unrealized gains associated with these investments are included as a part of accumulated other comprehensive income, a component of common stock equity and were $18.5 million, $11.1 million after tax, and $7.2 million, $4.2 million after tax, as of March 31, 2017 and September 30, 2016, respectively.

During the three and six months endedMarch 31, 2017, NJR received proceeds of approximately $3.4 million and $6.6 million, respectively, from the sale of available for sale securities and realized a pre-tax gain of $2.8 million and $5.4 million, respectively, which is included in other income, net in the Unaudited Condensed Consolidated Statements of Operations. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

Customer Accounts Receivable

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

(Thousands)	March 31, 2017				September 30, 2016
NJRES	$	135,199	56	%	$	102,884	72	%
NJNG (1)	100,449		41		30,951		22
NJRCEV	2,405		1		1,807		1
NJRHS and other	4,645		2		7,016		5
Total	$	242,698	100	%	$	142,658	100	%

(1) Does not include unbilled revenues of $42.7 million and $5.7 million as of March 31, 2017 and September 30, 2016, respectively.

Loans Receivable

NJNG provides 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 recorded $8.2 million and $7.8 million in other current assets and $40.7 million and $39.5 million in other noncurrent assets as of March 31, 2017 and September 30, 2016, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans.

NJNG's policy is to establish an allowance for doubtful accounts when loan balances are in arrears for more than 60 days. As of March 31, 2017 and September 30, 2016, there was no allowance for doubtful accounts established for the SAVEGREEN loans.

Stock Based Compensation

Effective January 25, 2017, the shareholders of NJR approved the NJR 2017 Stock Award and Incentive Plan, which replaced the NJR 2007 Stock Award and Incentive Plan. The 2007 plan had 2,367,338 and 4,223 shares available for future issuance to employees and directors, respectively, which were transferred into the 2017 plan. In addition, the 2017 plan increases the total shares available for issuance to 3,135,000.

Recently Adopted Updates to the Accounting Standards Codification

Stock Compensation

In March 2016, the FASB issued ASU 2016-09, an amendment to ASC 718, Compensation - Stock Compensation, which simplifies several aspects of the accounting for employee share-based compensation, including the accounting for income taxes and forfeitures. The new guidance also increased the threshold for tax withholding to the maximum statutory rate, as applicable, to maintain equity classification and amended the classification of certain tax transactions within the statement of cash flows.

The Company elected to early adopt the amended guidance during the third quarter of fiscal 2016 and applied the new provisions as of the beginning of the year of adoption on a retrospective or prospective basis depending on each amendment’s transition requirements. As such, effective October 1, 2015, NJR is recognizing forfeitures as they occur and is recognizing excess tax benefits (deficiencies) as a component of income tax (benefit) provision in its Unaudited Condensed Consolidated Statements of Operations on a prospective basis. All related information for prior periods has been adjusted throughout this report on a retrospective basis to reflect the effects of the adoption. See Note 11. Income Taxes for more information on these transactions.

In addition, the following amounts on the Unaudited Condensed Consolidated Financial Statements have been adjusted retrospectively during the three and six months endedMarch 31, 2016:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Three Months Ended
Statements of Operations
Income tax provision	$	17,840	$	(25	)	$	17,815
Net income	$	73,328	$	25		$	73,353
Earnings per common share
Basic	$	0.85	$	—		$	0.85
Diluted	$	0.84	$	—		$	0.84
Six Months Ended
Statements of Operations
Income tax provision	$	26,197	$	(1,660	)	$	24,537
Net income	$	121,975	$	1,660		$	123,635
Earnings per common share
Basic	$	1.42	$	0.02		$	1.44
Diluted	$	1.41	$	0.01		$	1.42
Cash flows from operating activities
Net income	$	121,975	$	1,660		$	123,635
Tax benefit from stock based compensation	$	—	$	1,660		$	1,660
Other noncurrent liabilities	$	2,302	$	(139	)	$	2,163
Net cash flows from operating activities	$	114,824	$	3,181		$	118,005
Cash flows from financing activities
Tax withholding payments related to net settled stock compensation	$	—	$	(3,181	)	$	(3,181	)
Cash flows from financing activities	$	53,547	$	(3,181	)	$	50,366

There was no impact to the Unaudited Condensed Consolidated Balance Sheets upon adoption of the new guidance.

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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or 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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis, which did not impact its financial position, results of operations or 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 on the balance sheet as a deduction from the carrying amount of the liability. The amendment does 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 amendment contained within ASU No. 2015-03 does not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis.

In addition, the following amounts on the Unaudited Condensed Consolidated Balance Sheets have been adjusted, retrospectively, as of September 30, 2016.

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Other noncurrent assets	$	68,708	$	(8,512	)	$	60,196
Total noncurrent assets	$	712,166	$	(8,512	)	$	703,654
Total assets	$	3,727,082	$	(8,512	)	$	3,718,570
Capitalization and Liabilities
Long-term debt	$	1,063,550	$	(8,512	)	$	1,055,038
Total capitalization	$	2,230,141	$	(8,512	)	$	2,221,629
Total capitalization and liabilities	$	3,727,082	$	(8,512	)	$	3,718,570

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 amendment provides 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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.

Other 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 the Company’s fiscal year ending September 30, 2019, and interim periods within that year. The Company continues to evaluate the provisions of ASC 606, however, based on the review of customer contracts to date, it is not anticipating a material impact to its financial position, results of operations or cash flows upon adoption. The Company anticipates significant new disclosures as a result of the new standard and currently expects to transition to the new guidance using the modified retrospective approach. The Company is also monitoring industry specific developments that may have an impact, including our ability to recognize revenue for contracts where collectability is uncertain.

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 or 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 the Company’s fiscal year ending September 30, 2018, and interim periods within that year. Upon adoption, the amendment will be applied on a prospective basis. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Financial Instruments

In January 2016, the FASB issued ASU 2016-01, an amendment to ASC 825, Financial Instruments, to address certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certain fair value changes for financial liabilities measured at fair value. It also simplifies the impairment assessment of equity investments without a readily determinable fair value by requiring a qualitative assessment. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year. Upon adoption, the amendment will be applied on a modified-retrospective basis. The Company evaluated the amendment and noted that, upon adoption, subsequent changes to the fair value of the Company’s available for sale securities will be recorded in the Consolidated Statement of Operations as opposed to other comprehensive income. The Company does not expect any other material impacts to its financial position, results of operations or cash flows upon adoption.

In June 2016, the FASB issued ASU 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. The guidance is effective for the Company’s fiscal year ending September 30, 2021, and interim periods within that year, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.

Leases

In February 2016, the FASB issued ASU 2016-02, an amendment to ASC 842, Leases, which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption. The guidance is effective for the Company’s fiscal year ending September 30, 2020, and interim periods within that year, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Statement of Cash Flows

In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. The Company is currently evaluating the amendment to understand the impact on its consolidated statements of cash flows upon adoption.

In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company’s fiscal year ending September 30, 2019, with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its financial position, results of operations or cash flows upon adoption.

Business Combinations

In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on what accounting to apply to acquisitions.

Gains and Losses from the Derecognition of Nonfinancial Assets

In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. ASU No. 2017-05 may be applied retrospectively for all periods presented or retrospectively with a cumulative-effect adjustment at the date of adoption. The Company is currently evaluating the amendment to understand the impact on its financial position, results from operations, and cash flows upon adoption.

Compensation - Retirement Benefits

In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis for presentation and changes to capitalization of costs will be applied on a prospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on its financial position, results of operations and cash flows upon adoption. The Company is also monitoring industry specific developments on the new guidance to determine the appropriate treatment of these changes in a rate regulated environment.

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REGULATION

6 Months Ended

Mar. 31, 2017

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 capital investments 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 rates, BGSS and other regulatory tariff riders. NJNG is required to make an annual filing to the BPU by June 1 of each year for review of its BGSS, CIP and various other programs and related rates. Annual rate changes are requested to be effective at the beginning of the following fiscal year. In addition, NJNG is also permitted to request approval of certain rate or program changes on an interim basis. All rate and program changes are subject to proper notification and BPU review and approval.

In September 2016, the BPU approved NJNG's base rate case, effective October 1, 2016, which included an increase in base rates in the amount of $45 million. The base rate increase includes a return on common equity of 9.75 percent, a common equity ratio of 52.5 percent and a depreciation rate of 2.4 percent. The approval also included the five-year extension of SAFE II, rate recovery of NJ RISE capital investment costs through June 30, 2016, recovery of NJNG’s SAFE I, NGV and LNG capital investments and recovery of other costs previously deferred in regulatory assets.

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

(Thousands)	March 31, 2017		September 30, 2016
Regulatory assets-current
Conservation Incentive Program	$	23,834	$	36,957
New Jersey Clean Energy Program	6,239		14,232
Underrecovered gas costs	13,271		—
Derivatives at fair value, net	—		3,097
Total current regulatory assets	$	43,344	$	54,286
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	19,067	$	19,595
Liability for future expenditures	165,849		172,000
Deferred income taxes	21,209		20,273
Derivatives at fair value, net	4,392		23,384
SAVEGREEN	15,604		25,208
Postemployment and other benefit costs	151,414		157,027
Deferred Superstorm Sandy costs	14,116		15,201
Other noncurrent regulatory assets	5,273		8,606
Total noncurrent regulatory assets	$	396,924	$	441,294
Regulatory liability-current
Derivatives at fair value, net	$	5,747	$	—
Overrecovered gas costs	—		9,469
Total current regulatory liabilities	$	5,747	$	9,469
Regulatory liabilities-noncurrent
Cost of removal obligation	$	17,224	$	30,549
New Jersey Clean Energy Program	10,269		10,657
Other noncurrent regulatory liabilities	964		205
Total noncurrent regulatory liabilities	$	28,457	$	41,411

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

• On March 31, 2017, NJNG filed its annual petition with the BPU requesting a base rate change in the amount of $4.3 million for the recovery of NJ RISE and SAFE II capital investment costs related to the period ending June 30, 2017, pursuant to the base rate case order dated September 23, 2016. The filing will be updated to reflect actual results in July 2017, with changes to base rates effective October 1, 2017.

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DERIVATIVE INSTRUMENTS

6 Months Ended

Mar. 31, 2017

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 to hedge Canadian dollar denominated gas purchases and/or sales. Therefore, the Company's primary underlying risks include commodity prices, interest rates and foreign currency. These contracts 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.

NJRES

Since NJRES chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, the changes in the fair value of these derivatives 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 exchange rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are typically used to hedge demand fee payments on pipeline capacity, storage and gas purchase agreements. Accordingly, changes in the fair value of foreign exchange contracts are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations. For transactions occurring on or before December 31, 2015, NJRES' foreign exchange contracts were designated as cash flow hedges, and the effective portion of the hedges were recorded in OCI.

As a result of NJRES entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating 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.

Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. The Company applies NPNS accounting to SREC forward and futures contracts entered into on or before December 31, 2015. Effective for contracts executed on or after January 1, 2016, NJRES no longer elects NPNS accounting treatment on all SREC forward sales contracts and recognizes changes in the fair value of these derivatives as a component of operating revenues. Upon settlement of the contract, the related revenue is recognized when the SREC is transferred to the counterparty.

NPNS is a contract-by-contract election and, where it makes sense to do so, we can and may elect normal accounting for certain contracts.

NJNG

Changes in fair value of NJNG's financial commodity derivatives are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis. Accordingly, physical natural gas 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 charged to expense in the current period earnings based on the BGSS factor times the therm sales. Effective for contracts executed on or after January 1, 2016, NJNG no longer elects NPNS accounting treatment on all physical forward commodity contracts. However, since NPNS is a contract-by-contract election, where it makes sense to do so, we can and may elect certain contracts to be normal. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets.

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 a 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 recovered in future rates. Upon settlement, any gain or loss will be amortized into earnings over the life of the future underlying 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
			March 31, 2017						September 30, 2016
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives not designated as hedging instruments:
NJNG:
Physical commodity contracts	Derivatives - current		$	64		$	17		$	235		$	1,154
Financial commodity contracts	Derivatives - current		2,240			928			805			2,979
	Derivatives - noncurrent		—			—			75			386
Interest rate contracts	Derivatives - noncurrent		—			4,392			—			23,073
NJRES:
Physical commodity contracts	Derivatives - current		4,080			2,460			5,994			11,660
	Derivatives - noncurrent		6,084			588			3,987			1,212
Financial commodity contracts	Derivatives - current		25,717			29,127			22,929			45,255
	Derivatives - noncurrent		263			1,125			1,165			581
Foreign currency contracts	Derivatives - current		2			27			1			32
Fair value of derivatives not designated as hedging instruments			$	38,450		$	38,664		$	35,191		$	86,332
Total fair value of derivatives			$	38,450		$	38,664		$	35,191		$	86,332

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 at the contract level unit of account 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 March 31, 2017:
Derivative assets:
NJRES
Physical commodity contracts		$	10,164		$	(540	)		$	(200	)		$	9,424
Financial commodity contracts		25,980			(25,068		)		—				912
Foreign currency contracts		2			(2		)		—				—
Total NJRES		$	36,146		$	(25,610	)		$	(200	)		$	10,336
NJNG
Physical commodity contracts		$	64		$	(2	)		$	—			$	62
Financial commodity contracts		2,240			(928		)		(1,312		)		—
Total NJNG		$	2,304		$	(930	)		$	(1,312	)		$	62
Derivative liabilities:
NJRES
Physical commodity contracts		$	3,048		$	(540	)		$	—			$	2,508
Financial commodity contracts		30,252			(25,068		)		(5,184		)		—
Foreign currency contracts		27			(2		)		—				25
Total NJRES		$	33,327		$	(25,610	)		$	(5,184	)		$	2,533
NJNG
Physical commodity contracts		$	17		$	(2	)		$	—			$	15
Financial commodity contracts		928			(928		)		—				—
Interest rate contracts		4,392			—				—				4,392
Total NJNG		$	5,337		$	(930	)		$	—			$	4,407
As of September 30, 2016:
Derivative assets:
NJRES
Physical commodity contracts		$	9,981		$	(2,837	)		$	(755	)		$	6,389
Financial commodity contracts		24,094			(17,945		)		(6,149		)		—
Foreign currency contracts		1			(1		)		—				—
Total NJRES		$	34,076		$	(20,783	)		$	(6,904	)		$	6,389
NJNG
Physical commodity contracts		$	235		$	(31	)		$	—			$	204
Financial commodity contracts		880			(880		)		—				—
Total NJNG		$	1,115		$	(911	)		$	—			$	204
Derivative liabilities:
NJRES
Physical commodity contracts		$	12,872		$	(2,837	)		$	1,200			$	11,235
Financial commodity contracts		45,836			(17,945		)		(27,891		)		—
Foreign currency contracts		32			(1		)		—				31
Total NJRES		$	58,740		$	(20,783	)		$	(26,691	)		$	11,266
NJNG
Physical commodity contracts		$	1,154		$	(31	)		$	—			$	1,123
Financial commodity contracts		3,365			(880		)		(2,485		)		—
Interest rate contracts		23,073			—				—				23,073
Total NJNG		$	27,592		$	(911	)		$	(2,485	)		$	24,196

(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) Includes transactions with NAESB netting election, transactions held by FCMs 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 to be used for storage injection and its subsequent sale 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 delivered. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments creates volatility in the results of NJRES, although the Company's intended economic results relating to the entire transaction are unaffected.

