10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended December 31, 2021

OR

☐ 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					(732)	938‑1480
Wall	New Jersey	07719		(Registrant's telephone number, including area code)
(Address of principal executive offices)
Securities registered pursuant to Section 12 (b) of the Act:
Title of each class			Trading symbol(s)		Name of each exchange on which registered
Common Stock - $2.50 Par Value			NJR		New York Stock Exchange

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: ☒            No: ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).

Yes: ☒            No: ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a 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	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

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: ☐            No: ☒

The number of shares outstanding of $2.50 par value Common Stock as of January 31, 2022 was 96,061,402.

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	9
		Note 1. Nature of the Business	9
		Note 2. Summary of Significant Accounting Policies	9
		Note 3. Revenue	10
		Note 4. Regulation	13
		Note 5. Derivative Instruments	15
		Note 6. Fair Value	20
		Note 7. Investments in Equity Investees	21
		Note 8. Earnings Per Share	22
		Note 9. Debt	22
		Note 10. Employee Benefit Plans	24
		Note 11. Income Taxes	24
		Note 12. Leases	25
		Note 13. Commitments and Contingent Liabilities	27
		Note 14. Reporting Segment and Other Operations Data	29
		Note 15. Related Party Transactions	33
	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	33
	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	60
	ITEM 4.	Controls and Procedures	63
PART II. OTHER INFORMATION
	ITEM 1.	Legal Proceedings	64
	ITEM 1A.	Risk Factors	64
	ITEM 2.	Unregistered Sale of Equity Securities and Use of Proceeds	64
	ITEM 6.	Exhibits	65
		Signatures	66

New Jersey Resources Corporation

GLOSSARY OF KEY TERMS                                                                                                                                                       

Adelphia Gateway	Adelphia Gateway, LLC
AFUDC	Allowance for Funds Used During Construction
AMA	Asset Management Agreement
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
Bcf	Billion Cubic Feet
BGSS	Basic Gas Supply Service
BPU	New Jersey Board of Public Utilities
CARES Act	Coronavirus Aid, Relief, and Economic Security Act
CIP	Conservation Incentive Program
Clean Energy Ventures	Clean Energy Ventures segment
CME	Chicago Mercantile Exchange
COVID-19	Novel coronavirus disease
CR&R	Commercial Realty & Resources Corp.
DRP	NJR Direct Stock Purchase and Dividend Reinvestment Plan
Dths	Dekatherms
EE	Energy Efficiency
Energy Services	Energy Services segment
Exchange Act	Securities Exchange Act of 1934, as amended
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
Fitch	Fitch Ratings Company
FMB	First Mortgage Bond
GAAP	Generally Accepted Accounting Principles of the United States
Home Services and Other	Home Services and Other Operations
ICE	Intercontinental Exchange
IIP	Infrastructure Investment Program
IRS	Internal Revenue Service
ISDA	The International Swaps and Derivatives Association
ITC	Federal Investment Tax Credit
Leaf River	Leaf River Energy Center LLC
MGP	Manufactured Gas Plant
MMBtu	Million British Thermal Units
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
Natural Gas Distribution	Natural Gas Distribution segment
NFE	Net Financial Earnings
NJ RISE	New Jersey Reinvestment in System Enhancement
NJCEP	New Jersey's Clean Energy Program

1

New Jersey Resources Corporation

GLOSSARY OF KEY TERMS (cont.)
NJDEP	New Jersey Department of Environmental Protection
NJNG	New Jersey Natural Gas Company
NJNG Credit Facility	The $250 million unsecured committed credit facility expiring in September 2026
NJR Credit Facility	The $500 million unsecured committed credit facility expiring in September 2026
NJR or The Company	New Jersey Resources Corporation
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
OASDI	Old Age, Survivors and Disability Insurance tax
OCI	Other Comprehensive Income
O&M	Operation and Maintenance
OPEB	Other Postemployment Benefit Plans
PennEast	PennEast Pipeline Company, LLC
PPA	Power Purchase Agreement
RAC	Remediation Adjustment Clause
REC	Renewable Energy Certificate
SAFE II	Safety Acceleration and Facility Enhancement Program, Phase II
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
Storage and Transportation	Storage and Transportation segment
Supreme Court	Supreme Court of the United States
TETCO	Texas Eastern Transmission
The Tax Act	An Act to Provide for Reconciliation Pursuant to Titles II and V of the Concurrent Resolution on the Budget for Fiscal Year 2018, previously known as The Tax Cuts and Jobs Act of 2017
Third Circuit	The United States Court of Appeals for the Third Circuit
TREC	Transition Renewable Energy Certificate
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 1. “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 Exchange Act 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, RECs, 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 2022 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, 2021, as well as the following:

•risks related to the impact of COVID-19, including the rise of COVID-19 mutations that have resulted in increased rates of reported cases, as well as impacts on business operations, supply chain, financial performance and condition and cash flows;

•our ability to obtain governmental and regulatory approvals, 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, pipeline transportation systems and NJNG and Storage and Transportation infrastructure projects, including Adelphia Gateway, in a timely manner;

•risks associated with our investments in clean energy projects, including the availability of regulatory incentives and federal tax credits, the availability of viable projects, our eligibility for ITCs, the future market for RECs and electricity prices, our ability to complete construction of the projects and operational risks related to projects in service;

•risks associated with acquisitions and the related integration of acquired assets with our current operations, including the acquisition of Adelphia Gateway;

•our ability to comply with current and future regulatory requirements;

•volatility of natural gas and other commodity prices and their impact on NJNG customer usage, NJNG’s BGSS incentive programs, our Energy Services segment operations and our risk management efforts;

•the performance of our subsidiaries;

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

•the level and rate at which NJNG’s costs and expenses are incurred and the extent to which they are approved for recovery from customers through the regulatory process, including through future base rate case filings;

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

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

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

•demographic changes in our service territory and their effect on our customer growth;

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

•the impact of volatility in the equity and credit markets on our access to capital;

•our ability to comply with debt covenants;

•the results of legal or administrative proceedings with respect to claims, rates, environmental issues, natural gas cost prudence reviews and other matters;

•risks related to cyberattacks or failure of information technology systems;

•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;

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

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

•our ability to optimize our physical assets;

•weather and economic conditions, including those changes in weather and weather patterns that could be attributable to climate change;

•the costs of compliance with present and future environmental laws, potential climate change-related legislation or any legislation resulting from the 2019 New Jersey Energy Master Plan;

•uncertainties related to litigation, regulatory, administrative or environmental proceedings;

•changes to tax laws and regulations;

•any potential need to record a valuation allowance for our deferred tax assets;

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

•risks related to our employee workforce and succession planning;

•risks associated with the management of our joint ventures and partnerships; and

•risks associated with keeping pace with technological change.

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
	December 31,
(Thousands, except per share data)	2021		2020
OPERATING REVENUES
Utility	$	274,435	$	195,729
Nonutility	401,407		258,576
Total operating revenues	675,842		454,305
OPERATING EXPENSES
Natural gas purchases:
Utility	122,269		56,145
Nonutility	278,794		173,247
Related parties	1,846		1,734
Operation and maintenance	68,984		73,636
Regulatory rider expenses	16,671		10,701
Depreciation and amortization	30,393		27,362
Total operating expenses	518,957		342,825
OPERATING INCOME	156,885		111,480
Other income, net	4,136		4,117
Interest expense, net of capitalized interest	19,477		19,786
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	141,544		95,811
Income tax provision	30,807		17,441
Equity in earnings of affiliates	575		2,675
NET INCOME	$	111,312	$	81,045
EARNINGS PER COMMON SHARE
Basic	$1.16		$0.84
Diluted	$1.16		$0.84
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic	95,944		96,114
Diluted	96,356		96,415

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Net income	$	111,312	$	81,045
Other comprehensive income, net of tax
Reclassifications of losses to net income on derivatives designated as hedging instruments, net of tax of $(79) and $(112), respectively	264		231
Adjustment to postemployment benefit obligation, net of tax of $(233) and $(245), respectively	766		812
Other comprehensive income	$	1,030	$	1,043
Comprehensive income	$	112,342	$	82,088

See Notes to Unaudited Condensed Consolidated Financial Statements

4

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                    

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	Three Months Ended
	December 31,
(Thousands)	2021		2020
CASH FLOWS (USED IN) FROM OPERATING ACTIVITIES
Net income	$	111,312	$	81,045
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) on derivative instruments	(82,191)		(37,491)
Depreciation and amortization	30,393		27,362
Amortization of acquired wholesale energy contracts	589		716
Allowance for equity used during construction	(2,494)		(4,931)
Allowance for doubtful accounts	550		3,970
Non cash lease expense	889		1,324
Deferred income taxes	14,855		17,667
Equivalent value of ITCs recognized on equipment financing	(727)		—
Manufactured gas plant remediation costs	(12,368)		(1,274)
Equity in earnings, net of distributions received from equity investees and impairments	481		(1,189)
Cost of removal - asset retirement obligations	(282)		(256)
Contributions to postemployment benefit plans	(1,942)		(1,670)
Taxes related to stock-based compensation	(166)		76
Changes in:
Components of working capital	(153,195)		(74,434)
Other noncurrent assets	(1,529)		11,806
Other noncurrent liabilities	58,418		9,002
Cash flows (used in) from operating activities	(37,407)		31,723
CASH FLOWS USED IN INVESTING ACTIVITIES
Expenditures for:
Utility plant	(64,350)		(64,481)
Solar equipment	(25,380)		(22,335)
Storage and Transportation and other	(65,454)		(8,299)
Cost of removal	(9,114)		(14,765)
Distribution from equity investees in excess of equity in earnings	244		1,413
Investments in equity investees	—		(286)
Cash flows (used in) investing activities	(164,054)		(108,753)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Proceeds from long-term debt	100,000		—
Payments of long-term debt	(1,810)		(5,203)
Proceeds from short-term debt, net	110,650		9,000
Proceeds from sale leaseback transaction - solar	3,300		12,124
Proceeds from sale leaseback transaction	17,300		—
Payments of common stock dividends	(31,841)		(31,902)
Proceeds from issuance of common stock - DRP	3,805		3,911
Tax withholding payments related to net settled stock compensation	(3,433)		(5,534)
Cash flows from (used in) financing activities	197,971		(17,604)
Change in cash, cash equivalents and restricted cash	(3,490)		(94,634)
Cash, cash equivalents and restricted cash at beginning of period	6,043		119,423
Cash, cash equivalents and restricted cash at end of period	$	2,553	$	24,789
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	(117,010)	$	(108,143)
Inventories	(48,866)		5,792
Recovery of natural gas costs	(4,505)		(10,542)
Natural gas purchases payable	(18,752)		24,146
Natural gas purchases payable - related parties	(10)		74
Deferred revenue	51,107		(819)
Accounts payable and other	(44,374)		(38,413)
Prepaid expenses	(6,951)		(5,045)
Prepaid and accrued taxes	31,205		10,568
Restricted broker margin accounts	(459)		38,986
Customers' credit balances and deposits	6,080		7,014
Other current assets	(660)		1,948
Total	$	(153,195)	$	(74,434)
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid (received) for:
Interest (net of amounts capitalized)	$	13,935	$	11,298
Income taxes	$	(229)	$	230
Accrued capital expenditures	$	57,129	$	4,205
See Notes to Unaudited Condensed Consolidated Financial Statements

5

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                    

CONDENSED CONSOLIDATED BALANCE SHEETS

ASSETS

	(Unaudited)
(Thousands)	December 31, 2021		September 30, 2021
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	3,397,776	$	3,324,611
Construction work in progress	158,052		182,196
Nonutility plant and equipment, at cost	1,136,718		1,124,896
Construction work in progress	452,685		365,346
Total property, plant and equipment	5,145,231		4,997,049
Accumulated depreciation and amortization, utility plant	(622,934)		(611,827)
Accumulated depreciation and amortization, nonutility plant and equipment	(179,194)		(171,709)
Property, plant and equipment, net	4,343,103		4,213,513
CURRENT ASSETS
Cash and cash equivalents	1,259		4,749
Customer accounts receivable
Billed	266,815		212,838
Unbilled revenues	72,949		10,351
Allowance for doubtful accounts	(24,767)		(24,652)
Regulatory assets	38,653		30,118
Natural gas in storage, at average cost	242,692		193,606
Materials and supplies, at average cost	19,341		19,561
Prepaid expenses	15,117		8,166
Prepaid and accrued taxes	23,246		51,211
Derivatives, at fair value	39,783		35,251
Restricted broker margin accounts	42,716		72,840
Other current assets	22,518		20,235
Total current assets	760,322		634,274
NONCURRENT ASSETS
Investments in equity method investees	114,249		114,529
Regulatory assets	528,074		522,099
Operating lease assets	173,617		173,928
Derivatives, at fair value	1,978		3,403
Intangible assets, net	4,337		5,029
Software costs	5,464		5,582
Other noncurrent assets	50,013		49,921
Total noncurrent assets	877,732		874,491
Total assets	$	5,981,157	$	5,722,278

See Notes to Unaudited Condensed Consolidated Financial Statements

6

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                    

CAPITALIZATION AND LIABILITIES

	(Unaudited)
(Thousands, except share data)	December 31, 2021		September 30, 2021
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding December 31, 2021 — 95,961,710; September 30, 2021 — 95,709,662	$	241,274	$	240,644
Premium on common stock	513,134		502,584
Accumulated other comprehensive loss, net of tax	(33,498)		(34,528)
Treasury stock at cost and other; shares December 31, 2021 — 762,344; September 30, 2021 — 762,313	(15,067)		(12,448)
Retained earnings	1,011,135		934,610
Common stock equity	1,716,978		1,630,862
Long-term debt	2,274,176		2,162,164
Total capitalization	3,991,154		3,793,026
CURRENT LIABILITIES
Current maturities of long-term debt	74,461		72,840
Short-term debt	487,950		377,300
Natural gas purchases payable	149,945		168,697
Natural gas purchases payable to related parties	851		861
Deferred revenue	52,852		1,745
Accounts payable and other	168,197		223,497
Dividends payable	34,786		34,768
Accrued taxes	6,596		3,356
Regulatory liabilities	18,999		28,007
New Jersey Clean Energy Program	14,416		16,308
Derivatives, at fair value	30,049		87,145
Operating lease liabilities	4,531		4,300
Restricted broker margin accounts	15,475		—
Customers' credit balances and deposits	38,666		32,586
Total current liabilities	1,097,774		1,051,410
NONCURRENT LIABILITIES
Deferred income taxes	178,654		163,530
Deferred investment tax credits	2,930		3,010
Deferred revenue	14,621		847
Derivatives, at fair value	15,261		13,497
Manufactured gas plant remediation	126,872		135,012
Postemployment employee benefit liability	167,335		169,267
Regulatory liabilities	190,714		193,051
Operating lease liabilities	141,356		141,363
Asset retirement obligation	46,541		46,306
Other noncurrent liabilities	7,945		11,959
Total noncurrent liabilities	892,229		877,842
Commitments and contingent liabilities (Note 13)
Total capitalization and liabilities	$	5,981,157	$	5,722,278

See Notes to Unaudited Condensed Consolidated Financial Statements

7

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                    

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Unaudited)

(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, 2021	95,710	$	240,644	$	502,584		$	(34,528)	$	(12,448)	$	934,610	$	1,630,862
Net income	—	—		—			—		—		111,312		111,312
Other comprehensive income	—	—		—			1,030		—		—		1,030
Common stock issued:
Incentive compensation plan	147	367		7,135			—		—		—		7,502
Dividend reinvestment plan	105	263		3,415			—		—		—		3,678
Cash dividend declared ($.3625 per share)	—	—		—			—		—		(34,787)		(34,787)
Treasury stock and other	—	—		—			—		(2,619)		—		(2,619)
Balance at December 31, 2021	95,962	$	241,274	$	513,134		$	(33,498)	$	(15,067)	$	1,011,135	$	1,716,978

(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, 2020	95,949	$	240,243	$	491,982		$	(44,315)	$	8,485	$	947,501	$	1,643,896
Net income	—	—		—			—		—		81,045		81,045
Other comprehensive income	—	—		—			1,043		—		—		1,043
Common stock issued:
Incentive compensation plan	50	124		5,410			—		—		—		5,534
Dividend reinvestment plan (1)	140	—		(4,502)			—		5,593		—		1,091
Cash dividend declared ($.3325 per share)	—	—		—			—		—		(31,966)		(31,966)
Treasury stock and other	—	—		—			—		(2,429)		—		(2,429)
Balance at December 31, 2020	96,139	$	240,367	$	492,890		$	(43,272)	$	11,649	$	996,580	$	1,698,214

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

8

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS                                               

1. NATURE OF THE BUSINESS

The Company provides regulated natural gas distribution services, transmission and storage services and operates certain unregulated businesses primarily through the following:

NJNG provides natural gas utility service to approximately 566,600 customers throughout Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex counties in New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment.

NJRCEV, the Company's clean energy subsidiary, comprises the Clean Energy Ventures segment and invests in, owns and operates clean energy projects, including commercial and residential solar installations located in New Jersey, Connecticut, Rhode Island and New York.

NJRES comprises the Energy Services segment. Energy Services maintains and transacts around a portfolio of natural gas transportation and storage capacity contracts and provides physical wholesale energy, retail energy and energy management services in the U.S. and Canada.

NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, invests in energy-related ventures through its subsidiaries. The Company operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River and Adelphia Gateway, and is subject to rate regulation by FERC. The Company holds a 50 percent combined ownership interest in Steckman Ridge, located in Pennsylvania and 20 percent ownership interest in PennEast, which are accounted for under the equity method of accounting.