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

(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended						Six Months Ended
		March 31,						March 31,
Derivatives not designated as hedging instruments:		2017			2016			2017			2016
NJRES:
Physical commodity contracts	Operating revenues	$	4,982		$	9,128		$	6,725		$	21,002
Physical commodity contracts	Gas purchases	(3,982		)	(5,583		)	(12,781		)	(26,820		)
Financial commodity contracts	Gas purchases	38,121			21,820			7,510			63,096
Foreign currency contracts	Gas purchases	53			—			(33		)	—
Total unrealized and realized gains (losses)		$	39,174		$	25,365		$	1,421		$	57,278

NJRES designated its foreign exchange contracts entered into prior to January 1, 2016, as cash flow hedges and, as a result, changes in fair value of the effective portion of the hedges were recorded in OCI and, upon settlement of the contracts, realized gains and (losses) were reclassified from AOCI to gas purchases on the Unaudited Condensed Consolidated Statements of Operations.

The following table reflects the effect of derivative instruments that were designated as cash flow hedges on OCI during the three and six months endedMarch 31, 2016:

(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)
March 31, 2016	Three Months Ended		Six Months Ended			Three Months Ended		Six Months Ended
Foreign currency contracts	$	29	$	(35	)	$	30	$	42

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 approval. At settlement, the resulting gains and/or losses are payable to or recoverable from utility customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings.

The following table reflects the gains (losses) associated with NJNG's derivative instruments as of:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
NJNG:
Physical commodity contracts	$	(3,780	)	$	(14,528	)	$	(2,730	)	$	(14,528	)
Financial commodity contracts	(418		)	(5,151		)	10,760			(10,786		)
Interest rate contracts	(1,690		)	(11,071		)	18,681			(8,705		)
Total unrealized and realized (losses) gains	$	(5,888	)	$	(30,750	)	$	26,711		$	(34,019	)

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

		Volume (Bcf)
		March 31, 2017		September 30, 2016
NJNG	Futures	24.6		23.6
	Physical	5.7		9.2
NJRES	Futures	(64.2	)	(79.1	)
	Options	—		1.2
	Physical	64.0		94.6

Not included in the previous table are NJRES' gross notional amount of foreign currency transactions of approximately $2.2 million, NJNG’s treasury lock agreement as previously discussed and 314,500 SRECs at NJRES that are open as of March 31, 2017.

Broker Margin

Futures exchanges have contract specific performance bond requirements, also known as margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily marked-to-market relative to maintenance margin requirements. The Company maintains separate broker margin accounts for NJNG and NJRES. The balances by company are as follows:

(Thousands)	Balance Sheet Location	March 31, 2017		September 30, 2016
NJNG	Broker margin - Current assets	$	3,354	$	4,822
NJRES	Broker margin - Current assets	$	20,250	$	42,822

Due to CME rulebook changes that took effect in January 2017, variation margin is being treated as a settlement payment, rather than collateral. As a result, the Company is now required to present variation margin net with the related derivative assets and/or liabilities on the Unaudited Condensed Consolidated Balance Sheets for any derivatives the Company clears through the CME. This change is being applied on a prospective basis. In September 30, 2016, prior to the rule change, the Company reported the variation margin as a separate unit of account within restricted broker margin on the Unaudited Condensed Consolidated Balance Sheets. There was no impact to the Company’s derivative gains or losses in the Unaudited Condensed Consolidated Statements of Operations as a result of the CME rule amendment.

Wholesale Credit Risk

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

NJR monitors and manages the credit risk of its wholesale 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 counterparty'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 March 31, 2017. 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		$	155,318
Noninvestment grade		35,381
Internally rated investment grade		8,974
Internally rated noninvestment grade		27,114
Total		$	226,787

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

Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company's credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on March 31, 2017 and September 30, 2016, was $4.5 million and $23.1 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on March 31, 2017 and September 30, 2016, the Company would have been required to post an additional $4.5 million and $23.1 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.

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FAIR VALUE

6 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

FAIR VALUE

FAIR VALUE

Fair Value of Assets and Liabilities

The fair value of cash and cash equivalents, 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 at NJNG and NJR, including current maturities, excluding capital leases and debt issuance costs, is as follows:

(Thousands)	March 31, 2017		September 30, 2016
Carrying value (1)	$	1,047,045	$	1,082,845
Fair market value	$	1,041,750	$	1,131,077

(1) Excludes capital leases of $45.9 million and $42.2 million as of March 31, 2017 and September 30, 2016, 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 March 31, 2017, 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 natural gas 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, SREC forward sales 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 the data is:

• widely accepted and public;

• non-proprietary and sourced from an independent third party; and

• observable and published.

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

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

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of March 31, 2017:
Assets:
Physical commodity contracts		$	—		$	10,228		$	—	$	10,228
Financial commodity contracts		28,220			—			—		28,220
Financial commodity contracts - foreign exchange		—			2			—		2
Available for sale equity securities - energy industry		65,884			—			—		65,884
Money market funds		65,115			—			—		65,115
Other		1,249			—			—		1,249
Total assets at fair value		$	160,468		$	10,230		$	—	$	170,698
Liabilities:
Physical commodity contracts		$	—		$	3,065		$	—	$	3,065
Financial commodity contracts		31,180			—			—		31,180
Financial commodity contracts - foreign exchange		—			27			—		27
Interest rate contracts		—			4,392			—		4,392
Total liabilities at fair value		$	31,180		$	7,484		$	—	$	38,664
As of September 30, 2016:
Assets:
Physical commodity contracts		$	—		$	10,216		$	—	$	10,216
Financial commodity contracts		24,974			—			—		24,974
Financial commodity contracts - foreign exchange		—			1			—		1
Available for sale equity securities - energy industry		55,789			—			—		55,789
Money market funds		34,072			—			—		34,072
Other		1,444			—			—		1,444
Total assets at fair value		$	116,279		$	10,217		$	—	$	126,496
Liabilities:
Physical commodity contracts		$	—		$	14,026		$	—	$	14,026
Financial commodity contracts		49,201			—			—		49,201
Financial commodity contracts - foreign exchange		—			32			—		32
Interest rate contracts		—			23,073			—		23,073
Total liabilities at fair value		$	49,201		$	37,131		$	—	$	86,332

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INVESTMENTS IN EQUITY METHOD INVESTEES

6 Months Ended

Mar. 31, 2017

Investments, All Other Investments [Abstract]

INVESTMENTS IN EQUITY METHOD INVESTEES

INVESTMENTS IN EQUITY METHOD INVESTEES

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

(Thousands)	March 31, 2017		September 30, 2016
Steckman Ridge (1)	$	121,809	$	123,155
PennEast	31,082		17,993
Total	$	152,891	$	141,148

(1) Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2017 and September 30, 2016. 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 120-mile pipeline that will extend from northeast Pennsylvania to western New Jersey, which is estimated to be in service by the first quarter of fiscal 2019.

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. See Note 14. Related Party Transactions for more information on these intercompany transactions.

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EARNINGS PER SHARE

6 Months Ended

Mar. 31, 2017

Earnings Per Share [Abstract]

EARNINGS PER SHARE

EARNINGS PER SHARE

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands, except per share amounts)	2017		2016		2017		2016
Net income, as reported	$	114,702	$	73,353	$	149,631	$	123,635
Basic earnings per share
Weighted average shares of common stock outstanding-basic	86,275		85,834		86,182		85,754
Basic earnings per common share	$1.33		$0.85		$1.74		$1.44
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	86,275		85,834		86,182		85,754
Incremental shares (1)	826		1,024		811		1,024
Weighted average shares of common stock outstanding-diluted	87,101		86,858		86,993		86,778
Diluted earnings per common share (2)	$1.32		$0.84		$1.72		$1.42

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

(2) There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and six months endedMarch 31, 2017 and 2016.

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COMMON STOCK EQUITY

6 Months Ended

Mar. 31, 2017

Equity [Abstract]

COMMON STOCK EQUITY

COMMON STOCK EQUITY

Changes in common stock equity during the six months endedMarch 31, 2017, were 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, 2016	86,086		$	221,654	$	215,580			$	(15,155	)	$	(81,044	)	$	825,556		$	1,166,591
Net income															149,631			149,631
Other comprehensive income									7,558									7,558
Common stock issued:
Incentive plan	232		581		4,788													5,369
Dividend reinvestment plan (1)	279				(1,266		)					10,994						9,728
Cash dividend declared ($.51 per share)															(44,003		)	(44,003		)
Treasury stock and other	(233	)			(28		)					(8,566		)				(8,594		)
Balance at March 31, 2017	86,364		$	222,235	$	219,074			$	(7,597	)	$	(78,616	)	$	931,184		$	1,286,280

(1) Shares sold through the DRP are issued from treasury stock at average cost, which may differ from the actual market price paid.

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. In December 2015, NJR registered 5 million shares of NJR common stock for issuance under the DRP. NJR raised $9.7 million and $8.2 million of equity through the DRP, by issuing approximately 279,000 and 260,000 shares of treasury stock, during the six months endedMarch 31, 2017 and 2016, respectively.

Accumulated Other Comprehensive Income (Loss)

The following table presents the changes in the components of accumulated other comprehensive income (loss), net of related tax effects during the three months ended March 31, 2017 and 2016:

(Thousands)	Available for Sale Securities			Cash Flow Hedges			Postemployment Benefit Obligation				Total
Balance at December 31, 2016	$	9,713		$	—		$	(19,036	)		$	(9,323	)
Other comprehensive income (loss), net of tax
Other comprehensive income, before reclassifications, net of tax of $(1,808), $0, $0, $(1,808)	3,054			—			—				3,054
Amounts reclassified from accumulated other comprehensive income, net of tax of $1,138, $0, $(217), $921	(1,646		)	—			318			(2)	(1,328		)
Net current-period other comprehensive income, net of tax of $(670), $0, $(217), $(887)	1,408			—			318				1,726
Balance at March 31, 2017	$	11,121		$	—		$	(18,718	)		$	(7,597	)
Balance as of December 31, 2015	$	10,086		$	(33	)	$	(15,523	)		$	(5,470	)
Other comprehensive income, net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(3,154), $(10), $0, $(3,164)	4,500			19			—				4,519
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(11), $(175), $(186)	—			19			257				276
Net current-period other comprehensive income, net of tax of ($3,154), $(21), $(175), $(3,350)	4,500			38			257				4,795
Balance as of March 31, 2016	$	14,586		$	5		$	(15,266	)		$	(675	)

The following table presents the changes in the components of accumulated other comprehensive income (loss), net of related tax effects during the six months ended March 31, 2017 and 2016:

(Thousands)	Available for Sale Securities			Cash Flow Hedges				Postemployment Benefit Obligation				Total
Balance at September 30, 2016	$	4,198		$	—			$	(19,353	)		$	(15,155	)
Other comprehensive income (loss), net of tax
Other comprehensive income, before reclassifications, net of tax of $(6,648), $0, $0, $(6,648)	10,096			—				—				10,096
Amounts reclassified from accumulated other comprehensive income, net of tax of $2,192, $0, $(434), $1,758	(3,173		)	—				635			(2)	(2,538		)
Net current-period other comprehensive income, net of tax of $(4,456), $0, $(434), $(4,890)	6,923			—				635				7,558
Balance at March 31, 2017	$	11,121		$	—			$	(18,718	)		$	(7,597	)
Balance as of September 30, 2015	$	6,385		$	—			$	(15,779	)		$	(9,394	)
Other comprehensive income (loss), net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(5,768), $13, $0, $(5,755)	8,201			(22		)		—				8,179
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(15), $(349), $(364)	—			27			(1)	513			(2)	540
Net current-period other comprehensive income, net of tax of ($5,768), $(2), $(349), $(6,119)	8,201			5				513				8,719
Balance as of March 31, 2016	$	14,586		$	5			$	(15,266	)		$	(675	)

(1) Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Unaudited Condensed Consolidated Statements of Operations. Effective January 1, 2016, the Company elected not to designate its foreign currency derivatives as accounting hedges and, as a result, changes in fair value of the effective portion of the hedges are no longer recorded in OCI.

(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

6 Months Ended

Mar. 31, 2017

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)	March 31, 2017			September 30, 2016			Expiration Dates
NJR
Bank revolving credit facilities(1)	$	425,000		$	425,000		September 2020
Notes outstanding at end of period	$	237,900		$	121,700
Weighted average interest rate at end of period	1.75		%	1.43		%
Amount available at end of period (2)	$	173,686		$	288,910
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		May 2019
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2) Letters of credit outstanding total $13.4 million and $14.4 million for March 31, 2017 and September 30, 2016, 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 for both March 31, 2017 and September 30, 2016, which reduces the amount available by the same amount.

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.

Long-term Debt

NJNG

On January 17, 2017, the Company completed the purchase of three FMBs in lieu of redemption with an aggregate principal amount totaling $35.8 million. The FMBs bore interest at rates ranging from 4.5 percent to 4.9 percent. The bonds purchased in lieu of redemption are being held by the Company to provide an opportunity to evaluate remarketing alternatives.

NJNG received $9.6 million and $7.1 million in December 2016 and 2015, 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. NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1 million during the six months endedMarch 31, 2017. NJNG did not exercise early purchase options during the six months endedMarch 31, 2016.