NJR Retail Holdings Corporation has two principal subsidiaries, NJRHS, which provides heating, central air conditioning, standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey, and CR&R, which owns commercial real estate. NJRHS and CR&R are included in Home Services and Other operations.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by the Company in accordance with the rules and regulations of the SEC and GAAP. The September 30, 2021 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 the Company's 2021 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 the Company'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, 2022. Intercompany transactions and accounts have been eliminated.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires the Company to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosure of contingencies during the reporting period. On a quarterly basis or more frequently whenever events or changes in circumstances indicate a need, the Company evaluates its estimates, including those related to the calculation of the fair value of derivative instruments, debt, equity method investments, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, long-lived assets, regulatory assets and liabilities, income taxes, pensions and other postemployment benefits, contingencies related to environmental matters and litigation. Asset retirement obligations are evaluated as often as needed. The Company’s estimates are based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources.

The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.

In March 2020, COVID-19 was declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention and has spread globally, including throughout the U.S. The Company’s Unaudited Condensed Consolidated Financial Statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the balance sheet date and reported amounts of revenue and expenses during the reporting periods presented.

The Company continues to closely monitor developments related to the COVID-19 pandemic and has, when appropriate, taken steps to ensure business continuity in the safe operation of its business. These steps include working from home for office-based employees, limiting direct contact with customers and suspending late payment fees for utility customers. While the Company and many businesses are beginning to return to normal operating practices, this remains an evolving situation. The timing for recovery of businesses and local economies, resurgences or mutations of the virus, and any potential future shutdowns remains unknown. Both the Company and NJNG continue to have sufficient liquidity to meet their current obligations and business operations remain fundamentally unchanged at this time. The Company will continue to monitor developments affecting its employees, customers, and operations and take additional steps to address the COVID-19 pandemic and its impacts, as necessary. The Company considered the impacts of COVID-19 on the assumptions and estimates used and determined that there have been no material adverse impacts on the Company’s results of operations as of December 31, 2021.

Revenues

Revenues from the sale of natural gas to NJNG customers are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for unbilled revenue. NJNG records unbilled revenue for natural gas services. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the month. At the end of each month, the amount of natural gas delivered to each customer after the last meter reading through the end of the respective accounting period is estimated, and recognizes unbilled revenues related to these amounts. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects, unaccounted-for natural gas and the most current tariff rates.

Clean Energy Ventures recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the transfer of certificates as per contractual settlement schedules. The Clean Energy Act of 2018 established guidelines for the closure of the SREC registration program to new applicants in New Jersey. The SREC program officially closed to new qualified solar projects on April 30, 2020.

In December 2019, the BPU established the TREC as the successor to the SREC program. TRECs provide a fixed compensation base multiplied by an assigned project factor in order to determine their value. The project factor is determined by the type and location of the project, as defined. All TRECs generated are required to be purchased monthly by a TREC program administrator as appointed by the BPU.

In June 2020, Clean Energy Ventures began generating TRECs for qualified new residential and commercial solar projects placed into service following the close of the SREC program. TREC revenue is recognized when TRECs are generated and are transferred monthly based upon metered solar electricity activity.

Revenues for Energy Services are recognized when the natural gas is physically delivered to the customer. In addition, changes in the fair value of derivatives that economically hedge the forecasted sales of the natural gas are recognized in operating revenues as they occur, as noted above. Energy Services also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues.

During December 2020, Energy Services entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts, which commenced on November 1, 2021. The AMAs include a series of temporary and permanent releases and revenue under these agreements is recognized as the performance obligations are satisfied. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis

over the agreed upon term. For permanent releases of pipeline capacity, which represent a transfer of contractual rights for such capacity, revenue is recognized upon the transfer of the underlying contractual rights. During the three months ended December 31, 2021, Energy Services recognized $22.1 million of operating revenue on the Unaudited Condensed Consolidated Statements of Operations. Amounts received in excess of revenue totaling $64.7 million are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets.

The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, related usage fees and hub services for the use of storage space, injections and withdrawals from their natural gas storage facility and the delivery of natural gas to customers. Demand fees are recognized as revenue over the term of the related agreement while usage fees and hub services revenues are recognized as services are performed.

Revenues from all other activities are recorded in the period during which products or services are delivered and accepted by customers, or over the related contractual term. See Note 3. Revenue for further information.

Cash and Cash Equivalents

Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to irrevocable letters of credit at Leaf River and escrow balances for utility plant projects at NJNG, which are recorded in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets, respectively.

The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Unaudited Condensed Consolidated Balance Sheets to the total amounts in the Unaudited Condensed Consolidated Statements of Cash Flows as follows:

(Thousands)	December 31, 2021		September 30, 2021		December 31, 2020
Balance Sheet
Cash and cash equivalents	$	1,259	$	4,749	$	22,358
Restricted cash in other noncurrent assets	$	1,294	$	1,294	$	2,431
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	2,553	$	6,043	$	24,789

Allowance for Doubtful Accounts

The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations, and macroeconomic factors, such as unemployment rates among others, including the estimated impact of the ongoing pandemic on the outstanding balances.

In December 2021, the Company deferred a portion of costs incurred related to bad debt for NJNG associated with customer accounts receivable as a regulatory asset resulting from the impacts of the ongoing COVID-19 pandemic. See Note 4. Regulation for additional information.

Loans Receivable

NJNG currently 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 fair value on the Unaudited Condensed Consolidated Balance Sheets. The Company has $14.1 million and $14.2 million recorded in other current assets and $32.6 million and $32.3 million in other noncurrent assets as of December 31, 2021 and September 30, 2021, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans. The Company regularly evaluates the credit quality and collection profile of its customers. If NJNG determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of December 31, 2021 and September 30, 2021, the Company has not recorded any impairments for SAVEGREEN loans.

Natural Gas in Storage

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

	December 31, 2021				September 30, 2021
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	110,673	22.7		$	115,824	27.6
Energy Services		132,019		28.9		77,782		18.8
Total		$	242,692	51.6		$	193,606	46.4

Software Costs

The Company capitalizes certain costs, such as software design and configuration, coding, testing and installation, that are incurred to purchase or create and implement computer software for internal use. Capitalized costs include external costs of materials and services utilized in developing or obtaining internal-use software and payroll and payroll-related costs for employees who are directly associated with and devote time to the internal-use software project. Maintenance costs are expensed as incurred. Upgrades and enhancements are capitalized if it is probable that such expenditures will result in additional functionality. Amortization is recorded on the straight-line basis over the estimated useful lives.

The following tables present the software costs included in the Unaudited Condensed Consolidated Financial Statements:

(Thousands)	December 31, 2021		September 30, 2021
Balance Sheets
Utility plant, at cost	$	16,777	$	16,543
Construction work in progress	$	11,725	$	7,801
Nonutility plant and equipment, at cost	$	341	$	338
Construction work in progress	$	1	$	8
Accumulated depreciation and amortization, utility plant	$	(1,644)	$	(1,333)
Accumulated depreciation and amortization, nonutility plant and equipment	$	(16)	$	(29)
Software costs	$	5,464	$	5,582

	Three Months Ended
	December 31,
Statements of Operations	2021		2020
Operation and maintenance (1)	$	2,523	$	1,924
Depreciation and amortization	$	299	$	253

(1)During the three months ended December 31, 2021 and 2020, approximately $113,000 and $77,000, respectively, was amortized from software costs into O&M.

Sale Leasebacks

NJNG utilizes sale leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease or repurchase the asset at the end of the term. Proceeds from sale leaseback transactions are accounted for as financing arrangements and are included in long-term debt on the Unaudited Condensed Consolidated Balance Sheets. NJNG received $17.3 million during the three months ended December 31, 2021, in connection with the sale leaseback of its natural gas meters. There were no natural gas meter sale leasebacks recorded during the three months ended December 31, 2020.

In addition, for certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third parties and the concurrent leaseback of the assets. For sale leaseback transactions where the Company has concluded that the arrangement does not qualify as a sale as the Company retains control of the underlying assets and, as such, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the buyer-lessor that constitute a payment to acquire the

solar energy asset as a financing arrangement, which is recorded as a component of debt on the Unaudited Condensed Consolidated Balance Sheets.

The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from RECs and energy sales. The ITCs and other tax benefits associated with these solar projects transfer to the buyer; however, the payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax attributes. Accordingly, Clean Energy Ventures recognizes the equivalent value of the tax attributes in other income on the Unaudited Condensed Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease.

During the three months ended December 31, 2021 and 2020, Clean Energy Ventures received proceeds of $3.3 million and $12.1 million, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets.

Accumulated Other Comprehensive (Loss) Income

The following table presents the changes in the components of accumulated other comprehensive (loss) income, net of related tax effects during the three months ended December 31, 2021 and 2020:

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2021	$	(9,376)	$	(25,152)		$	(34,528)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive loss, net of tax of $(79), $(233), $(312), respectively	264		766		(1)	1,030
Balance at December 31, 2021	$	(9,112)	$	(24,386)		$	(33,498)
Balance at September 30, 2020	$	(10,397)	$	(33,918)		$	(44,315)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive loss, net of tax of $(112), $(245) and $(357)	231		812		(1)	1,043
Balance at December 31, 2020	$	(10,166)	$	(33,106)		$	(43,272)

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

Reclassification

Certain prior period amounts related to deferred revenue within current liabilities on the Unaudited Condensed Consolidated Balance Sheets and Unaudited Consolidated Condensed Statements of Cash Flows have been reclassified to conform to the current period presentation.

Recently Adopted Updates to the Accounting Standards Codification

Income Taxes

In December 2019, the FASB issued ASU No. 2019-12, an amendment to ASC 740, Income Taxes, which simplifies the accounting for income taxes and changes the accounting for certain income tax transactions, among other minor improvements. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. The amendments in this update were either not applicable, currently applied, or did not have a material impact on the Company's financial position, results of operations, cash flows or disclosures.

Investments - Equity Securities, Investments - Equity Method and Joint Ventures and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, an amendment to ASC 321, Investments - Equity Securities, ASC 323, Investments - Equity Method and Joint Ventures, and ASC 815, Derivatives and Hedging, which clarifies the interactions between the three ASU topics. The update requires an entity to evaluate observable transactions that necessitate applying or discontinuing the equity method of accounting when applying the measurement alternative in Topic 321. This evaluation occurs prior to applying or upon ceasing the equity method. The update also states that when applying paragraph 815-10-15-141(a) for

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forward contracts and purchased options, an entity is not required to assess whether the underlying securities will be accounted for under the equity method in accordance with Topic 323 or fair value method under Topic 825 upon settlement or exercise. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures.

Other

In October 2020, the FASB issued ASU No. 2020-10, Codification Improvements, which clarifies application of various provisions in the ASC by amending and adding new headings, cross referencing to other guidance, and refining or correcting terminology. It also improves the consistency by amending the ASC to include all disclosure guidance in the appropriate section. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures.

Other Recent Updates to the Accounting Standards Codification

Debt and Other

In August 2020, the FASB issued ASU No. 2020-06, an amendment to ASC 470, Debt, and ASC 815, Derivatives and Hedging, which changes the accounting for convertible instruments by reducing the number of acceptable accounting models to three models including, the embedded derivative, substantial premium, and traditional no proceeds allocated models. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it on either a modified or a full retrospective basis. The Company does not currently have convertible debt instruments and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption.

In May 2021, the FASB issued ASU No. 2021-04, an amendment to ASC 470, Debt, ASC 260, Earnings per Share, ASC 718, Stock Compensation, and ASC 815, Derivatives and Hedging. The update impacts equity-classified written call options that remain equity-classified after a modification or exchange. The guidance is effective for the Company beginning October 1, 2022, and will be applied on a prospective basis. The Company does not currently have equity-classified written call options and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Leases

In July 2021, the FASB issued ASU No. 2021-05, an amendment to ASC 842, Leases, which requires a lessor to classify a lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another classification, including sales-type or direct financing would trigger a loss at the lease commencement date. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it either on a retrospective basis to leases that have commenced or have been modified under ASC 842 or on a prospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Business Combinations

In October 2021, the FASB issued ASU No. 2021-08, an amendment to ASC 805, Business Combinations, which requires that an acquirer recognize, and measure contract assets and contract liabilities acquired in a business combination in accordance with Topic 606, Revenue from Contracts with Customers. The guidance is effective for the Company beginning October 1, 2023, and will be applied on a prospective basis to new acquisitions following the date of adoption. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

3. REVENUE

Revenue is recognized when a performance obligation is satisfied by transferring control of a product or service to a customer. Revenue is measured based on consideration specified in a contract with a customer using the output method of progress. The Company elected to apply the invoice practical expedient for recognizing revenue, whereby the amounts invoiced to customers represent the value to the customer and the Company’s performance completion as of the invoice date. Therefore, the Company does not disclose related unsatisfied performance obligations. The Company also elected the practical expedient to exclude from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales tax net in operating revenues on the Unaudited Condensed Consolidated Statements of Operations.

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Below is a listing of performance obligations that arise from contracts with customers, along with details on the satisfaction of each performance obligation, the significant payment terms and the nature of the goods and services being transferred, by reporting segment and other business operations:

Revenue Recognized Over Time:
Segment	Performance Obligation	Description
Natural Gas Distribution	Natural gas utility sales	NJNG's performance obligation is to provide natural gas to residential, commercial and industrial customers as demanded, based on regulated tariff rates, which are established by the BPU. Revenues from the sale of natural gas are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for quantities consumed but not billed during the period. Payment is due each month for the previous month's deliveries. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the billing period. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects and the most current tariff rates. NJNG is entitled to be compensated for performance completed until service is terminated. Customers may elect to purchase the natural gas commodity from NJNG or may contract separately to purchase natural gas directly from third-party suppliers. As NJNG is acting as an agent on behalf of the third-party supplier, revenue is recorded for the delivery of natural gas to the customer.
Clean Energy Ventures	Commercial solar electricity	Clean Energy Ventures operates wholly-owned solar projects that recognize revenue as electricity is generated and transferred to the customer. The performance obligation is to provide electricity to the customer in accordance with contract terms or the interconnection agreement and is satisfied upon transfer of electricity generated. Revenue is recognized as invoiced and the payment is due each month for the previous month's services.
Clean Energy Ventures	Residential solar electricity	Clean Energy Ventures provides access to residential rooftop and ground-mount solar equipment to customers who then pay the Company a monthly fee. The performance obligation is to provide electricity to the customer based on generation from the underlying residential solar asset and is satisfied upon transfer of electricity generated. Revenue is derived from the contract terms and is recognized as invoiced, with the payment due each month for the previous month's services.
Clean Energy Ventures	Transition renewable energy certificates	Clean Energy Ventures generates TRECs, which are created for every MWh of electricity produced by a solar generator. The performance obligation of Clean Energy Ventures is to generate electricity and TRECs, which are purchased monthly by a REC Administrator. Revenue is recognized upon generation.
Energy Services	Natural gas services	The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers in line with the terms of the contract and based on the services provided. Payment is due upon receipt of the invoice. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed upon term.
Storage and Transportation	Natural gas services	The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as customers receive the benefits of its service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement.
Home Services and Other	Service contracts	Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice.

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Revenue Recognized at a Point in Time:
Energy Services	Natural gas services	For a permanent release of pipeline capacity, the performance obligation of NJRES is the release of the pipeline capacity associated with certain natural gas transportation contracts and the transfer of the underlying contractual rights to the counterparty. Revenue is recognized upon the transfer of the underlying contractual rights.
Storage and Transportation	Natural gas services	The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from usage fees and hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Usage fees and hub services revenues are recognized as services are performed.
Home Services and Other	Installations	Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators to customers. The distinct performance obligation is the installation of the contracted appliance, which is satisfied at the point in time the item is installed. The transaction price for each installation differs accordingly. Revenue is recognized at a point in time upon completion of the installation, which is when the customer is billed.

Disaggregated revenues from contracts with customers by product line and by reporting segment and other business operations during the three months ended December 31, 2021 and 2020, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales (1)	$	223,796	—		—	—	—	$	223,796
Natural gas services	—		—		27,879	12,143	—	40,022
Service contracts	—		—		—	—	8,467	8,467
Installations and maintenance	—		—		—	—	5,484	5,484
Renewable energy certificates	—		846		—	—	—	846
Electricity sales	—		6,470		—	—	—	6,470
Eliminations (2	(337)		—		—	(559)	(99)	(995)
Revenues from contracts with customers	223,459		7,316		27,879	11,584	13,852	284,090
Alternative revenue programs (3)	10,654		—		—	—	—	10,654
Derivative instruments	40,322		2,867	(4)	341,365	—	—	384,554
Eliminations (2)	—		—		(3,456)	—	—	(3,456)
Revenues out of scope	50,976		2,867		337,909	—	—	391,752
Total operating revenues	$	274,435	10,183		365,788	11,584	13,852	$	675,842
2020
Natural gas utility sales	$	189,364	—		—	—	—	$	189,364
Natural gas services	—		—		6,428	13,104	—	19,532
Service contracts	—		—		—	—	8,259	8,259
Installations and maintenance	—		—		—	—	4,318	4,318
Renewable energy certificates	—		690		—	—	—	690
Electricity sales	—		4,388		—	—	—	4,388
Eliminations (1)	—		—		—	(657)	(167)	(824)
Revenues from contracts with customers	189,364		5,078		6,428	12,447	12,410	225,727
Alternative revenue programs (3)	1,568		—		—	—	—	1,568
Derivative instruments	4,797		1,292	(4)	223,049	—	—	229,138
Eliminations (2)	—		—		(2,128)	—	—	(2,128)
Revenues out of scope	6,365		1,292		220,921	—	—	228,578
Total operating revenues	$	195,729	6,370		227,349	12,447	12,410	$	454,305

(1)Includes building rent related to the Wall headquarters, which is eliminated in consolidation.