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EMPLOYEE BENEFIT PLANS

6 Months Ended

Mar. 31, 2017

Compensation and Retirement Disclosure [Abstract]

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

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

	Pension												OPEB
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	March 31,						March 31,						March 31,						March 31,
(Thousands)	2017			2016			2017			2016			2017			2016			2017			2016
Service cost	$	2,087		$	1,898		$	4,174		$	3,796		$	1,095		$	1,131		$	2,190		$	2,261
Interest cost	2,442			2,835			4,885			5,671			1,387			1,564			2,773			3,128
Expected return on plan assets	(4,828		)	(5,030		)	(9,656		)	(10,059		)	(1,191		)	(1,211		)	(2,383		)	(2,422		)
Recognized actuarial loss	2,206			1,821			4,413			3,641			1,092			818			2,185			1,637
Prior service cost amortization	28			27			55			55			(91		)	(91		)	(182		)	(182		)
Net periodic benefit cost	$	1,935		$	1,551		$	3,871		$	3,104		$	2,292		$	2,211		$	4,583		$	4,422

The Company made a discretionary contribution of $30 million during the first quarter of fiscal 2016, to improve the funded status of the pension plans based on then current actuarial assumptions, which included the adoption of the most recent mortality table. The Company does not expect to be required to make additional contributions to fund the pension plans during fiscal 2017 or 2018 based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets 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 six months endedMarch 31, 2017.

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INCOME TAXES

6 Months Ended

Mar. 31, 2017

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

NJR evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with unrecognized tax benefits. During the six months endedMarch 31, 2017 and 2016, 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 forecasted pre-tax book income and estimated permanent book versus tax differences, as well as 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 forecasted effective tax rates for the six months endedMarch 31, 2017 and 2016, were 15.6 percent and 17.7 percent, respectively. The decreased effective tax rate is due primarily to an increase in forecasted tax credits for the fiscal year ending September 30, 2017, compared with the prior fiscal year. Forecasted tax credits, net of deferred taxes, were $34.6 million and $27.1 million for fiscal 2017 and 2016, respectively.

To the extent there are discrete tax items that are not included in the forecasted effective tax rate, the actual effective tax rate will differ from the estimated annual effective tax rate. The Company recognized $1.5 million and $1.7 million during the six months endedMarch 31, 2017 and 2016, respectively, in additional tax benefits associated with the vesting of share-based awards and the release of a valuation allowance associated with state tax net operating losses, as a component of income tax provision in its Unaudited Condensed Consolidated Statements of Operations. Since the tax effects of the awards and the valuation allowance are treated as discrete items, NJR’s actual effective tax rate was 14.8 percent and 16.6 percent as of March 31, 2017and 2016, respectively.

As of March 31, 2017, the Company has federal and state income tax net operating losses of approximately $78.7 million and $344.7 million, respectively, which generally have a life of 20 years. The Company has recorded federal and state income tax receivables and deferred tax assets of approximately $27.5 million and $20.2 million, respectively, on the Unaudited Condensed Consolidated Balance Sheets, reflecting the tax benefits associated with these net operating losses. As of September 30, 2016, the Company had federal and state income tax net operating losses of approximately $78.7 million and $310.6 million, respectively, deferred federal and state tax assets of approximately $27.5 million and $18.2 million, respectively.

As of September 30, 2016, the Company recorded a valuation allowance in the amount of $262,000 associated with state net operating loss carryforwards at CR&R. As a result of taxable income generated from the sale of property and available for sale securities during the six months ended March 31, 2017, the Company determined the benefits resulting from the state net operating loss carryforwards at CR&R are more likely than not to be realized prior to their expiration. Accordingly, the Company released the related valuation allowance against these state net operating loss carryforwards. There were no other valuation allowances needed for the Company as of March 31, 2017.

In addition, as of March 31, 2017 and September 30, 2016, the Company had an ITC/PTC carryforward of approximately $111 million and $74 million, respectively, which has a life of 20 years. The Company expects to utilize this entire carryforward, which would begin to expire in fiscal 2034.

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 during 2020 and to 22 percent for property under construction during 2021. For any property that is under construction before 2022, but not placed in service before 2024, the ITC will be reduced to 10 percent. In addition, the PTC was extended 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

6 Months Ended

Mar. 31, 2017

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 2033, for the supply, storage and transportation of natural gas. These contracts include fixed charges of approximately $40 million at current contract rates and volumes for the remainder of the fiscal year, 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 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 March 31, 2017, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2017		2018		2019		2020		2021		Thereafter
NJRES:
Natural gas purchases	$	179,517	$	121,391	$	55,395	$	—	$	—	$	—
Storage demand fees	19,525		28,869		16,195		12,913		8,822		8,580
Pipeline demand fees	38,347		48,509		19,057		8,137		7,605		10,403
Sub-total NJRES	$	237,389	$	198,769	$	90,647	$	21,050	$	16,427	$	18,983
NJNG:
Natural gas purchases	$	45,266	$	11,250	$	—	$	—	$	—	$	—
Storage demand fees	14,568		29,187		25,772		14,476		7,802		11,705
Pipeline demand fees	25,400		81,229		116,976		112,555		90,106		732,538
Sub-total NJNG (1)	$	85,234	$	121,666	$	142,748	$	127,031	$	97,908	$	744,243
Total	$	322,623	$	320,435	$	233,395	$	148,081	$	114,335	$	763,226

(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 June 2016, the BPU approved NJNG’s December 2015 filing, which requested approval of its MGP expenditures incurred through June 30, 2015, with recovery of $9.4 million annually related to the SBC RA factor with rates effective July 9, 2016. As of March 31, 2017, $19.1 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 $143.9 million to $231.6 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, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets of $172 million as of September 30, 2016, based on the most likely amount at year end and $165.8 million as of March 31, 2017, which includes adjustments for actual expenditures during fiscal 2017. 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

In February 2015, a natural gas fire and explosion occurred in Stafford Township, New Jersey as a result of a natural gas leak emanating from an underground pipe. There were no fatalities, although several employees of NJNG were injured and several homes were damaged. NJNG notified its insurance carrier and believes that any costs associated with the incident, including attorneys’ fees, property damage and other losses, will be substantially covered by insurance. The Company believes the resolution of any potential claims associated with the incident will not have a material effect on its financial condition, results of operations or cash flows. As of March 31, 2017, NJNG estimates that liabilities associated with claims will range between $600,000 and $3.2 million and has accrued the lower end of the range, as we do not believe there is an amount within the range that is more probable than any other.

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

6 Months Ended

Mar. 31, 2017

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 its 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 Clean Energy Ventures segment consists of capital investments in clean energy projects; the Energy Services segment consists of unregulated wholesale energy operations; 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						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Operating revenues
Natural Gas Distribution
External customers	$	295,546		$	242,536		$	481,102		$	394,142
Clean Energy Ventures
External customers	12,943			7,662			20,510			15,456
Energy Services
External customers (1)	417,608			316,703			756,538			592,885
Intercompany	2,679			3,255			930			5,766
Subtotal	728,776			570,156			1,259,080			1,008,249
Home Services and Other
External customers	7,449			7,292			16,424			15,968
Intercompany	1,055			639			2,086			1,536
Eliminations	(3,734		)	(3,894		)	(3,016		)	(7,302		)
Total	$	733,546		$	574,193		$	1,274,574		$	1,018,451
Depreciation and amortization
Natural Gas Distribution	$	12,263		$	11,598		$	24,293		$	22,836
Clean Energy Ventures	7,923			5,876			14,964			10,986
Energy Services	17			23			33			46
Midstream	2			2			3			3
Subtotal	20,205			17,499			39,293			33,871
Home Services and Other	199			237			420			464
Eliminations	(76		)	8			(125		)	(109		)
Total	$	20,328		$	17,744		$	39,588		$	34,226
Interest income (2)
Natural Gas Distribution	$	97		$	60		$	172		$	128
Energy Services	—			—			—			72
Midstream	512			450			974			714
Subtotal	609			510			1,146			914
Home Services and Other	132			123			253			160
Eliminations	(633		)	(580		)	(1,216		)	(951		)
Total	$	108		$	53		$	183		$	123

(1) Includes sales to Canada, which accounted for 1.5 and 2.9 percent of total operating revenues during the six months endedMarch 31, 2017 and 2016.

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

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Interest expense, net of capitalized interest
Natural Gas Distribution	$	6,392		$	4,690		$	13,216		$	9,278
Clean Energy Ventures	4,055			2,552			7,379			4,605
Energy Services	716			168			1,287			376
Midstream	414			130			470			172
Subtotal	11,577			7,540			22,352			14,431
Home Services and Other	123			105			197			105
Eliminations	(264		)	(276		)	(498		)	(390		)
Total	$	11,436		$	7,369		$	22,051		$	14,146
Income tax provision (benefit)
Natural Gas Distribution	$	30,499		$	22,704		$	45,386		$	36,211
Clean Energy Ventures	(24,756		)	(13,916		)	(36,643		)	(25,650		)
Energy Services	16,277			7,805			13,101			12,710
Midstream	1,502			1,530			3,151			3,170
Subtotal	23,522			18,123			24,995			26,441
Home Services and Other	1,066			(1,474		)	821			(2,604		)
Eliminations	(656		)	1,166			134			700
Total	$	23,932		$	17,815		$	25,950		$	24,537
Equity in earnings of affiliates
Midstream	$	6,119		$	3,508		$	9,450		$	7,053
Eliminations	(1,040		)	(1,106		)	(2,060		)	(2,245		)
Total	$	5,079		$	2,402		$	7,390		$	4,808
Net financial earnings
Natural Gas Distribution	$	60,233		$	48,967		$	90,581		$	79,893
Clean Energy Ventures	22,743			11,807			25,585			19,459
Energy Services	15,746			17,005			19,233			27,309
Midstream	4,948			2,228			7,335			4,572
Subtotal	103,670			80,007			142,734			131,233
Home Services and Other	708			(2,022		)	2,250			(1,763		)
Eliminations	(272		)	(80		)	(495		)	(298		)
Total	$	104,106		$	77,905		$	144,489		$	129,172
Capital expenditures
Natural Gas Distribution	$	34,744		$	47,366		$	73,599		$	96,406
Clean Energy Ventures	43,120			25,876			89,905			70,882
Subtotal	77,864			73,242			163,504			167,288
Home Services and Other	345			272			516			1,069
Total	$	78,209		$	73,514		$	164,020		$	168,357
Investments in equity investees
Midstream	$	5,902		$	3,102		$	10,538		$	5,948
Total	$	5,902		$	3,102		$	10,538		$	5,948

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						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Net financial earnings	$	104,106		$	77,905		$	144,489		$	129,172
Less:
Unrealized (gain) loss on derivative instruments and related transactions	(54,855		)	3,170			(26,553		)	2,035
Tax effect	19,679			(1,152		)	9,922			(739		)
Effects of economic hedging related to natural gas inventory	34,328			(1,054		)	16,389			2,759
Tax effect	(12,334		)	384			(6,130		)	(1,001		)
Net income to NFE tax adjustment	2,586			3,204			1,230			2,483
Net income	$	114,702		$	73,353		$	149,631		$	123,635

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

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

(Thousands)	March 31, 2017			September 30, 2016
Assets at end of period:
Natural Gas Distribution	$	2,572,576		$	2,517,401
Clean Energy Ventures	709,289			665,696
Energy Services	328,372			327,626
Midstream	212,439			186,259
Subtotal	3,822,676			3,696,982
Home Services and Other	126,255			109,487
Intercompany assets(1)	(91,572		)	(87,899		)
Total	$	3,857,359		$	3,718,570

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

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RELATED PARTY TRANSACTIONS

6 Months Ended

Mar. 31, 2017

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS

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 as a component of regulatory assets.

NJRES may periodically enter into storage or park and loan agreements with its affiliated FERC-jurisdictional natural gas storage facility, Steckman Ridge. As of March 31, 2017, NJRES has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 2020.

Demand fees, net of eliminations, associated with Steckman Ridge were as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
NJNG	$	1,383	$	1,385	$	2,793	$	2,774
NJRES	689		692		1,390		1,377
Total	$	2,072	$	2,077	$	4,183	$	4,151

The following table summarizes demand fees payable to Steckman Ridge as of:

(Thousands)	March 31, 2017		September 30, 2016
NJNG	$	780	$	775
NJRES	376		375
Total	$	1,156	$	1,150

NJNG and NJRES have entered into various asset management agreements, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to NJRES. As of March 31, 2017, NJNG and NJRES had three asset management agreements with expiration dates ranging from October 2017 through March 2018.

NJNG has entered into a 15-year transportation precedent agreement for committed capacity of 180,000 Dths per day with PennEast, which is estimated to be in service by the first quarter of fiscal 2019.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Mar. 31, 2017

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 investments in two publicly traded energy companies.

Loans Receivable

Loans Receivable

NJNG provides 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 recorded $8.2 million and $7.8 million in other current assets and $40.7 million and $39.5 million in other noncurrent assets as of March 31, 2017 and September 30, 2016, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans.

NJNG's policy is to establish an allowance for doubtful accounts when loan balances are in arrears for more than 60 days. As of March 31, 2017 and September 30, 2016, there was no allowance for doubtful accounts established for the SAVEGREEN loans.

Recently Adopted Updates to the Accounting Standards Codification

Recently Adopted Updates to the Accounting Standards Codification

Stock Compensation

In March 2016, the FASB issued ASU 2016-09, an amendment to ASC 718, Compensation - Stock Compensation, which simplifies several aspects of the accounting for employee share-based compensation, including the accounting for income taxes and forfeitures. The new guidance also increased the threshold for tax withholding to the maximum statutory rate, as applicable, to maintain equity classification and amended the classification of certain tax transactions within the statement of cash flows.

The Company elected to early adopt the amended guidance during the third quarter of fiscal 2016 and applied the new provisions as of the beginning of the year of adoption on a retrospective or prospective basis depending on each amendment’s transition requirements. As such, effective October 1, 2015, NJR is recognizing forfeitures as they occur and is recognizing excess tax benefits (deficiencies) as a component of income tax (benefit) provision in its Unaudited Condensed Consolidated Statements of Operations on a prospective basis. All related information for prior periods has been adjusted throughout this report on a retrospective basis to reflect the effects of the adoption. See Note 11. Income Taxes for more information on these transactions.