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

(3)Includes CIP revenue.

(4)Includes SREC revenue.

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Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the three months ended December 31, 2021 and 2020, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	151,308	2,972	—	—	13,775	$	168,055
Commercial and industrial	47,184		4,344	27,879	11,584	77	91,068
Firm transportation	22,675		—	—	—	—	22,675
Interruptible and off-tariff	2,292		—	—	—	—	2,292
Revenues out of scope	50,976		2,867	337,909	—	—	391,752
Total operating revenues	$	274,435	10,183	365,788	11,584	13,852	$	675,842
2020
Residential	$	137,224	2,722	—	—	12,204	$	152,150
Commercial and industrial	29,229		2,356	6,428	12,447	206	50,666
Firm transportation	21,104		—	—	—	—	21,104
Interruptible and off-tariff	1,807		—	—	—	—	1,807
Revenues out of scope	6,365		1,292	220,921	—	—	228,578
Total operating revenues	$	195,729	6,370	227,349	12,447	12,410	$	454,305

Customer Accounts Receivable/Credit Balances and Deposits

The timing of revenue recognition, customer billings and cash collections resulting in accounts receivables, billed and unbilled, and customers’ credit balances and deposits on the Unaudited Condensed Consolidated Balance Sheets during the three months ended December 31, 2021 and 2020, are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of September 30, 2021	$	212,838	$	10,351	$	32,586
Increase	53,977		62,598		6,080
Balance as of December 31, 2021	$	266,815	$	72,949	$	38,666
Balance as of September 30, 2020	$	134,173	$	9,226	$	25,934
Increase	63,468		44,568		7,014
Balance as of December 31, 2020	$	197,641	$	53,794	$	32,948

The following table provides information about receivables, which are included within accounts receivable, billed and unbilled, and customers’ credit balances and deposits, respectively, on the Unaudited Condensed Consolidated Balance Sheets as of December 31, 2021 and September 30, 2021:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
December 31, 2021
Customer accounts receivable
Billed	$	102,890	4,608	153,014	4,339	1,964	$	266,815
Unbilled	71,542		1,407	—	—	—	72,949
Customers' credit balances and deposits	(38,666)		—	—	—	—	(38,666)
Total	$	135,766	6,015	153,014	4,339	1,964	$	301,098
September 30, 2021
Customer accounts receivable
Billed	$	54,514	5,534	147,087	3,956	1,747	$	212,838
Unbilled	8,427		1,924	—	—	—	10,351
Customers' credit balances and deposits	(32,586)		—	—	—	—	(32,586)
Total	$	30,355	7,458	147,087	3,956	1,747	$	190,603

13

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

4. 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 filings to the BPU for review of its BGSS, CIP and other programs and related rates. Annual rate changes are typically requested to be effective at the beginning of the following fiscal year. The current base rates include a weighted average cost of capital of 6.84 percent and a return on common equity of 9.6 percent. All rate and program changes are subject to proper notification and BPU review and approval. In addition, NJNG is permitted to implement certain BGSS rate changes on a provisional basis with proper notification to the BPU.

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

(Thousands)	December 31, 2021		September 30, 2021
Regulatory assets-current
New Jersey Clean Energy Program	$	14,416	$	16,308
Conservation Incentive Program	22,493		11,839
Other current regulatory assets	1,371		1,554
Total current regulatory assets	$	38,280	$	29,701
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	64,662	$	58,483
Liability for future expenditures	126,881		135,012
Deferred income taxes	39,613		39,694
SAVEGREEN	37,342		32,941
Postemployment and other benefit costs	114,515		117,194
Deferred storm damage costs	3,800		4,343
Cost of removal	99,160		99,238
Other noncurrent regulatory assets	38,685		32,695
Total noncurrent regulatory assets	$	524,658	$	519,600
Regulatory liability-current
Overrecovered natural gas costs	$	11,659	$	5,510
Derivatives at fair value, net	7,340		22,497
Total current regulatory liabilities	$	18,999	$	28,007
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	189,131	$	190,386
Derivatives at fair value, net	—		1,166
Other noncurrent regulatory liabilities	688		336
Total noncurrent regulatory liabilities	$	189,819	$	191,888

(1)Reflects the re-measurement and subsequent amortization of NJNG's net deferred tax liabilities as a result of the change in federal tax rates enacted in the Tax Act.

At December 31, 2021, other noncurrent regulatory assets include deferred pandemic costs of $10.7 million primarily related to a portion of bad debt associated with customer accounts receivable resulting from the impacts of the ongoing COVID-19 pandemic. These costs are eligible for future regulatory recovery.

14

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 for Adelphia Gateway are comprised of the following:

(Thousands)	December 31, 2021		September 30, 2021
Total current regulatory assets	$	373	$	417
Total noncurrent regulatory assets	$	3,416	$	2,499
Total noncurrent regulatory liabilities	$	895	$	1,163

The assets are comprised primarily of the tax benefit associated with the equity component of AFUDC and the liability consists primarily of scheduling penalties. Recovery of regulatory assets is subject to FERC approval.

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

•On November 17, 2021, the BPU issued an order adopting a stipulation of settlement approving a $79.0 million increase to base rates, effective December 1, 2021. In addition, the order also included approval for the final increase for the NJ RISE/SAFE II programs, which totaled $269,000. The increase includes an overall rate of return on rate base of 6.84 percent, return on common equity of 9.6 percent, a common equity ratio of 54.0 percent and a depreciation rate of 2.78 percent.

•On November 17, 2021, the BPU approved a $2.9 million increase to the annual revenues credited to BGSS, a $13.0 million annual increase related to its balancing charge, as well as changes to CIP rates, which will result in a $6.3 million decrease to the annual recovery, effective December 1, 2021.

•On November 19, 2021, NJNG submitted notification of its intent to self-implement an increase to its BGSS rate which will result in an approximately $24.2 million increase to annual revenues credited to BGSS, effective December 1, 2021.

•On January 26, 2022, the BPU approved a stipulation to resolve the current EE annual cost recovery filing, which will increase annual recoveries by $2.2 million, effective February 1, 2022.

5. DERIVATIVE INSTRUMENTS

The Company is subject primarily 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 is exposed to foreign currency and interest rate risk and may utilize foreign currency derivatives to hedge Canadian dollar denominated natural gas purchases and/or sales and interest rate derivatives to reduce exposure to fluctuations in interest rates. All of these types of contracts are accounted for as derivatives, unless the Company elects NPNS, which is done on a contract-by-contract election. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company’s fair value measurement policies and level disclosures associated with the Company’s derivative instruments, see Note 6. Fair Value.

Energy Services

Energy Services 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 natural gas purchases or operating revenues, as appropriate for Energy Services, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of natural 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 natural gas purchases or operating revenues.

15

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Energy Services 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. Energy Services may utilize foreign currency derivatives to lock in the exchange rates 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 natural gas purchase agreements.

As a result of Energy Services 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 natural 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. Energy Services 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.

Natural Gas Distribution

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 a portfolio basis. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as 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 natural 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.

Clean Energy Ventures

The Company elects NPNS accounting treatment on PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to do so, the Company can and may elect to treat certain contracts as normal.

Fair Value of Derivatives

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

			Derivatives at Fair Value
			December 31, 2021						September 30, 2021
(Thousands)	Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	234		$	4		$	36		$	16
Financial commodity contracts	Derivatives - current		5,032			240			2,046			13
Energy Services:
Physical commodity contracts	Derivatives - current		2,285			18,592			2,818			24,592
	Derivatives - noncurrent		135			15,261			333			13,237
Financial commodity contracts	Derivatives - current		32,164			11,209			30,226			62,521
	Derivatives - noncurrent		1,843			—			3,068			260
Foreign currency contracts	Derivatives - current		68			4			125			3
	Derivatives - noncurrent		—			—			2			—
Total fair value of derivatives			$	41,761		$	45,310		$	38,654		$	100,642

16

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Offsetting of Derivatives

The Company transacts under master netting arrangements or equivalent agreements that allow it to offset derivative assets and liabilities with the same counterparty. However, the Company’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 the Company has the right to offset but elects not to, financial collateral, as well as the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(Thousands)	Amounts Presented on Balance Sheets (1)			Offsetting Derivative Instruments (2)			Financial Collateral Received/Pledged (3)			Net Amounts (4)
As of December 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	2,420		$	(908)		$	(200)		$	1,312
Financial commodity contracts		34,007			(9,247)			—			24,760
Foreign currency contracts		68			(4)			—			64
Total Energy Services		$	36,495		$	(10,159)		$	(200)		$	26,136
Natural Gas Distribution
Physical commodity contracts		$	234		$	—		$	—		$	234
Financial commodity contracts		5,032			(240)			—			4,792
Total Natural Gas Distribution		$	5,266		$	(240)		$	—		$	5,026
Derivative liabilities:
Energy Services
Physical commodity contracts		$	33,853		$	(908)		$	—		$	32,945
Financial commodity contracts		11,209			(9,247)			—			1,962
Foreign currency contracts		4			(4)			—			—
Total Energy Services		$	45,066		$	(10,159)		$	—		$	34,907
Natural Gas Distribution
Physical commodity contracts		$	4		$	—		$	—		$	4
Financial commodity contracts		240			(240)			—			—
Total Natural Gas Distribution		$	244		$	(240)		$	—		$	4
As of September 30, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	3,151		$	(894)		$	(700)		$	1,557
Financial commodity contracts		33,294			(33,294)			20,532			20,532
Foreign currency contracts		127			(3)						124
Total Energy Services		$	36,572		$	(34,191)		$	19,832		$	22,213
Natural Gas Distribution
Physical commodity contracts		$	36		$	(8)		$	—		$	28
Financial commodity contracts		2,046			(13)			—			2,033
Total Natural Gas Distribution		$	2,082		$	(21)		$	—		$	2,061
Derivative liabilities:
Energy Services
Physical commodity contracts		$	37,829		$	(894)		$	—		$	36,935
Financial commodity contracts		62,781			(33,294)			—			29,487
Foreign currency contracts		3			(3)			—			—
Total Energy Services		$	100,613		$	(34,191)		$	—		$	66,422
Natural Gas Distribution
Physical commodity contracts		$	16		$	(8)		$	—		$	8
Financial commodity contracts		13			(13)			—			—
Total Natural Gas Distribution		$	29		$	(21)		$	—		$	8

(1)Derivative assets and liabilities are presented on a gross basis on 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)                     

Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical natural 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 natural 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 Energy Services, although the Company's intended economic results relating to the entire transaction are unaffected.

The following table presents the effect of derivative instruments recognized on the Unaudited Condensed Consolidated Statements of Operations for the periods set forth below:

(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended
		December 31,
Derivatives not designated as hedging instruments:		2021		2020
Energy Services:
Physical commodity contracts	Operating revenues	$	150	$	5,252
Physical commodity contracts	Natural gas purchases	1,505		(5,054)
Financial commodity contracts	Natural gas purchases	61,189		47,755
Foreign currency contracts	Natural gas purchases	—		200
Total unrealized and realized loss		$	62,844	$	48,153

NJNG’s derivative contracts are part of the Company's risk management activities that relate to its natural gas purchases and BGSS incentive programs. 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 for the periods set forth below:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Natural Gas Distribution:
Physical commodity contracts	$	1,696	$	342
Financial commodity contracts	(14,647)		(4,272)
Total unrealized and realized (loss)	$	(12,951)	$	(3,930)

During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with debt issuances that were finalized in 2020. NJR designates its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges are recorded in OCI and upon settlement of the contracts, realized gains and (losses) are reclassified from OCI to interest expense on the Consolidated Statements of Operations. During both the three months ended December 31, 2021 and 2020, $343,000 of pre-tax loss was reclassified from OCI into income.

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

		Volume (Bcf)
	Transaction Type	December 31, 2021	September 30, 2021
Natural Gas Distribution	Futures	24.0	22.2
	Physical Commodity	1.5	7.6
Energy Services	Futures	(22.0)	(13.4)
	Swaps	(0.2)	(0.3)
	Physical Commodity	(4.9)	0.6

Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $63,000 as of December 31, 2021 and $(123,000) as of September 30, 2021, respectively, and 1.4 million SRECs that were open as of both December 31, 2021 and September 30, 2021.

18

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Broker Margin

Futures exchanges have contract specific 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 the Natural Gas Distribution and Energy Services segments. The balances are as follows:

(Thousands)	Balance Sheet Location	December 31, 2021		September 30, 2021
Natural Gas Distribution	Restricted broker margin accounts-current assets	$	5,358	$	2,790
Energy Services	Restricted broker margin accounts-current assets	$	37,358	$	70,050
	Restricted broker margin accounts-current liabilities	$	(15,475)	$	—

Wholesale Credit Risk

NJNG, Energy Services, Clean Energy Ventures and the Storage and Transportation segment 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, 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 then the Company could sustain a loss.

The Company 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 the Company's election not to extend credit or because exposure exceeds defined thresholds. Most of the Company'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 Fitch or Moody's. In these cases, the counterparty's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by Fitch and/or Moody's are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of December 31, 2021. 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 Clean Energy Ventures residential solar installations.

(Thousands)	Gross Credit Exposure
Investment grade		$	185,828
Noninvestment grade		11,016
Internally rated investment grade		23,742
Internally rated noninvestment grade		30,016
Total		$	250,602

Conversely, certain of NJNG's and Energy Services' 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. 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.

19

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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. There were no derivative instruments with credit-risk-related contingent features that were in a liability position for which collateral is required as of December 31, 2021 and 2020. 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.

6. 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, in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.

The estimated fair value of long-term debt, including current maturities, excluding finance leases, debt issuance costs and solar asset financing obligations, is as follows:

(Thousands)	December 31, 2021		September 30, 2021
Carrying value (1) (2) (3)	$	2,202,845	$	2,102,845
Fair market value	$	2,373,791	$	2,288,544

(1)Excludes finance leases of $35.1 million and $20.1 million as of December 31, 2021 and September 30, 2021, respectively.

(2)Excludes NJNG's debt issuance costs of $10.3 million and $9.1 million as of December 31, 2021 and September 30, 2021, respectively.

(3)Excludes NJR's debt issuance costs of $3.7 million and $3.3 million as of December 31, 2021 and September 30, 2021, respectively.

Clean Energy Ventures enters into transactions to sell certain commercial solar assets and lease the assets back for a term specified in the lease. These transactions are considered financing obligations for accounting purposes and are recorded within long-term debt on the Unaudited Condensed Consolidated Balance Sheets. The estimated fair value of solar asset financing obligations as of December 31, 2021 and September 30, 2021 was $131.5 million and $132.5 million, respectively.

The Company utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific issue and the Company's credit rating. As of December 31, 2021, the Company discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, investments in equity 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 1Unadjusted quoted prices for identical assets or liabilities in active markets. The Company'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 the Company refers to internally as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM.

Level 2Other 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. The Company'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

20

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). 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 3Inputs derived from a significant amount of unobservable market data. These include the Company's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of December 31, 2021:
Assets:
Physical commodity contracts		$	—		$	2,654		$	—	$	2,654
Financial commodity contracts		39,039			—			—		39,039
Financial commodity contracts - foreign exchange		—			68			—		68
Money market funds		41			—			—		41
Other		2,085			—			—		2,085
Total assets at fair value		$	41,165		$	2,722		$	—	$	43,887
Liabilities:
Physical commodity contracts		$	—		$	33,857		$	—	$	33,857
Financial commodity contracts		11,278			171			—		11,449
Financial commodity contracts - foreign exchange		—			4			—		4
Total liabilities at fair value		$	11,278		$	34,032		$	—	$	45,310

	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 September 30, 2021:
Assets:
Physical commodity contracts		$	—		$	3,187		$	—	$	3,187
Financial commodity contracts		35,340			—			—		35,340
Financial commodity contracts - foreign exchange		—			127			—		127
Money market funds		41			—			—		41
Other		1,815			—			—		1,815
Total assets at fair value		$	37,196		$	3,314		$	—	$	40,510
Liabilities:
Physical commodity contracts		$	—		$	37,845		$	—	$	37,845
Financial commodity contracts		62,188			606			—		62,794
Financial commodity contracts - foreign exchange		—			3			—		3
Total liabilities at fair value		$	62,188		$	38,454		$	—	$	100,642

21

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

7. INVESTMENTS IN EQUITY INVESTEES

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

(Thousands)	December 31, 2021		September 30, 2021
Steckman Ridge (1)	$	108,770	$	109,050
PennEast	5,479		5,479
Total	$	114,249	$	114,529

(1)Includes loans with a total outstanding principal balance of $70.4 million for both December 31, 2021 and September 30, 2021, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

Steckman Ridge

The Company holds a 50 percent equity method investment in Steckman Ridge, a jointly owned and controlled natural gas storage facility located in Bedford County, Pennsylvania. NJNG and Energy Services have entered into storage and park and loan agreements with Steckman Ridge. See Note 15. Related Party Transactions for more information on these intercompany transactions.

PennEast

The Company, through its subsidiary NJR Midstream Company, is a 20 percent investor in PennEast, a partnership whose purpose was to construct and operate a 120-mile natural gas pipeline that would have extended from northeast Pennsylvania to western New Jersey.

During the third quarter of fiscal 2021, the PennEast partnership determined that this project is no longer supported, and all further development has ceased. The Company recognized an other-than-temporary impairment charge of $92.0 million, or approximately $74.5 million, net of income taxes, which represents the best estimate of the salvage value of the remaining assets of the project. Other-than-temporary impairments are recorded in equity in earnings (losses) of affiliates in the Unaudited Condensed Consolidated Statements of Operations.