In addition, the following amounts on the Unaudited Condensed Consolidated Financial Statements have been adjusted retrospectively during the three and six months endedMarch 31, 2016:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Three Months Ended
Statements of Operations
Income tax provision	$	17,840	$	(25	)	$	17,815
Net income	$	73,328	$	25		$	73,353
Earnings per common share
Basic	$	0.85	$	—		$	0.85
Diluted	$	0.84	$	—		$	0.84
Six Months Ended
Statements of Operations
Income tax provision	$	26,197	$	(1,660	)	$	24,537
Net income	$	121,975	$	1,660		$	123,635
Earnings per common share
Basic	$	1.42	$	0.02		$	1.44
Diluted	$	1.41	$	0.01		$	1.42
Cash flows from operating activities
Net income	$	121,975	$	1,660		$	123,635
Tax benefit from stock based compensation	$	—	$	1,660		$	1,660
Other noncurrent liabilities	$	2,302	$	(139	)	$	2,163
Net cash flows from operating activities	$	114,824	$	3,181		$	118,005
Cash flows from financing activities
Tax withholding payments related to net settled stock compensation	$	—	$	(3,181	)	$	(3,181	)
Cash flows from financing activities	$	53,547	$	(3,181	)	$	50,366

There was no impact to the Unaudited Condensed Consolidated Balance Sheets upon adoption of the new guidance.

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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or 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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis, which did not impact its financial position, results of operations or 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 on the balance sheet as a deduction from the carrying amount of the liability. The amendment does 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 amendment contained within ASU No. 2015-03 does not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis.

In addition, the following amounts on the Unaudited Condensed Consolidated Balance Sheets have been adjusted, retrospectively, as of September 30, 2016.

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Other noncurrent assets	$	68,708	$	(8,512	)	$	60,196
Total noncurrent assets	$	712,166	$	(8,512	)	$	703,654
Total assets	$	3,727,082	$	(8,512	)	$	3,718,570
Capitalization and Liabilities
Long-term debt	$	1,063,550	$	(8,512	)	$	1,055,038
Total capitalization	$	2,230,141	$	(8,512	)	$	2,221,629
Total capitalization and liabilities	$	3,727,082	$	(8,512	)	$	3,718,570

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 amendment provides 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 Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.

Other 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 the Company’s fiscal year ending September 30, 2019, and interim periods within that year. The Company continues to evaluate the provisions of ASC 606, however, based on the review of customer contracts to date, it is not anticipating a material impact to its financial position, results of operations or cash flows upon adoption. The Company anticipates significant new disclosures as a result of the new standard and currently expects to transition to the new guidance using the modified retrospective approach. The Company is also monitoring industry specific developments that may have an impact, including our ability to recognize revenue for contracts where collectability is uncertain.

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 or 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 the Company’s fiscal year ending September 30, 2018, and interim periods within that year. Upon adoption, the amendment will be applied on a prospective basis. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Financial Instruments

In January 2016, the FASB issued ASU 2016-01, an amendment to ASC 825, Financial Instruments, to address certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certain fair value changes for financial liabilities measured at fair value. It also simplifies the impairment assessment of equity investments without a readily determinable fair value by requiring a qualitative assessment. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year. Upon adoption, the amendment will be applied on a modified-retrospective basis. The Company evaluated the amendment and noted that, upon adoption, subsequent changes to the fair value of the Company’s available for sale securities will be recorded in the Consolidated Statement of Operations as opposed to other comprehensive income. The Company does not expect any other material impacts to its financial position, results of operations or cash flows upon adoption.

In June 2016, the FASB issued ASU 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. The guidance is effective for the Company’s fiscal year ending September 30, 2021, and interim periods within that year, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.

Leases

In February 2016, the FASB issued ASU 2016-02, an amendment to ASC 842, Leases, which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption. The guidance is effective for the Company’s fiscal year ending September 30, 2020, and interim periods within that year, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption.

Statement of Cash Flows

In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. The Company is currently evaluating the amendment to understand the impact on its consolidated statements of cash flows upon adoption.

In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company’s fiscal year ending September 30, 2019, with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its financial position, results of operations or cash flows upon adoption.

Business Combinations

In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on what accounting to apply to acquisitions.

Gains and Losses from the Derecognition of Nonfinancial Assets

In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. ASU No. 2017-05 may be applied retrospectively for all periods presented or retrospectively with a cumulative-effect adjustment at the date of adoption. The Company is currently evaluating the amendment to understand the impact on its financial position, results from operations, and cash flows upon adoption.

Compensation - Retirement Benefits

In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis for presentation and changes to capitalization of costs will be applied on a prospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on its financial position, results of operations and cash flows upon adoption. The Company is also monitoring industry specific developments on the new guidance to determine the appropriate treatment of these changes in a rate regulated environment.

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 to hedge Canadian dollar denominated gas purchases and/or sales. Therefore, the Company's primary underlying risks include commodity prices, interest rates and foreign currency. These contracts 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.

NJRES

Since NJRES chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, the changes in the fair value of these derivatives 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 exchange rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are typically used to hedge demand fee payments on pipeline capacity, storage and gas purchase agreements. Accordingly, changes in the fair value of foreign exchange contracts are recognized in gas purchases on the Unaudited Condensed Consolidated Statements of Operations. For transactions occurring on or before December 31, 2015, NJRES' foreign exchange contracts were designated as cash flow hedges, and the effective portion of the hedges were recorded in OCI.

As a result of NJRES entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating 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.

Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. The Company applies NPNS accounting to SREC forward and futures contracts entered into on or before December 31, 2015. Effective for contracts executed on or after January 1, 2016, NJRES no longer elects NPNS accounting treatment on all SREC forward sales contracts and recognizes changes in the fair value of these derivatives as a component of operating revenues. Upon settlement of the contract, the related revenue is recognized when the SREC is transferred to the counterparty.

NPNS is a contract-by-contract election and, where it makes sense to do so, we can and may elect normal accounting for certain contracts.

NJNG

Changes in fair value of NJNG's financial commodity derivatives are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis. Accordingly, physical natural gas 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 charged to expense in the current period earnings based on the BGSS factor times the therm sales. Effective for contracts executed on or after January 1, 2016, NJNG no longer elects NPNS accounting treatment on all physical forward commodity contracts. However, since NPNS is a contract-by-contract election, where it makes sense to do so, we can and may elect certain contracts to be normal. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets.

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 a 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 recovered in future rates. Upon settlement, any gain or loss will be amortized into earnings over the life of the future underlying 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 natural gas 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, SREC forward sales 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 the data is:

• widely accepted and public;

• non-proprietary and sourced from an independent third party; and

• 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)

6 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Summary of Gas in Storage

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

	March 31, 2017				September 30, 2016
($ in thousands)	Gas in Storage			Bcf	Gas in Storage			Bcf
NJRES		$	128,281	46.4		$	130,493	62.0
NJNG		15,233		4.3		75,758		21.3
Total		$	143,514	50.7		$	206,251	83.3

Accounts Receivable by Subsidiary

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

(Thousands)	March 31, 2017				September 30, 2016
NJRES	$	135,199	56	%	$	102,884	72	%
NJNG (1)	100,449		41		30,951		22
NJRCEV	2,405		1		1,807		1
NJRHS and other	4,645		2		7,016		5
Total	$	242,698	100	%	$	142,658	100	%

(1) Does not include unbilled revenues of $42.7 million and $5.7 million as of March 31, 2017 and September 30, 2016, respectively.

Schedule of Retrospective Application of New Accounting Standard

In addition, the following amounts on the Unaudited Condensed Consolidated Financial Statements have been adjusted retrospectively during the three and six months endedMarch 31, 2016:

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Three Months Ended
Statements of Operations
Income tax provision	$	17,840	$	(25	)	$	17,815
Net income	$	73,328	$	25		$	73,353
Earnings per common share
Basic	$	0.85	$	—		$	0.85
Diluted	$	0.84	$	—		$	0.84
Six Months Ended
Statements of Operations
Income tax provision	$	26,197	$	(1,660	)	$	24,537
Net income	$	121,975	$	1,660		$	123,635
Earnings per common share
Basic	$	1.42	$	0.02		$	1.44
Diluted	$	1.41	$	0.01		$	1.42
Cash flows from operating activities
Net income	$	121,975	$	1,660		$	123,635
Tax benefit from stock based compensation	$	—	$	1,660		$	1,660
Other noncurrent liabilities	$	2,302	$	(139	)	$	2,163
Net cash flows from operating activities	$	114,824	$	3,181		$	118,005
Cash flows from financing activities
Tax withholding payments related to net settled stock compensation	$	—	$	(3,181	)	$	(3,181	)
Cash flows from financing activities	$	53,547	$	(3,181	)	$	50,366

In addition, the following amounts on the Unaudited Condensed Consolidated Balance Sheets have been adjusted, retrospectively, as of September 30, 2016.

(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Other noncurrent assets	$	68,708	$	(8,512	)	$	60,196
Total noncurrent assets	$	712,166	$	(8,512	)	$	703,654
Total assets	$	3,727,082	$	(8,512	)	$	3,718,570
Capitalization and Liabilities
Long-term debt	$	1,063,550	$	(8,512	)	$	1,055,038
Total capitalization	$	2,230,141	$	(8,512	)	$	2,221,629
Total capitalization and liabilities	$	3,727,082	$	(8,512	)	$	3,718,570

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REGULATION (Tables)

6 Months Ended

Mar. 31, 2017

Regulated Operations [Abstract]

Schedule of Regulatory Assets and Liabilities

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

(Thousands)	March 31, 2017		September 30, 2016
Regulatory assets-current
Conservation Incentive Program	$	23,834	$	36,957
New Jersey Clean Energy Program	6,239		14,232
Underrecovered gas costs	13,271		—
Derivatives at fair value, net	—		3,097
Total current regulatory assets	$	43,344	$	54,286
Regulatory assets-noncurrent
Environmental remediation costs
Expended, net of recoveries	$	19,067	$	19,595
Liability for future expenditures	165,849		172,000
Deferred income taxes	21,209		20,273
Derivatives at fair value, net	4,392		23,384
SAVEGREEN	15,604		25,208
Postemployment and other benefit costs	151,414		157,027
Deferred Superstorm Sandy costs	14,116		15,201
Other noncurrent regulatory assets	5,273		8,606
Total noncurrent regulatory assets	$	396,924	$	441,294
Regulatory liability-current
Derivatives at fair value, net	$	5,747	$	—
Overrecovered gas costs	—		9,469
Total current regulatory liabilities	$	5,747	$	9,469
Regulatory liabilities-noncurrent
Cost of removal obligation	$	17,224	$	30,549
New Jersey Clean Energy Program	10,269		10,657
Other noncurrent regulatory liabilities	964		205
Total noncurrent regulatory liabilities	$	28,457	$	41,411

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DERIVATIVE INSTRUMENTS (Tables)

6 Months Ended

Mar. 31, 2017

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
			March 31, 2017						September 30, 2016
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives not designated as hedging instruments:
NJNG:
Physical commodity contracts	Derivatives - current		$	64		$	17		$	235		$	1,154
Financial commodity contracts	Derivatives - current		2,240			928			805			2,979
	Derivatives - noncurrent		—			—			75			386
Interest rate contracts	Derivatives - noncurrent		—			4,392			—			23,073
NJRES:
Physical commodity contracts	Derivatives - current		4,080			2,460			5,994			11,660
	Derivatives - noncurrent		6,084			588			3,987			1,212
Financial commodity contracts	Derivatives - current		25,717			29,127			22,929			45,255
	Derivatives - noncurrent		263			1,125			1,165			581
Foreign currency contracts	Derivatives - current		2			27			1			32
Fair value of derivatives not designated as hedging instruments			$	38,450		$	38,664		$	35,191		$	86,332
Total fair value of derivatives			$	38,450		$	38,664		$	35,191		$	86,332

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 March 31, 2017:
Derivative assets:
NJRES
Physical commodity contracts		$	10,164		$	(540	)		$	(200	)		$	9,424
Financial commodity contracts		25,980			(25,068		)		—				912
Foreign currency contracts		2			(2		)		—				—
Total NJRES		$	36,146		$	(25,610	)		$	(200	)		$	10,336
NJNG
Physical commodity contracts		$	64		$	(2	)		$	—			$	62
Financial commodity contracts		2,240			(928		)		(1,312		)		—
Total NJNG		$	2,304		$	(930	)		$	(1,312	)		$	62
Derivative liabilities:
NJRES
Physical commodity contracts		$	3,048		$	(540	)		$	—			$	2,508
Financial commodity contracts		30,252			(25,068		)		(5,184		)		—
Foreign currency contracts		27			(2		)		—				25
Total NJRES		$	33,327		$	(25,610	)		$	(5,184	)		$	2,533
NJNG
Physical commodity contracts		$	17		$	(2	)		$	—			$	15
Financial commodity contracts		928			(928		)		—				—
Interest rate contracts		4,392			—				—				4,392
Total NJNG		$	5,337		$	(930	)		$	—			$	4,407
As of September 30, 2016:
Derivative assets:
NJRES
Physical commodity contracts		$	9,981		$	(2,837	)		$	(755	)		$	6,389
Financial commodity contracts		24,094			(17,945		)		(6,149		)		—
Foreign currency contracts		1			(1		)		—				—
Total NJRES		$	34,076		$	(20,783	)		$	(6,904	)		$	6,389
NJNG
Physical commodity contracts		$	235		$	(31	)		$	—			$	204
Financial commodity contracts		880			(880		)		—				—
Total NJNG		$	1,115		$	(911	)		$	—			$	204
Derivative liabilities:
NJRES
Physical commodity contracts		$	12,872		$	(2,837	)		$	1,200			$	11,235
Financial commodity contracts		45,836			(17,945		)		(27,891		)		—
Foreign currency contracts		32			(1		)		—				31
Total NJRES		$	58,740		$	(20,783	)		$	(26,691	)		$	11,266
NJNG
Physical commodity contracts		$	1,154		$	(31	)		$	—			$	1,123
Financial commodity contracts		3,365			(880		)		(2,485		)		—
Interest rate contracts		23,073			—				—				23,073
Total NJNG		$	27,592		$	(911	)		$	(2,485	)		$	24,196