On December 16, 2021, the FERC dismissed PennEast’s pending applications. The order vacates the certificate authorization for the PennEast pipeline project in light of PennEast’s response to FERC staff’s November 23, 2021 request for a status update, in which PennEast informed the Commission it is no longer developing the project.

8. EARNINGS PER SHARE

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

	Three Months Ended
	December 31,
(Thousands, except per share amounts)	2021		2020
Net income, as reported	$	111,312	$	81,045
Basic earnings per share
Weighted average shares of common stock outstanding-basic	95,944		96,114
Basic earnings per common share	$1.16		$0.84
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	95,944		96,114
Incremental shares (1)	412		301
Weighted average shares of common stock outstanding-diluted	96,356		96,415
Diluted earnings per common share (2)(3)	$1.16		$0.84

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

(2)There were anti-dilutive shares of 32,317 excluded from the calculation of diluted earnings per share related to an equity forward sale agreement during the three months ended December 31, 2020.

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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 and committed unsecured credit facilities.

Credit Facilities

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

(Thousands)	December 31, 2021			September 30, 2021			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	500,000		$	500,000		September 2026
Notes outstanding at end of period	$	310,550		$	219,100
Weighted average interest rate at end of period	1.13		%	1.05		%
Amount available at end of period (2)	$	169,862		$	270,312
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		September 2026
Commercial paper and notes outstanding at end of period	$	177,400		$	158,200
Weighted average interest rate at end of period	0.55		%	0.17		%
Amount available at end of period (4)	$	71,869		$	91,069

(1)Committed credit facilities, which require commitment fees of 0.10 percent on the unused amounts.

(2)Letters of credit outstanding total $19.6 million at December 31, 2021 and $10.6 million at September 30, 2021, which reduces the amount available by the same amount.

(3)Committed credit facilities, which require commitment fees of 0.075 percent on the unused amounts.

(4)Letters of credit outstanding total $731,000 at both December 31, 2021 and September 30, 2021, 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 October 28, 2021, NJNG entered into a Note Purchase Agreement for $100 million of its senior notes, of which $50 million were issued at an interest rate of 2.97 percent, maturing in 2051, and $50 million were issued at an interest rate of 3.07 percent, maturing in 2061. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

NJNG received $17.3 million during the three months ended December 31, 2021, in connection with the sale leaseback of its natural gas meters. NJNG records a financing 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. During the three months ended December 31, 2021, NJNG exercised an early purchase option with respect to meter leases by making a final principal payment of $1.1 million. NJNG continues to evaluate this sale leaseback program based on current market conditions. Natural gas meters are excepted from the lien on NJNG property under the Mortgage Indenture. There were no natural gas meter sale leasebacks recorded during the three months ended December 31, 2020.

Clean Energy Ventures

Clean Energy Ventures enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over a period of five to 15 years. These transactions are treated as financing obligations for accounting purposes, and are typically secured by the renewable energy facility asset and its future cash flows from RECs and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if applicable; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Clean Energy Ventures

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continues to operate the solar assets, including related expenses, and retain the revenue generated from RECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. During the three months ended December 31, 2021 and 2020, Clean Energy Ventures received proceeds of $3.3 million and $12.1 million, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets.

10. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

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

	Pension				OPEB
	Three Months Ended				Three Months Ended
	December 31,				December 31,
(Thousands)	2021		2020		2021		2020
Service cost	$	2,073	$	2,182	$	1,076	$	1,211
Interest cost	2,408		2,278		1,589		1,518
Expected return on plan assets	(5,319)		(5,224)		(1,894)		(1,683)
Recognized actuarial loss	2,186		2,862		1,421		1,977
Prior service cost (credit) amortization	25		25		(36)		(45)
Net periodic benefit cost	$	1,373	$	2,123	$	2,156	$	2,978

The Company does not expect to be required to make additional contributions to fund the pension plans during fiscal 2022 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 three months ended December 31, 2021 and 2020.

There are no federal requirements to pre-fund OPEB benefits. However, the Company is required to fund certain amounts due to regulatory agreements with the BPU and estimates that it will contribute between $5 million and $10 million over each of the next five years. Additional contributions may be required based on market conditions and changes to assumptions.

11. INCOME TAXES

ASC Topic 740, Income Taxes requires the use of an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating its estimated annual effective tax rate, the Company considers forecasted annual pre-tax income and estimated permanent book versus tax differences. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

Changes in tax laws or tax rates are recognized in the financial reporting period that includes the enactment date, the date in which the act is signed into law.

The Company evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with unrecognized tax benefits. A tax benefit claimed, or expected to be claimed, on a tax return may be recognized if it is more likely than not that the position will be upheld upon examination by the applicable taxing authority. Interest and penalties related to unrecognized tax benefits, if any, are recognized within income tax expense and accrued interest, and penalties are recognized within other noncurrent liabilities on the Unaudited Condensed Consolidated Balance Sheets.

Effective Tax Rate

The forecasted effective tax rates were 21.6 percent and 17.6 percent, for the three months ended December 31, 2021 and 2020, respectively.

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To the extent there are discrete tax items that are not included in the forecasted effective tax rate, the actual effective tax rate may differ from the estimated annual effective tax rate. During the three months ended December 31, 2021 and 2020, discrete items totaled approximately $166,000 and $(76,000), respectively, related to excess tax expense (benefits) associated with the vesting of share-based awards. NJR’s actual effective tax rate was 21.7 percent and 17.7 percent during the three months ended December 31, 2021 and 2020, respectively.

Other Tax Items

As of December 31, 2021 and September 30, 2021, the Company has tax credit carryforwards of approximately $226.1 million and $224.2 million, respectively, which each have a life of 20 years. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2035.

As of December 31, 2021 and September 30, 2021, the Company has state income tax net operating losses of approximately $461.9 million and $554.6 million, respectively. These state net operating losses have varying carry-forward periods dictated by the state in which they were incurred; these state carry-forward periods range from seven to 20 years and began to expire in fiscal 2021, with the majority expiring after 2035. The Company expects to utilize this entire carryforward, other than as described below.

The impairment of the equity method investment in PennEast created potential net capital loss attributes totaling approximately $61.8 million, which can only be utilized to offset capital gains income, and can be carried back three years and forward five years prior to expiration.

As of December 31, 2021, the Company has a valuation allowance totaling $23.7 million comprised of approximately $17.3 million related to the recognition of state net operating loss carryforwards, which primarily relate to New Jersey and approximately $6.4 million related to potential capital loss carryforwards resulting from the impairment of the equity method investment in PennEast, which the Company believes may not be fully utilized prior to expiration. As of September 30, 2021, the Company had a valuation allowance totaling $23.6 million related to the state net operating loss carryforwards and the potential capital loss carryforwards resulting from the impairment of the equity method investment, as previously discussed.

The Consolidated Appropriations Act extended the 30 percent ITC for solar property that is under construction on or before December 31, 2019. Projects placed in service after December 31, 2019, may also qualify for a 30 percent federal ITC if five percent or more of the total costs of a solar property are incurred before the end of the applicable year and there are continuous efforts to advance towards completion of the project, based on the IRS guidance around ITC safe harbor determination. The credit declined to 26 percent for property under construction before the end of 2020. The Consolidated Appropriations Act, 2021 extended the 26 percent tax credit for property under construction during 2021 and 2022. The credit will drop to 22 percent for property under construction before the end of 2023. After 2023 the ITC will be reduced to 10 percent.

12. LEASES

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of its natural gas meters.

Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns.

Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five to 20 years. The Company’s office leases vary in duration, ranging from two to 17 years and may or may not include extension or early purchase options. The Company’s meter lease terms are between seven and ten years with purchase options available prior to the end of the term. Equipment leases include general office equipment that also vary in duration, with an average term of six years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The Company has elected an accounting policy that exempts leases with an original term of one year or less from the recognition requirements of ASC 842, Leases.

The Company has lease agreements with lease and non-lease components and has elected the practical expedient to combine lease and non-lease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not considered material to the Company. The Company’s lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

The following table presents the Company's lease costs included in the Unaudited Condensed Consolidated Statements of Operations:

		Three Months Ended
		December 31,
(Thousands)	Income Statement Location	2021		2020
Operating lease cost (1)	Operation and maintenance	$	2,119	$	2,089
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	396		1,246
Interest on lease liabilities	Interest expense, net of capitalized interest	80		221
Total finance lease cost		476		1,467
Short-term lease cost	Operation and maintenance	11		127
Variable lease cost	Operation and maintenance	191		153
Total lease cost		$	2,797	$	3,836

(1)Net of capitalized costs.