(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) Includes transactions with NAESB netting election, transactions held by FCMs 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 March 31, 2017:
Derivative assets:
NJRES
Physical commodity contracts		$	10,164		$	(540	)		$	(200	)		$	9,424
Financial commodity contracts		25,980			(25,068		)		—				912
Foreign currency contracts		2			(2		)		—				—
Total NJRES		$	36,146		$	(25,610	)		$	(200	)		$	10,336
NJNG
Physical commodity contracts		$	64		$	(2	)		$	—			$	62
Financial commodity contracts		2,240			(928		)		(1,312		)		—
Total NJNG		$	2,304		$	(930	)		$	(1,312	)		$	62
Derivative liabilities:
NJRES
Physical commodity contracts		$	3,048		$	(540	)		$	—			$	2,508
Financial commodity contracts		30,252			(25,068		)		(5,184		)		—
Foreign currency contracts		27			(2		)		—				25
Total NJRES		$	33,327		$	(25,610	)		$	(5,184	)		$	2,533
NJNG
Physical commodity contracts		$	17		$	(2	)		$	—			$	15
Financial commodity contracts		928			(928		)		—				—
Interest rate contracts		4,392			—				—				4,392
Total NJNG		$	5,337		$	(930	)		$	—			$	4,407
As of September 30, 2016:
Derivative assets:
NJRES
Physical commodity contracts		$	9,981		$	(2,837	)		$	(755	)		$	6,389
Financial commodity contracts		24,094			(17,945		)		(6,149		)		—
Foreign currency contracts		1			(1		)		—				—
Total NJRES		$	34,076		$	(20,783	)		$	(6,904	)		$	6,389
NJNG
Physical commodity contracts		$	235		$	(31	)		$	—			$	204
Financial commodity contracts		880			(880		)		—				—
Total NJNG		$	1,115		$	(911	)		$	—			$	204
Derivative liabilities:
NJRES
Physical commodity contracts		$	12,872		$	(2,837	)		$	1,200			$	11,235
Financial commodity contracts		45,836			(17,945		)		(27,891		)		—
Foreign currency contracts		32			(1		)		—				31
Total NJRES		$	58,740		$	(20,783	)		$	(26,691	)		$	11,266
NJNG
Physical commodity contracts		$	1,154		$	(31	)		$	—			$	1,123
Financial commodity contracts		3,365			(880		)		(2,485		)		—
Interest rate contracts		23,073			—				—				23,073
Total NJNG		$	27,592		$	(911	)		$	(2,485	)		$	24,196

(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) Includes transactions with NAESB netting election, transactions held by FCMs 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						Six Months Ended
		March 31,						March 31,
Derivatives not designated as hedging instruments:		2017			2016			2017			2016
NJRES:
Physical commodity contracts	Operating revenues	$	4,982		$	9,128		$	6,725		$	21,002
Physical commodity contracts	Gas purchases	(3,982		)	(5,583		)	(12,781		)	(26,820		)
Financial commodity contracts	Gas purchases	38,121			21,820			7,510			63,096
Foreign currency contracts	Gas purchases	53			—			(33		)	—
Total unrealized and realized gains (losses)		$	39,174		$	25,365		$	1,421		$	57,278

The following table reflects the gains (losses) associated with NJNG's derivative instruments as of:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
NJNG:
Physical commodity contracts	$	(3,780	)	$	(14,528	)	$	(2,730	)	$	(14,528	)
Financial commodity contracts	(418		)	(5,151		)	10,760			(10,786		)
Interest rate contracts	(1,690		)	(11,071		)	18,681			(8,705		)
Total unrealized and realized (losses) gains	$	(5,888	)	$	(30,750	)	$	26,711		$	(34,019	)

Effect of Derivative Instruments Designated as Cash Flow Hedges on OCI

The following table reflects the effect of derivative instruments that were designated as cash flow hedges on OCI during the three and six months endedMarch 31, 2016:

(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)
March 31, 2016	Three Months Ended		Six Months Ended			Three Months Ended		Six Months Ended
Foreign currency contracts	$	29	$	(35	)	$	30	$	42

Schedule of Outstanding Long (Short) Derivatives

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

		Volume (Bcf)
		March 31, 2017		September 30, 2016
NJNG	Futures	24.6		23.6
	Physical	5.7		9.2
NJRES	Futures	(64.2	)	(79.1	)
	Options	—		1.2
	Physical	64.0		94.6

Not included in the previous table are NJRES' gross notional amount of foreign currency transactions of approximately $2.2 million, NJNG’s treasury lock agreement as previously discussed and 314,500 SRECs at NJRES that are open as of March 31, 2017.

Schedule of Broker Margin Accounts by Company

The balances by company are as follows:

(Thousands)	Balance Sheet Location	March 31, 2017		September 30, 2016
NJNG	Broker margin - Current assets	$	3,354	$	4,822
NJRES	Broker margin - Current assets	$	20,250	$	42,822

Summary of Gross Credit Exposures

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of March 31, 2017. 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		$	155,318
Noninvestment grade		35,381
Internally rated investment grade		8,974
Internally rated noninvestment grade		27,114
Total		$	226,787

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FAIR VALUE (Tables)

6 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

Fair Value, by Balance Sheet Grouping

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

(Thousands)	March 31, 2017		September 30, 2016
Carrying value (1)	$	1,047,045	$	1,082,845
Fair market value	$	1,041,750	$	1,131,077

(1) Excludes capital leases of $45.9 million and $42.2 million as of March 31, 2017 and September 30, 2016, 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 March 31, 2017:
Assets:
Physical commodity contracts		$	—		$	10,228		$	—	$	10,228
Financial commodity contracts		28,220			—			—		28,220
Financial commodity contracts - foreign exchange		—			2			—		2
Available for sale equity securities - energy industry		65,884			—			—		65,884
Money market funds		65,115			—			—		65,115
Other		1,249			—			—		1,249
Total assets at fair value		$	160,468		$	10,230		$	—	$	170,698
Liabilities:
Physical commodity contracts		$	—		$	3,065		$	—	$	3,065
Financial commodity contracts		31,180			—			—		31,180
Financial commodity contracts - foreign exchange		—			27			—		27
Interest rate contracts		—			4,392			—		4,392
Total liabilities at fair value		$	31,180		$	7,484		$	—	$	38,664
As of September 30, 2016:
Assets:
Physical commodity contracts		$	—		$	10,216		$	—	$	10,216
Financial commodity contracts		24,974			—			—		24,974
Financial commodity contracts - foreign exchange		—			1			—		1
Available for sale equity securities - energy industry		55,789			—			—		55,789
Money market funds		34,072			—			—		34,072
Other		1,444			—			—		1,444
Total assets at fair value		$	116,279		$	10,217		$	—	$	126,496
Liabilities:
Physical commodity contracts		$	—		$	14,026		$	—	$	14,026
Financial commodity contracts		49,201			—			—		49,201
Financial commodity contracts - foreign exchange		—			32			—		32
Interest rate contracts		—			23,073			—		23,073
Total liabilities at fair value		$	49,201		$	37,131		$	—	$	86,332

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INVESTMENTS IN EQUITY METHOD INVESTEES (Tables)

6 Months Ended

Mar. 31, 2017

Investments, All Other Investments [Abstract]

Schedule of Equity Method Investments

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

(Thousands)	March 31, 2017		September 30, 2016
Steckman Ridge (1)	$	121,809	$	123,155
PennEast	31,082		17,993
Total	$	152,891	$	141,148

(1) Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2017 and September 30, 2016. 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)

6 Months Ended

Mar. 31, 2017

Earnings Per Share [Abstract]

Schedule of Earnings Per Share Basic and Diluted

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands, except per share amounts)	2017		2016		2017		2016
Net income, as reported	$	114,702	$	73,353	$	149,631	$	123,635
Basic earnings per share
Weighted average shares of common stock outstanding-basic	86,275		85,834		86,182		85,754
Basic earnings per common share	$1.33		$0.85		$1.74		$1.44
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	86,275		85,834		86,182		85,754
Incremental shares (1)	826		1,024		811		1,024
Weighted average shares of common stock outstanding-diluted	87,101		86,858		86,993		86,778
Diluted earnings per common share (2)	$1.32		$0.84		$1.72		$1.42

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

(2) There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for the three and six months endedMarch 31, 2017 and 2016.

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COMMON STOCK EQUITY (Tables)

6 Months Ended

Mar. 31, 2017

Equity [Abstract]

Changes in Common Stock Equity

Changes in common stock equity during the six months endedMarch 31, 2017, were 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, 2016	86,086		$	221,654	$	215,580			$	(15,155	)	$	(81,044	)	$	825,556		$	1,166,591
Net income															149,631			149,631
Other comprehensive income									7,558									7,558
Common stock issued:
Incentive plan	232		581		4,788													5,369
Dividend reinvestment plan (1)	279				(1,266		)					10,994						9,728
Cash dividend declared ($.51 per share)															(44,003		)	(44,003		)
Treasury stock and other	(233	)			(28		)					(8,566		)				(8,594		)
Balance at March 31, 2017	86,364		$	222,235	$	219,074			$	(7,597	)	$	(78,616	)	$	931,184		$	1,286,280

(1) Shares sold through the DRP are issued from treasury stock at average cost, which may differ from the actual market price paid.

Components of Accumulated Other Comprehensive Income (Loss), Net of Tax

The following table presents the changes in the components of accumulated other comprehensive income (loss), net of related tax effects during the three months ended March 31, 2017 and 2016:

(Thousands)	Available for Sale Securities			Cash Flow Hedges			Postemployment Benefit Obligation				Total
Balance at December 31, 2016	$	9,713		$	—		$	(19,036	)		$	(9,323	)
Other comprehensive income (loss), net of tax
Other comprehensive income, before reclassifications, net of tax of $(1,808), $0, $0, $(1,808)	3,054			—			—				3,054
Amounts reclassified from accumulated other comprehensive income, net of tax of $1,138, $0, $(217), $921	(1,646		)	—			318			(2)	(1,328		)
Net current-period other comprehensive income, net of tax of $(670), $0, $(217), $(887)	1,408			—			318				1,726
Balance at March 31, 2017	$	11,121		$	—		$	(18,718	)		$	(7,597	)
Balance as of December 31, 2015	$	10,086		$	(33	)	$	(15,523	)		$	(5,470	)
Other comprehensive income, net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(3,154), $(10), $0, $(3,164)	4,500			19			—				4,519
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(11), $(175), $(186)	—			19			257				276
Net current-period other comprehensive income, net of tax of ($3,154), $(21), $(175), $(3,350)	4,500			38			257				4,795
Balance as of March 31, 2016	$	14,586		$	5		$	(15,266	)		$	(675	)

The following table presents the changes in the components of accumulated other comprehensive income (loss), net of related tax effects during the six months ended March 31, 2017 and 2016:

(Thousands)	Available for Sale Securities			Cash Flow Hedges				Postemployment Benefit Obligation				Total
Balance at September 30, 2016	$	4,198		$	—			$	(19,353	)		$	(15,155	)
Other comprehensive income (loss), net of tax
Other comprehensive income, before reclassifications, net of tax of $(6,648), $0, $0, $(6,648)	10,096			—				—				10,096
Amounts reclassified from accumulated other comprehensive income, net of tax of $2,192, $0, $(434), $1,758	(3,173		)	—				635			(2)	(2,538		)
Net current-period other comprehensive income, net of tax of $(4,456), $0, $(434), $(4,890)	6,923			—				635				7,558
Balance at March 31, 2017	$	11,121		$	—			$	(18,718	)		$	(7,597	)
Balance as of September 30, 2015	$	6,385		$	—			$	(15,779	)		$	(9,394	)
Other comprehensive income (loss), net of tax
Other comprehensive income (loss), before reclassifications, net of tax of $(5,768), $13, $0, $(5,755)	8,201			(22		)		—				8,179
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(15), $(349), $(364)	—			27			(1)	513			(2)	540
Net current-period other comprehensive income, net of tax of ($5,768), $(2), $(349), $(6,119)	8,201			5				513				8,719
Balance as of March 31, 2016	$	14,586		$	5			$	(15,266	)		$	(675	)

(1) Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Unaudited Condensed Consolidated Statements of Operations. Effective January 1, 2016, the Company elected not to designate its foreign currency derivatives as accounting hedges and, as a result, changes in fair value of the effective portion of the hedges are no longer recorded in OCI.

(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)

6 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

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

(Thousands)	March 31, 2017			September 30, 2016			Expiration Dates
NJR
Bank revolving credit facilities(1)	$	425,000		$	425,000		September 2020
Notes outstanding at end of period	$	237,900		$	121,700
Weighted average interest rate at end of period	1.75		%	1.43		%
Amount available at end of period (2)	$	173,686		$	288,910
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		May 2019
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2) Letters of credit outstanding total $13.4 million and $14.4 million for March 31, 2017 and September 30, 2016, 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 for both March 31, 2017 and September 30, 2016, which reduces the amount available by the same amount.

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EMPLOYEE BENEFIT PLANS (Tables)

6 Months Ended

Mar. 31, 2017

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Benefit Costs

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

	Pension												OPEB
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	March 31,						March 31,						March 31,						March 31,
(Thousands)	2017			2016			2017			2016			2017			2016			2017			2016
Service cost	$	2,087		$	1,898		$	4,174		$	3,796		$	1,095		$	1,131		$	2,190		$	2,261
Interest cost	2,442			2,835			4,885			5,671			1,387			1,564			2,773			3,128
Expected return on plan assets	(4,828		)	(5,030		)	(9,656		)	(10,059		)	(1,191		)	(1,211		)	(2,383		)	(2,422		)
Recognized actuarial loss	2,206			1,821			4,413			3,641			1,092			818			2,185			1,637
Prior service cost amortization	28			27			55			55			(91		)	(91		)	(182		)	(182		)
Net periodic benefit cost	$	1,935		$	1,551		$	3,871		$	3,104		$	2,292		$	2,211		$	4,583		$	4,422

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COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

6 Months Ended

Mar. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment

Commitments as of March 31, 2017, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2017		2018		2019		2020		2021		Thereafter
NJRES:
Natural gas purchases	$	179,517	$	121,391	$	55,395	$	—	$	—	$	—
Storage demand fees	19,525		28,869		16,195		12,913		8,822		8,580
Pipeline demand fees	38,347		48,509		19,057		8,137		7,605		10,403
Sub-total NJRES	$	237,389	$	198,769	$	90,647	$	21,050	$	16,427	$	18,983
NJNG:
Natural gas purchases	$	45,266	$	11,250	$	—	$	—	$	—	$	—
Storage demand fees	14,568		29,187		25,772		14,476		7,802		11,705
Pipeline demand fees	25,400		81,229		116,976		112,555		90,106		732,538
Sub-total NJNG (1)	$	85,234	$	121,666	$	142,748	$	127,031	$	97,908	$	744,243
Total	$	322,623	$	320,435	$	233,395	$	148,081	$	114,335	$	763,226

(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)

6 Months Ended

Mar. 31, 2017

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

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

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Operating revenues
Natural Gas Distribution
External customers	$	295,546		$	242,536		$	481,102		$	394,142
Clean Energy Ventures
External customers	12,943			7,662			20,510			15,456
Energy Services
External customers (1)	417,608			316,703			756,538			592,885
Intercompany	2,679			3,255			930			5,766
Subtotal	728,776			570,156			1,259,080			1,008,249
Home Services and Other
External customers	7,449			7,292			16,424			15,968
Intercompany	1,055			639			2,086			1,536
Eliminations	(3,734		)	(3,894		)	(3,016		)	(7,302		)
Total	$	733,546		$	574,193		$	1,274,574		$	1,018,451
Depreciation and amortization
Natural Gas Distribution	$	12,263		$	11,598		$	24,293		$	22,836
Clean Energy Ventures	7,923			5,876			14,964			10,986
Energy Services	17			23			33			46
Midstream	2			2			3			3
Subtotal	20,205			17,499			39,293			33,871
Home Services and Other	199			237			420			464
Eliminations	(76		)	8			(125		)	(109		)
Total	$	20,328		$	17,744		$	39,588		$	34,226
Interest income (2)
Natural Gas Distribution	$	97		$	60		$	172		$	128
Energy Services	—			—			—			72
Midstream	512			450			974			714
Subtotal	609			510			1,146			914
Home Services and Other	132			123			253			160
Eliminations	(633		)	(580		)	(1,216		)	(951		)
Total	$	108		$	53		$	183		$	123

(1) Includes sales to Canada, which accounted for 1.5 and 2.9 percent of total operating revenues during the six months endedMarch 31, 2017 and 2016.

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

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Interest expense, net of capitalized interest
Natural Gas Distribution	$	6,392		$	4,690		$	13,216		$	9,278
Clean Energy Ventures	4,055			2,552			7,379			4,605
Energy Services	716			168			1,287			376
Midstream	414			130			470			172
Subtotal	11,577			7,540			22,352			14,431
Home Services and Other	123			105			197			105
Eliminations	(264		)	(276		)	(498		)	(390		)
Total	$	11,436		$	7,369		$	22,051		$	14,146
Income tax provision (benefit)
Natural Gas Distribution	$	30,499		$	22,704		$	45,386		$	36,211
Clean Energy Ventures	(24,756		)	(13,916		)	(36,643		)	(25,650		)
Energy Services	16,277			7,805			13,101			12,710
Midstream	1,502			1,530			3,151			3,170
Subtotal	23,522			18,123			24,995			26,441
Home Services and Other	1,066			(1,474		)	821			(2,604		)
Eliminations	(656		)	1,166			134			700
Total	$	23,932		$	17,815		$	25,950		$	24,537
Equity in earnings of affiliates
Midstream	$	6,119		$	3,508		$	9,450		$	7,053
Eliminations	(1,040		)	(1,106		)	(2,060		)	(2,245		)
Total	$	5,079		$	2,402		$	7,390		$	4,808
Net financial earnings
Natural Gas Distribution	$	60,233		$	48,967		$	90,581		$	79,893
Clean Energy Ventures	22,743			11,807			25,585			19,459
Energy Services	15,746			17,005			19,233			27,309
Midstream	4,948			2,228			7,335			4,572
Subtotal	103,670			80,007			142,734			131,233
Home Services and Other	708			(2,022		)	2,250			(1,763		)
Eliminations	(272		)	(80		)	(495		)	(298		)
Total	$	104,106		$	77,905		$	144,489		$	129,172
Capital expenditures
Natural Gas Distribution	$	34,744		$	47,366		$	73,599		$	96,406
Clean Energy Ventures	43,120			25,876			89,905			70,882
Subtotal	77,864			73,242			163,504			167,288
Home Services and Other	345			272			516			1,069
Total	$	78,209		$	73,514		$	164,020		$	168,357
Investments in equity investees
Midstream	$	5,902		$	3,102		$	10,538		$	5,948
Total	$	5,902		$	3,102		$	10,538		$	5,948

Reconciliation of Consolidated NFE to Consolidated Net Income

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

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2017			2016			2017			2016
Net financial earnings	$	104,106		$	77,905		$	144,489		$	129,172
Less:
Unrealized (gain) loss on derivative instruments and related transactions	(54,855		)	3,170			(26,553		)	2,035
Tax effect	19,679			(1,152		)	9,922			(739		)
Effects of economic hedging related to natural gas inventory	34,328			(1,054		)	16,389			2,759
Tax effect	(12,334		)	384			(6,130		)	(1,001		)
Net income to NFE tax adjustment	2,586			3,204			1,230			2,483
Net income	$	114,702		$	73,353		$	149,631		$	123,635

Reconciliation of Assets from Segment to Consolidated

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

(Thousands)	March 31, 2017			September 30, 2016
Assets at end of period:
Natural Gas Distribution	$	2,572,576		$	2,517,401
Clean Energy Ventures	709,289			665,696
Energy Services	328,372			327,626
Midstream	212,439			186,259
Subtotal	3,822,676			3,696,982
Home Services and Other	126,255			109,487
Intercompany assets(1)	(91,572		)	(87,899		)
Total	$	3,857,359		$	3,718,570

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

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RELATED PARTY TRANSACTIONS (Tables)

6 Months Ended

Mar. 31, 2017

Related Party Transactions [Abstract]

Schedule Of Demand Fees And Demand Fees Payable

Demand fees, net of eliminations, associated with Steckman Ridge were as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2017		2016		2017		2016
NJNG	$	1,383	$	1,385	$	2,793	$	2,774
NJRES	689		692		1,390		1,377
Total	$	2,072	$	2,077	$	4,183	$	4,151

The following table summarizes demand fees payable to Steckman Ridge as of:

(Thousands)	March 31, 2017		September 30, 2016
NJNG	$	780	$	775
NJRES	376		375
Total	$	1,156	$	1,150

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NATURE OF THE BUSINESS (Details) shares in Thousands, customer in Thousands	6 Months Ended
	Mar. 31, 2017 subsidiary customer shares
Common Units
Nature of Business [Line Items]
Ownership interest exchanged (in shares) | shares	1,840
Steckman Ridge
Nature of Business [Line Items]
Equity method investment, ownership percentage	50.00%
PennEast
Nature of Business [Line Items]
Equity method investment, ownership percentage	20.00%
NJNG
Nature of Business [Line Items]
Total retail customers | customer	528
NJR Retail Holdings Corporation
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	Mar. 31, 2017 USD ($) Bcf	Sep. 30, 2016 USD ($) Bcf
Inventory [Line Items]
Gas in Storage, value | $	$ 143,514	$ 206,251
Gas in Storage, Bcf | Bcf	50.7	83.3
NJRES
Inventory [Line Items]
Gas in Storage, value | $	$ 128,281	$ 130,493
Gas in Storage, Bcf | Bcf	46.4	62.0
NJNG
Inventory [Line Items]
Gas in Storage, value | $	$ 15,233	$ 75,758
Gas in Storage, Bcf | Bcf	4.3	21.3

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SALES TAX ACCOUNTING (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016	Jan. 01, 2017	Dec. 31, 2016
Subsequent Event [Line Items]
Sales tax	$ 16.9	$ 13.5	$ 28.1	$ 20.7
NEW JERSEY
Subsequent Event [Line Items]
State sales tax, percent					6.875%	7.00%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SALE OF ASSET (Details) - Mar. 08, 2017 $ in Millions	USD ($) a	ft²
Accounting Policies [Abstract]
Area of real estate property	5	56,400
Proceeds from sale of real estate	$ 9.4
Gain on sale of real estate	$ 1.9

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - AVAILABLE FOR SALE SECURITIES (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2017	Mar. 31, 2016	Sep. 30, 2016
Accounting Policies [Abstract]
Available for sale securities	$ 65,884	$ 65,884		$ 55,789
Unrealized gain		18,500		7,200
Unrealized gain, net of tax		11,100		$ 4,200
Proceeds from sale of available for sale securities	3,400	6,639	$ 0
Pre-tax gain on sale of available-for-sale securities	$ 2,800	$ 5,400

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - CUSTOMER ACCOUNTS RECEIVABLE (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed	$ 242,698	$ 142,658
Receivable by subsidiary, percentage	100.00%	100.00%
Unbilled revenues	$ 42,657	$ 5,744
NJRES
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed	$ 135,199	$ 102,884
Receivable by subsidiary, percentage	56.00%	72.00%
NJNG
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed	$ 100,449	$ 30,951
Receivable by subsidiary, percentage	41.00%	22.00%
NJRCEV
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed	$ 2,405	$ 1,807
Receivable by subsidiary, percentage	1.00%	1.00%
NJRHS and other
Accounts, Notes, Loans and Financing Receivable [Line Items]
Billed	$ 4,645	$ 7,016
Receivable by subsidiary, percentage	2.00%	5.00%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - LOAN RECEIVABLE (Details) - USD ($)	6 Months Ended
	Mar. 31, 2017	Sep. 30, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loans receivable in other current assets	$ 8,200,000	$ 7,800,000
Loans receivable in other noncurrent assets	$ 40,700,000	39,500,000
Threshold period in establishing allowance for doubtful accounts	60 days
Allowance for doubtful accounts	$ 0	$ 0
Minimum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loan term	2 years
Maximum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loan term	10 years

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - STOCK BASED COMPENSATION (Details) - shares	Jan. 25, 2017	Jan. 24, 2017
NJR 2017 Stock Award And Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance	3,135,000
Employees | NJR 2007 Stock Award And Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance		2,367,338
Directors | NJR 2007 Stock Award And Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issuance		4,223

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - NEW ACCOUNTING STANDARD (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016	Sep. 30, 2016
Income Statement [Abstract]
Income tax provision	$ 23,932	$ 17,815	$ 25,950	$ 24,537
Net income	$ 114,702	$ 73,353	$ 149,631	$ 123,635
EARNINGS PER COMMON SHARE
Basic (usd per share)	$ 1.33	$ 0.85	$ 1.74	$ 1.44
Diluted (usd per share)	$ 1.32	$ 0.84	$ 1.72	$ 1.42
Cash flows (used in) operating activities
Net income, as reported	$ 114,702	$ 73,353	$ 149,631	$ 123,635
Tax benefit from stock-based compensation			1,231	1,660
Other noncurrent liabilities			(2,997)	2,163
Net cash flows (used in) operating activities			171,804	118,005
Cash flows from financing activities
Tax withholding payments related to net settled stock compensation			(4,354)	(3,181)
Cash flows from financing activities			39,251	50,366
Assets
Other noncurrent assets	61,052		61,052		$ 60,196
Total noncurrent assets	683,098		683,098		703,654
Total assets	3,857,359		3,857,359		3,718,570
Capitalization and Liabilities
Long-term debt	1,023,968		1,023,968		1,055,038
Total capitalization	2,310,248		2,310,248		2,221,629
Total capitalization and liabilities	$ 3,857,359		$ 3,857,359		3,718,570
As Previously Reported
Income Statement [Abstract]
Income tax provision		17,840		26,197
Net income		$ 73,328		$ 121,975
EARNINGS PER COMMON SHARE
Basic (usd per share)		$ 0.85		$ 1.42
Diluted (usd per share)		$ 0.84		$ 1.41
Cash flows (used in) operating activities
Net income, as reported		$ 73,328		$ 121,975
Tax benefit from stock-based compensation				0
Other noncurrent liabilities				2,302
Net cash flows (used in) operating activities				114,824
Cash flows from financing activities
Tax withholding payments related to net settled stock compensation				0
Cash flows from financing activities				53,547
Assets
Other noncurrent assets					68,708
Total noncurrent assets					712,166
Total assets					3,727,082
Capitalization and Liabilities
Long-term debt					1,063,550
Total capitalization					2,230,141
Total capitalization and liabilities					3,727,082
Effect of Change
Income Statement [Abstract]
Income tax provision		(25)		(1,660)
Net income		$ 25		$ 1,660
EARNINGS PER COMMON SHARE
Basic (usd per share)		$ 0.00		$ 0.02
Diluted (usd per share)		$ 0.00		$ 0.01
Cash flows (used in) operating activities
Net income, as reported		$ 25		$ 1,660
Tax benefit from stock-based compensation				1,660
Other noncurrent liabilities				(139)
Net cash flows (used in) operating activities				3,181
Cash flows from financing activities
Tax withholding payments related to net settled stock compensation				(3,181)
Cash flows from financing activities				$ (3,181)
Assets
Other noncurrent assets					(8,512)
Total noncurrent assets					(8,512)
Total assets					(8,512)
Capitalization and Liabilities
Long-term debt					(8,512)
Total capitalization					(8,512)
Total capitalization and liabilities					$ (8,512)

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REGULATION - REGULATORY FILINGS (Details) - USD ($) $ in Millions	Mar. 31, 2017	Oct. 01, 2016
Schedule of Regulatory Filings [Line Items]
Increase in base tariff rates		$ 45.0
Return on equity		9.75%
Public utilities, approved equity capital structure, percentage		52.50%
Composite rate of depreciation		2.40%
Recovery of expenditures, approved rolling period		5 years
NJNG
Schedule of Regulatory Filings [Line Items]
Increase in base tariff rates	$ 4.3

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REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	$ 43,344	$ 54,286
Regulatory assets-noncurrent	396,924	441,294
Regulatory liability-current	5,747	9,469
Regulatory liabilities-noncurrent	28,457	41,411
Overrecovered gas costs
Regulatory Assets And Liabilities [Line Items]
Regulatory liability-current	0	9,469
Derivatives at fair value, net
Regulatory Assets And Liabilities [Line Items]
Regulatory liability-current	5,747	0
Cost of removal obligation
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	17,224	30,549
New Jersey Clean Energy Program
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	10,269	10,657
Other noncurrent regulatory liabilities
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	964	205
Conservation Incentive Program
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	23,834	36,957
New Jersey Clean Energy Program
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	6,239	14,232
Underrecovered gas costs
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	13,271	0
Derivatives at fair value, net
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	0	3,097
Regulatory assets-noncurrent	4,392	23,384
Expended, net of recoveries
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	19,067	19,595
Liability for future expenditures
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	165,849	172,000
Deferred income taxes
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	21,209	20,273
SAVEGREEN
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	15,604	25,208
Postemployment and other benefit costs
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	151,414	157,027
Deferred Superstorm Sandy costs
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	14,116	15,201
Other noncurrent regulatory assets
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	$ 5,273	$ 8,606

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DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) - USD ($)	Mar. 31, 2017	Sep. 30, 2016	Jun. 01, 2015
Derivatives, Fair Value [Line Items]
Benchmark interest rate			3.26%
Notional amount of foreign currency derivatives			$ 125,000,000
Fair Value
Derivative assets, current	$ 32,103,000	$ 29,964,000
Derivative liabilities, current	32,559,000	61,080,000
Derivative assets, noncurrent	6,347,000	5,227,000
Derivative liabilities, noncurrent	6,105,000	25,252,000
Derivative assets	38,450,000	35,191,000
Derivative liabilities	38,664,000	86,332,000
Foreign currency contracts
Derivatives, Fair Value [Line Items]
Notional amount of foreign currency derivatives	2,200,000
Not Designated as Hedging Instrument
Fair Value
Derivative assets	38,450,000	35,191,000
Derivative liabilities	38,664,000	86,332,000
NJNG | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	64,000	235,000
Derivative liabilities, current	17,000	1,154,000
NJNG | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	2,240,000	805,000
Derivative liabilities, current	928,000	2,979,000
Derivative assets, noncurrent	0	75,000
Derivative liabilities, noncurrent	0	386,000
NJNG | Not Designated as Hedging Instrument | Interest rate contracts
Fair Value
Derivative assets, noncurrent	0	0
Derivative liabilities, noncurrent	4,392,000	23,073,000
NJRES | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	4,080,000	5,994,000
Derivative liabilities, current	2,460,000	11,660,000
Derivative assets, noncurrent	6,084,000	3,987,000
Derivative liabilities, noncurrent	588,000	1,212,000
NJRES | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	25,717,000	22,929,000
Derivative liabilities, current	29,127,000	45,255,000
Derivative assets, noncurrent	263,000	1,165,000
Derivative liabilities, noncurrent	1,125,000	581,000
NJRES | Not Designated as Hedging Instrument | Foreign currency contracts
Fair Value
Derivative assets, current	2,000	1,000
Derivative liabilities, current	27,000	$ 32,000
Series Ll | NJNG
Derivatives, Fair Value [Line Items]
Debt issued	$ 125,000,000
Interest rate, stated percentage	5.60%

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DERIVATIVE INSTRUMENTS - OFFSETTING OF ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
NJRES
Derivative assets:
Amounts Presented in Balance Sheets	$ 36,146	$ 34,076
Offsetting Derivative Instruments	(25,610)	(20,783)
Financial Collateral Received/Pledged	(200)	(6,904)
Net Amounts	10,336	6,389
Derivative liabilities:
Amounts Presented in Balance Sheets	33,327	58,740
Offsetting Derivative Instruments	(25,610)	(20,783)
Financial Collateral Received/Pledged	(5,184)	(26,691)
Net Amounts	2,533	11,266
NJRES | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	10,164	9,981
Offsetting Derivative Instruments	(540)	(2,837)
Financial Collateral Received/Pledged	(200)	(755)
Net Amounts	9,424	6,389
Derivative liabilities:
Amounts Presented in Balance Sheets	3,048	12,872
Offsetting Derivative Instruments	(540)	(2,837)
Financial Collateral Received/Pledged	0	1,200
Net Amounts	2,508	11,235
NJRES | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	25,980	24,094
Offsetting Derivative Instruments	(25,068)	(17,945)
Financial Collateral Received/Pledged	0	(6,149)
Net Amounts	912	0
Derivative liabilities:
Amounts Presented in Balance Sheets	30,252	45,836
Offsetting Derivative Instruments	(25,068)	(17,945)
Financial Collateral Received/Pledged	(5,184)	(27,891)
Net Amounts	0	0
NJRES | Foreign currency contracts
Derivative assets:
Amounts Presented in Balance Sheets	2	1
Offsetting Derivative Instruments	(2)	(1)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	0
Derivative liabilities:
Amounts Presented in Balance Sheets	27	32
Offsetting Derivative Instruments	(2)	(1)
Financial Collateral Received/Pledged	0	0
Net Amounts	25	31
NJNG
Derivative assets:
Amounts Presented in Balance Sheets	2,304	1,115
Offsetting Derivative Instruments	(930)	(911)
Financial Collateral Received/Pledged	(1,312)	0
Net Amounts	62	204
Derivative liabilities:
Amounts Presented in Balance Sheets	5,337	27,592
Offsetting Derivative Instruments	(930)	(911)
Financial Collateral Received/Pledged	0	(2,485)
Net Amounts	4,407	24,196
NJNG | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	64	235
Offsetting Derivative Instruments	(2)	(31)
Financial Collateral Received/Pledged	0	0
Net Amounts	62	204
Derivative liabilities:
Amounts Presented in Balance Sheets	17	1,154
Offsetting Derivative Instruments	(2)	(31)
Financial Collateral Received/Pledged	0	0
Net Amounts	15	1,123
NJNG | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	2,240	880
Offsetting Derivative Instruments	(928)	(880)
Financial Collateral Received/Pledged	(1,312)	0
Net Amounts	0	0
Derivative liabilities:
Amounts Presented in Balance Sheets	928	3,365
Offsetting Derivative Instruments	(928)	(880)
Financial Collateral Received/Pledged	0	(2,485)
Net Amounts	0	0
NJNG | Interest rate contracts
Derivative liabilities:
Amounts Presented in Balance Sheets	4,392	23,073
Offsetting Derivative Instruments	0	0
Financial Collateral Received/Pledged	0	0
Net Amounts	$ 4,392	$ 23,073

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DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Foreign currency contracts | Gas purchases | Cash Flow Hedging
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion)		$ 29		$ (35)
Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion)		30		42
Not Designated as Hedging Instrument | NJRES
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	$ 39,174	25,365	$ 1,421	57,278
Not Designated as Hedging Instrument | NJRES | Physical commodity contracts | Operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	4,982	9,128	6,725	21,002
Not Designated as Hedging Instrument | NJRES | Physical commodity contracts | Gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	(3,982)	(5,583)	(12,781)	(26,820)
Not Designated as Hedging Instrument | NJRES | Financial commodity contracts | Gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	38,121	21,820	7,510	63,096
Not Designated as Hedging Instrument | NJRES | Foreign currency contracts | Gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	53	0	(33)	0
Not Designated as Hedging Instrument | NJNG
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	(5,888)	(30,750)	26,711	(34,019)
Not Designated as Hedging Instrument | NJNG | Physical commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	(3,780)	(14,528)	(2,730)	(14,528)
Not Designated as Hedging Instrument | NJNG | Financial commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	(418)	(5,151)	10,760	(10,786)
Not Designated as Hedging Instrument | NJNG | Interest rate contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in income on derivatives	$ (1,690)	$ (11,071)	$ 18,681	$ (8,705)

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DERIVATIVE INSTRUMENTS - VOLUME (Details)	Mar. 31, 2017 USD ($) Bcf certificate	Sep. 30, 2016 Bcf	Jun. 01, 2015 USD ($)
Derivative [Line Items]
Derivative, notional amount | $			$ 125,000,000
Foreign currency contracts
Derivative [Line Items]
Derivative, notional amount | $	$ 2,200,000
NJNG | Long | Futures
Derivative [Line Items]
Volume	24.6	23.6
NJNG | Long | Physical
Derivative [Line Items]
Volume	5.7	9.2
NJRES | Physical commodity contracts
Derivative [Line Items]
Number of SRECs | certificate	314,500
NJRES | Long | Physical
Derivative [Line Items]
Volume	64.0	94.6
NJRES | Long | Options
Derivative [Line Items]
Volume	0.0	1.2
NJRES | Short | Futures
Derivative [Line Items]
Volume	64.2	79.1

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DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
NJNG
Derivative [Line Items]
Broker margin - Current assets	$ 3,354	$ 4,822
NJRES
Derivative [Line Items]
Broker margin - Current assets	$ 20,250	$ 42,822

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DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2017	Sep. 30, 2016
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 226,787
Derivative, net liability position, aggregate fair value	4,500	$ 23,100
Additional collateral, aggregate fair value	4,500	$ 23,100
Investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	155,318
Noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	35,381
Internally rated investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	8,974
Internally rated noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 27,114

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FAIR VALUE - DEBT (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Capital leases	$ 45,900	$ 42,200
Level 2 | Carrying Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	1,047,045	1,082,845
Level 2 | Fair market value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 1,041,750	$ 1,131,077

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FAIR VALUE - HIERARCHY (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 38,450	$ 35,191
Liabilities	38,664	86,332
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	65,884	55,789
Other	1,249	1,444
Total assets at fair value	170,698	126,496
Total liabilities at fair value	38,664	86,332
Fair Value, Measurements, Recurring | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	10,228	10,216
Liabilities	3,065	14,026
Fair Value, Measurements, Recurring | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	28,220	24,974
Liabilities	31,180	49,201
Fair Value, Measurements, Recurring | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	2	1
Liabilities	27	32
Fair Value, Measurements, Recurring | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	4,392	23,073
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets, (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	65,884	55,789
Other	1,249	1,444
Total assets at fair value	160,468	116,279
Total liabilities at fair value	31,180	49,201
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets, (Level 1) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets, (Level 1) | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	28,220	24,974
Liabilities	31,180	49,201
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets, (Level 1) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets, (Level 1) | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	0	0
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	0	0
Other	0	0
Total assets at fair value	10,230	10,217
Total liabilities at fair value	7,484	37,131
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	10,228	10,216
Liabilities	3,065	14,026
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	2	1
Liabilities	27	32
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2) | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	4,392	23,073
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available for sale equity securities - energy industry	0	0
Other	0	0
Total assets at fair value	0	0
Total liabilities at fair value	0	0
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	0	0
Money market funds | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	65,115	34,072
Money market funds | Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets, (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	65,115	34,072
Money market funds | Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	0	0
Money market funds | Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	$ 0	$ 0

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INVESTMENTS IN EQUITY METHOD INVESTEES (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2017 USD ($) Investor mi	Sep. 30, 2016 USD ($)
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 152,891	$ 141,148
Steckman Ridge
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	121,809	123,155
Steckman Ridge | Equity Method Investee
Schedule of Equity Method Investments [Line Items]
Total outstanding principal balance of loans	70,400	70,400
PennEast
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 31,082	$ 17,993
Number of investors in pipeline construction and operation | Investor	5
Construction plan, project area (in miles) | mi	120

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EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Earnings Per Share [Abstract]
Net income, as reported	$ 114,702	$ 73,353	$ 149,631	$ 123,635
Basic earnings per share
Weighted average shares of common stock outstanding-basic (shares)	86,275,000	85,834,000	86,182,000	85,754,000
Basic earnings per common share (usd per share)	$ 1.33	$ 0.85	$ 1.74	$ 1.44
Diluted earnings per share
Weighted average shares of common stock outstanding-basic (shares)	86,275,000	85,834,000	86,182,000	85,754,000
Incremental shares	826,000	1,024,000	811,000	1,024,000
Weighted average shares of common stock outstanding-diluted (shares)	87,101,000	86,858,000	86,993,000	86,778,000
Diluted (loss) earnings per common share (usd per share)	$ 1.32	$ 0.84	$ 1.72	$ 1.42
Anti-dilutive shares excluded from the calculation of diluted earnings per share	0	0	0	0

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COMMON STOCK EQUITY - NARRATIVE (Details) - USD ($) shares in Thousands, $ in Millions	1 Months Ended	6 Months Ended
	Dec. 31, 2015	Mar. 31, 2017	Mar. 31, 2016
Equity [Abstract]
Number of treasury shares issued from raising of equity through the DRP	5,000	279	260
Equity raised through the DRP		$ 9.7	$ 8.2

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COMMON STOCK EQUITY - CHANGE IN COMMON STOCK EQUITY (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Dec. 31, 2015	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period (shares)				86,086,355
Balance as of beginning of period				$ 1,166,591
Net income		$ 114,702	$ 73,353	149,631	$ 123,635
Other comprehensive income		$ 1,726	$ 4,795	7,558	$ 8,719
Common stock issued:
Incentive plan				$ 5,369
Dividend reinvestment plan (in shares)	5,000,000			279,000	260,000
Dividend reinvestment plan				$ 9,728
Cash dividend declared ($.51 per share)				(44,003)
Treasury stock and other				$ (8,594)
Balance as of end of period (shares)		86,363,986		86,363,986
Balance as of end of period		$ 1,286,280		$ 1,286,280
Cash dividend declared per share (usd per share)		$ 0.255	$ 0.24	$ 0.51	$ 0.48
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period (shares)				86,086,000
Balance as of beginning of period				$ 221,654
Common stock issued:
Incentive plan (in shares)				232,000
Incentive plan				$ 581
Dividend reinvestment plan (in shares)				279,000
Treasury stock and other (shares)				(233,000)
Balance as of end of period (shares)		86,364,000		86,364,000
Balance as of end of period		$ 222,235		$ 222,235
Premium on Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period				215,580
Common stock issued:
Incentive plan				4,788
Dividend reinvestment plan				(1,266)
Treasury stock and other				(28)
Balance as of end of period		219,074		219,074
Accumulated Other Comprehensive (Loss) Income
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period		(9,323)	$ (5,470)	(15,155)	$ (9,394)
Other comprehensive income				7,558
Common stock issued:
Balance as of end of period	$ (5,470)	(7,597)	$ (675)	(7,597)	$ (675)
Treasury Stock And Other
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period				(81,044)
Common stock issued:
Dividend reinvestment plan				10,994
Treasury stock and other				(8,566)
Balance as of end of period		(78,616)		(78,616)
Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period				825,556
Net income				149,631
Common stock issued:
Cash dividend declared ($.51 per share)				(44,003)
Balance as of end of period		$ 931,184		$ 931,184

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COMMON STOCK EQUITY - ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period			$ 1,166,591
Other comprehensive income (loss), before reclassifications, net of tax	$ 3,054	$ 4,519	10,096	$ 8,179
Amounts reclassified from accumulated other comprehensive income, net of tax	(1,328)	276	(2,538)	540
Other comprehensive income	1,726	4,795	7,558	8,719
Balance as of end of period	1,286,280		1,286,280
Available for Sale Securities
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	9,713	10,086	4,198	6,385
Other comprehensive income (loss), before reclassifications, net of tax	3,054	4,500	10,096	8,201
Amounts reclassified from accumulated other comprehensive income, net of tax	(1,646)	0	(3,173)	0
Other comprehensive income	1,408	4,500	6,923	8,201
Balance as of end of period	11,121	14,586	11,121	14,586
Tax on other comprehensive income (loss) before reclassifications	1,808	3,154	6,648	5,768
Tax on amounts reclassified from accumulated other comprehensive income	(1,138)	0	(2,192)	0
Tax on net current-period other comprehensive income (loss)	670	3,154	4,456	5,768
Cash Flow Hedges
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	0	(33)	0	0
Other comprehensive income (loss), before reclassifications, net of tax	0	19	0	(22)
Amounts reclassified from accumulated other comprehensive income, net of tax	0	19	0	27
Other comprehensive income	0	38	0	5
Balance as of end of period	0	5	0	5
Tax on other comprehensive income (loss) before reclassifications	0	10	0	(13)
Tax on amounts reclassified from accumulated other comprehensive income	0	11	0	15
Tax on net current-period other comprehensive income (loss)	0	21	0	2
Postemployment Benefit Obligation
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(19,036)	(15,523)	(19,353)	(15,779)
Other comprehensive income (loss), before reclassifications, net of tax	0	0	0	0
Amounts reclassified from accumulated other comprehensive income, net of tax	318	257	635	513
Other comprehensive income	318	257	635	513
Balance as of end of period	(18,718)	(15,266)	(18,718)	(15,266)
Tax on other comprehensive income (loss) before reclassifications	0	0	0	0
Tax on amounts reclassified from accumulated other comprehensive income	217	175	434	349
Tax on net current-period other comprehensive income (loss)	217	175	434	349
Total
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(9,323)	(5,470)	(15,155)	(9,394)
Other comprehensive income			7,558
Balance as of end of period	(7,597)	(675)	(7,597)	(675)
Tax on other comprehensive income (loss) before reclassifications	1,808	3,164	6,648	5,755
Tax on amounts reclassified from accumulated other comprehensive income	(921)	186	(1,758)	364
Tax on net current-period other comprehensive income (loss)	$ 887	$ 3,350	$ 4,890	$ 6,119

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DEBT - CREDIT FACILITIES (Details) - USD ($)	Mar. 31, 2017	Sep. 30, 2016
NJR | Letter of Credit
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount	$ 13,400,000	$ 14,400,000
NJR | Notes
Line of Credit Facility [Line Items]
Amount outstanding at end of period	$ 237,900,000	$ 121,700,000
Weighted average interest rate at end of period	1.75%	1.43%
Amount available at end of period	$ 173,686,000	$ 288,910,000
NJR | Revolving Credit Facility | Committed Credit Facilities Due September 2020
Line of Credit Facility [Line Items]
Bank revolving credit facilities	425,000,000	425,000,000
NJNG | Commercial Paper
Line of Credit Facility [Line Items]
Amount outstanding at end of period	$ 0	$ 0
Weighted average interest rate at end of period	0.00%	0.00%
Amount available at end of period	$ 249,269,000	$ 249,269,000
NJNG | Letter of Credit
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount	731,000	731,000
NJNG | Revolving Credit Facility | Committed Credit Facilities Due May 2019
Line of Credit Facility [Line Items]
Bank revolving credit facilities	$ 250,000,000	$ 250,000,000

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DEBT - SCHEDULE OF LONG TERM DEBT (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Mar. 31, 2017	Mar. 31, 2017	Mar. 31, 2016
Debt Instrument [Line Items]
Payments of long-term debt		$ 41,660	$ 5,807
Proceeds from sale-leaseback transaction		9,587	7,107
NJNG
Debt Instrument [Line Items]
Proceeds from sale-leaseback transaction		9,600	$ 7,100
Sale leaseback transaction, other payments required		$ 1,000
NJNG | First Mortgage
Debt Instrument [Line Items]
Payments of long-term debt	$ 35,800
Series II | NJNG | First Mortgage
Debt Instrument [Line Items]
Interest rate, stated percentage	4.50%	4.50%
Series KK | NJNG | First Mortgage
Debt Instrument [Line Items]
Interest rate, stated percentage	4.90%	4.90%

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EMPLOYEE BENEFIT PLANS (Details) - USD ($)	3 Months Ended			6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2017	Mar. 31, 2016
Components of net periodic cost
Discretionary contribution			$ 30,000,000	$ 0
Pension
Components of net periodic cost
Service cost	$ 2,087,000	$ 1,898,000		4,174,000	$ 3,796,000
Interest cost	2,442,000	2,835,000		4,885,000	5,671,000
Expected return on plan assets	(4,828,000)	(5,030,000)		(9,656,000)	(10,059,000)
Recognized actuarial loss	2,206,000	1,821,000		4,413,000	3,641,000
Prior service cost amortization	28,000	27,000		55,000	55,000
Net periodic benefit cost	1,935,000	1,551,000		3,871,000	3,104,000
OPEB
Components of net periodic cost
Service cost	1,095,000	1,131,000		2,190,000	2,261,000
Interest cost	1,387,000	1,564,000		2,773,000	3,128,000
Expected return on plan assets	(1,191,000)	(1,211,000)		(2,383,000)	(2,422,000)
Recognized actuarial loss	1,092,000	818,000		2,185,000	1,637,000
Prior service cost amortization	(91,000)	(91,000)		(182,000)	(182,000)
Net periodic benefit cost	$ 2,292,000	$ 2,211,000		$ 4,583,000	$ 4,422,000

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INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016	Sep. 30, 2017	Sep. 30, 2016
Operating Loss Carryforwards [Line Items]
Forecasted effective tax rate			15.60%	17.70%
Forecasted tax credits, net of deferred tax						$ 27,100
Excess tax benefits associated with vesting of share-based awards	$ 1,500	$ 1,700
Actual effective tax rate since tax effects of awards are treated as discrete item			14.80%	16.60%
Deferred tax assets, federal	27,500		$ 27,500			27,500
Deferred tax asset, state	20,200		20,200			18,200
ITC carryforward	111,000		$ 111,000			74,000
ITC carryforward, expiration period			20 years
Federal
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	78,700		$ 78,700			78,700
State
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	$ 344,700		$ 344,700			310,600
Valuation allowance						$ 262
Scenario, Forecast
Operating Loss Carryforwards [Line Items]
Forecasted tax credits, net of deferred tax					$ 34,600

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COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2017 USD ($)
Long-term Purchase Commitment [Line Items]
Current charges recoverable through BGSS	$ 40,000
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	322,623
2018	320,435
2019	233,395
2020	148,081
2021	114,335
Thereafter	763,226
NJRES
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	237,389
2018	198,769
2019	90,647
2020	21,050
2021	16,427
Thereafter	18,983
NJRES | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	179,517
2018	121,391
2019	55,395
2020	0
2021	0
Thereafter	0
NJRES | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	19,525
2018	28,869
2019	16,195
2020	12,913
2021	8,822
Thereafter	8,580
NJRES | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	38,347
2018	48,509
2019	19,057
2020	8,137
2021	7,605
Thereafter	$ 10,403
NJRES | Minimum
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, contract term	1 year
NJRES | Maximum
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, contract term	10 years
NJNG
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	$ 85,234
2018	121,666
2019	142,748
2020	127,031
2021	97,908
Thereafter	744,243
NJNG | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	45,266
2018	11,250
2019	0
2020	0
2021	0
Thereafter	0
NJNG | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	14,568
2018	29,187
2019	25,772
2020	14,476
2021	7,802
Thereafter	11,705
NJNG | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2017	25,400
2018	81,229
2019	116,976
2020	112,555
2021	90,106
Thereafter	$ 732,538

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COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details)		6 Months Ended
	Jun. 29, 2016 USD ($)	Mar. 31, 2017 USD ($) site	Sep. 30, 2016 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		$ 396,924,000	$ 441,294,000
Manufactured gas plant remediation		165,849,000	172,000,000
Minimum
Site Contingency [Line Items]
Litigation settlement, gross		143,900,000
Loss contingency, estimate of possible loss		600,000
Maximum
Site Contingency [Line Items]
Litigation settlement, gross		231,600,000
Loss contingency, estimate of possible loss		3,200,000
Expended, net of recoveries
Site Contingency [Line Items]
Regulatory assets		19,067,000	19,595,000
Liability for future expenditures
Site Contingency [Line Items]
Regulatory assets		$ 165,849,000	$ 172,000,000
SBC | December 2015 SBC Filing
Site Contingency [Line Items]
Public utilities, approved rate, amount	$ 9,400,000

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting Information [Line Items]
Utility	$ 295,546	$ 242,536	$ 481,102	$ 394,142
Nonutility	438,000	331,657	793,472	624,309
Total operating revenues	733,546	574,193	1,274,574	1,018,451
Depreciation and amortization	20,328	17,744	39,588	34,226
Interest income	108	53	183	123
Interest expense, net of capitalized interest	11,436	7,369	22,051	14,146
Income tax provision (benefit)	23,932	17,815	25,950	24,537
Equity in earnings of affiliates	5,079	2,402	7,390	4,808
Net financial earnings	104,106	77,905	144,489	129,172
Capital expenditures	78,209	73,514	164,020	168,357
Investments in equity investees	5,902	3,102	$ 10,538	$ 5,948
Canada
Segment Reporting Information [Line Items]
Percentage to total operating revenues			1.50%	2.90%
Operating Segments
Segment Reporting Information [Line Items]
Total operating revenues	728,776	570,156	$ 1,259,080	$ 1,008,249
Depreciation and amortization	20,205	17,499	39,293	33,871
Interest income	609	510	1,146	914
Interest expense, net of capitalized interest	11,577	7,540	22,352	14,431
Income tax provision (benefit)	23,522	18,123	24,995	26,441
Net financial earnings	103,670	80,007	142,734	131,233
Capital expenditures	77,864	73,242	163,504	167,288
Operating Segments | Natural Gas Distribution
Segment Reporting Information [Line Items]
Utility	295,546	242,536	481,102	394,142
Depreciation and amortization	12,263	11,598	24,293	22,836
Interest income	97	60	172	128
Interest expense, net of capitalized interest	6,392	4,690	13,216	9,278
Income tax provision (benefit)	30,499	22,704	45,386	36,211
Net financial earnings	60,233	48,967	90,581	79,893
Capital expenditures	34,744	47,366	73,599	96,406
Operating Segments | Clean Energy Ventures
Segment Reporting Information [Line Items]
Nonutility	12,943	7,662	20,510	15,456
Depreciation and amortization	7,923	5,876	14,964	10,986
Interest expense, net of capitalized interest	4,055	2,552	7,379	4,605
Income tax provision (benefit)	(24,756)	(13,916)	(36,643)	(25,650)
Net financial earnings	22,743	11,807	25,585	19,459
Capital expenditures	43,120	25,876	89,905	70,882
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Nonutility	417,608	316,703	756,538	592,885
Depreciation and amortization	17	23	33	46
Interest income	0	0	0	72
Interest expense, net of capitalized interest	716	168	1,287	376
Income tax provision (benefit)	16,277	7,805	13,101	12,710
Net financial earnings	15,746	17,005	19,233	27,309
Operating Segments | Midstream
Segment Reporting Information [Line Items]
Depreciation and amortization	2	2	3	3
Interest income	512	450	974	714
Interest expense, net of capitalized interest	414	130	470	172
Income tax provision (benefit)	1,502	1,530	3,151	3,170
Equity in earnings of affiliates	6,119	3,508	9,450	7,053
Net financial earnings	4,948	2,228	7,335	4,572
Investments in equity investees	5,902	3,102	10,538	5,948
Intercompany
Segment Reporting Information [Line Items]
Nonutility	1,055	639	2,086	1,536
Intercompany | Energy Services
Segment Reporting Information [Line Items]
Nonutility	2,679	3,255	930	5,766
Home Services and Other
Segment Reporting Information [Line Items]
Nonutility	7,449	7,292	16,424	15,968
Depreciation and amortization	199	237	420	464
Interest income	132	123	253	160
Interest expense, net of capitalized interest	123	105	197	105
Income tax provision (benefit)	1,066	(1,474)	821	(2,604)
Net financial earnings	708	(2,022)	2,250	(1,763)
Capital expenditures	345	272	516	1,069
Eliminations
Segment Reporting Information [Line Items]
Nonutility	(3,734)	(3,894)	(3,016)	(7,302)
Depreciation and amortization	(76)	8	(125)	(109)
Interest income	(633)	(580)	(1,216)	(951)
Interest expense, net of capitalized interest	(264)	(276)	(498)	(390)
Income tax provision (benefit)	(656)	1,166	134	700
Equity in earnings of affiliates	(1,040)	(1,106)	(2,060)	(2,245)
Net financial earnings	$ (272)	$ (80)	$ (495)	$ (298)

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS (LOSS) RECONCILIATION (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting [Abstract]
Net financial earnings	$ 104,106	$ 77,905	$ 144,489	$ 129,172
Less:
Unrealized (gain) loss on derivative instruments and related transactions	(54,855)	3,170	(26,553)	2,035
Tax effect	19,679	(1,152)	9,922	(739)
Effects of economic hedging related to natural gas inventory	34,328	(1,054)	16,389	2,759
Tax effect	(12,334)	384	(6,130)	(1,001)
Net income to NFE tax adjustment	2,586	3,204	1,230	2,483
NET INCOME	$ 114,702	$ 73,353	$ 149,631	$ 123,635

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BUSINESS SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Sep. 30, 2016
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	$ 3,857,359	$ 3,718,570
Operating Segments
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	3,822,676	3,696,982
Operating Segments | Natural Gas Distribution
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	2,572,576	2,517,401
Operating Segments | Energy Services
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	328,372	327,626
Operating Segments | Clean Energy Ventures
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	709,289	665,696
Operating Segments | Midstream
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	212,439	186,259
Home Services and Other
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	126,255	109,487
Intercompany Assets
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	$ (91,572)	$ (87,899)

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RELATED PARTY TRANSACTIONS (Details) $ in Thousands		3 Months Ended		6 Months Ended
	Apr. 01, 2010 USD ($) Bcf	Mar. 31, 2017 USD ($)	Mar. 31, 2016 USD ($)	Mar. 31, 2017 USD ($) Bcf / d contract	Mar. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement		$ 2,072	$ 2,077	$ 4,183	$ 4,151
Demand fees payable		1,156		$ 1,156		$ 1,150
Number of asset management agreements | contract				3
NJNG to NJRES Affilate
Related Party Transaction [Line Items]
Asset management agreement, period	10 years
NJNG to Steckman RIdge Affiliate
Related Party Transaction [Line Items]
Natural gas sold at cost under asset management agreement (in Bcf) | Bcf	3
Approximate annual demand fees under agreement	$ 9,300
Demand fees expense recognized pertaining to related party agreement		1,383	1,385	$ 2,793	2,774
Demand fees payable		780		780		775
NJRES to Steckman Ridge Affiliate
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement		689	$ 692	1,390	$ 1,377
Demand fees payable		$ 376		$ 376		$ 375
NJNG to PennEast Affiliate
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