The following table presents supplemental cash flow information related to leases:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,037	$	1,737
Operating cash flows for finance leases	$	170	$	2,176
Financing cash flows for finance leases	$	2,275	$	5,997

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Assets obtained or modified for operating lease liabilities totaled approximately $808,000 and $9.3 million during the three months ended December 31, 2021 and 2020, respectively. Assets obtained or modified through finance lease liabilities totaled $17.3 million during the three months ended December 31, 2021. There were no assets obtained or modified through finance lease liabilities during the three months ended December 31, 2020.

The following table presents the balance and classifications of the Company's right of use assets and lease liabilities included in the Unaudited Condensed Consolidated Balance Sheets:

(Thousands)	Balance Sheet Location	December 31, 2021		September 30, 2021
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	173,617	$	173,928
Finance lease assets	Utility plant	23,286		13,489
Total lease assets		$	196,903	$	187,417
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,531	$	4,300
Finance lease liabilities	Current maturities of long-term debt	6,397		5,393
Noncurrent
Operating lease liabilities	Operating lease liabilities	141,356		141,363
Finance lease liabilities	Long-term debt	28,673		14,742
Total lease liabilities		$	180,957	$	165,798

For operating lease assets and liabilities, the weighted average remaining lease term was 29.7 years and 29.6 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.2 percent as of both December 31, 2021 and September 30, 2021.

For finance lease assets and liabilities as of December 31, 2021 and September 30, 2021, the weighted average remaining lease term was 4.7 years and 3.4 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.7 percent and 3.5 percent as of December 31, 2021 and September 30, 2021, respectively.

13. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through November 2038, for the supply, transportation and storage of natural gas. These contracts include annual fixed charges of approximately $191.0 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, the Energy Services segment enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by Energy Services 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.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Commitments as of December 31, 2021, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2022		2023		2024		2025		2026		Thereafter
Energy Services:
Natural gas purchases	$	101,257	$	1,857	$	—	$	—	$	—	$	—
Storage demand fees	15,217		12,177		6,698		5,018		2,375		906
Pipeline demand fees	49,519		46,628		22,259		19,131		15,211		18,648
Sub-total Energy Services	$	165,993	$	60,662	$	28,957	$	24,149	$	17,586	$	19,554
NJNG:
Natural gas purchases	$	7,668	$	—	$	—	$	—	$	—	$	—
Storage demand fees	34,738		38,107		17,743		7,740		2,171		1,879
Pipeline demand fees	104,124		144,971		133,176		132,456		125,788		1,121,334
Sub-total NJNG	$	146,530	$	183,078	$	150,919	$	140,196	$	127,959	$	1,123,213
Total	$	312,523	$	243,740	$	179,876	$	164,345	$	145,545	$	1,142,767

Certain pipeline demand fees totaling approximately $4.0 million per year, for which Energy Services is the responsible party, are being paid for by the counterparty to a capacity release transaction beginning November 1, 2021 for a period of 10 years.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of certain former 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 NJDEP regulations.

NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester, Toms River, Freehold and Aberdeen, New Jersey, 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 at the former 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 $115.7 million to $178.7 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of December 31, 2021, NJNG recorded a MGP remediation liability and a corresponding regulatory asset of approximately $126.9 million on the Unaudited Condensed Consolidated Balance Sheets based on the most likely amount. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and insurance recoveries, if any.

In June 2019, NJNG initiated a preliminary assessment of a site in Aberdeen, New Jersey to determine prior ownership and if former MGP operations were active at the location. The preliminary assessment and site investigation activities are ongoing at the Aberdeen, NJ site location. The estimated costs to complete the preliminary assessment and site investigation phase are included in the MGP remediation liability and corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets at December 31, 2021 and September 30, 2021. NJNG will continue to gather information to determine whether the obligation exists to undertake remedial action, if any, and refine its estimate of potential costs for this site as more information becomes available.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. On April 7, 2021, the BPU approved an increase in the RAC, which increased the annual recovery from $9.7 million to $11.1 million and was effective May 1, 2021. On September 30, 2021, NJNG filed its annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $2.0 million annually, effective April 1, 2022. As of December 31, 2021, $64.7 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination.

General

The Company is involved, and from time to time in the future may be involved, in a number of pending and threatened judicial, regulatory and arbitration proceedings relating to matters that arise in the ordinary course of business. In view of the inherent difficulty of predicting the outcome of litigation matters, particularly when such matters are in their early stages or where the claimants seek indeterminate damages, the Company cannot state with confidence what the eventual outcome of the pending litigation will be, what the timing of the ultimate resolution of these matters will be, or what the eventual loss, fines or penalties related to each pending matter will be, if any. In accordance with applicable accounting guidance, the Company establishes accruals for litigation for those matters that present loss contingencies as to which it is both probable that a loss will be incurred and the amount of such loss can be reasonably estimated. The Company also discloses contingent matters for which there is a reasonable possibility of a loss. Based upon currently available information, the Company believes that the results of litigation that are currently pending, taken together, will not have a materially adverse effect on the Company’s financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts accrued.

The foregoing statements about the Company’s litigation are based upon the Company’s judgments, assumptions and estimates and are necessarily subjective and uncertain. The Company has a number of threatened and pending litigation matters at various stages.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

14. REPORTING SEGMENT AND OTHER OPERATIONS DATA

The Company 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 reporting 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 and retail energy operations; the Storage and Transportation segment consists of the Company’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, other investments and general corporate activities.

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues
Natural Gas Distribution
External customers	$	274,435	$	195,729
Intercompany	337		—
Clean Energy Ventures
External customers	10,183		6,370
Energy Services
External customers (1)	365,788		227,349
Intercompany	3,456		2,128
Storage and Transportation
External customers	11,584		12,447
Intercompany	559		657
Subtotal	666,342		444,680
Home Services and Other
External customers	13,852		12,410
Intercompany	99		167
Eliminations	(4,451)		(2,952)
Total	$	675,842	$	454,305
Depreciation and amortization
Natural Gas Distribution	$	22,893	$	19,169
Clean Energy Ventures	5,233		5,433
Energy Services (2)	28		42
Storage and Transportation	2,133		2,640
Subtotal	30,287		27,284
Home Services and Other	204		260
Eliminations	(98)		(182)
Total	$	30,393	$	27,362
Interest income (3)
Natural Gas Distribution	$	193	$	82
Storage and Transportation	377		694
Subtotal	570		776
Home Services and Other	155		132
Eliminations	(224)		(239)
Total	$	501	$	669

(1)Includes sales to Canada for the Energy Services segment, which are immaterial.

(2)The amortization of acquired wholesale energy contracts is excluded above and is included in natural gas purchases - nonutility on the Unaudited Condensed Consolidated Statements of Operations.

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

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Interest expense, net of capitalized interest
Natural Gas Distribution	$	10,995	$	8,974
Clean Energy Ventures	5,427		5,034
Energy Services	675		680
Storage and Transportation	2,136		3,982
Subtotal	19,233		18,670
Home Services and Other	244		1,116
Total	$	19,477	$	19,786
Income tax provision (benefit)
Natural Gas Distribution	$	13,204	$	8,367
Clean Energy Ventures	(2,046)		(3,086)
Energy Services	20,505		12,122
Storage and Transportation	343		646
Subtotal	32,006		18,049
Home Services and Other	246		118
Eliminations	(1,445)		(726)
Total	$	30,807	$	17,441
Equity in earnings (loss) of affiliates
Storage and Transportation	$	1,056	$	3,193
Eliminations	(481)		(518)
Total	$	575	$	2,675
Net financial earnings (loss)
Natural Gas Distribution	$	51,080	$	49,467
Clean Energy Ventures	(6,821)		(10,274)
Energy Services	17,567		1,500
Storage and Transportation	2,962		3,508
Subtotal	64,788		44,201
Home Services and Other	447		(62)
Eliminations	535		518
Total	$	65,770	$	44,657
Capital expenditures
Natural Gas Distribution	$	73,464	$	79,246
Clean Energy Ventures	25,380		22,335
Storage and Transportation	65,375		7,613
Subtotal	164,219		109,194
Home Services and Other	79		686
Total	$	164,298	$	109,880
Investments in equity investees
Storage and Transportation	$	—	$	286
Total	$	—	$	286

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

(Thousands)	December 31, 2021		September 30, 2021
Assets at end of period:
Natural Gas Distribution	$	3,861,240	$	3,707,461
Clean Energy Ventures	937,696		914,788
Energy Services	393,744		365,423
Storage and Transportation	928,653		862,407
Subtotal	6,121,333		5,850,079
Home Services and Other	148,368		162,134
Intercompany assets (1)	(288,544)		(289,935)
Total	$	5,981,157	$	5,722,278

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

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Net financial earnings	$	65,770	$	44,657
Less:
Unrealized (gain) on derivative instruments and related transactions	(82,191)		(37,491)
Tax effect	19,536		8,913
Effects of economic hedging related to natural gas inventory	23,577		(7,532)
Tax effect	(5,603)		1,790
NFE tax adjustment	(861)		(2,068)
Net income	$	111,312	$	81,045

The Company uses derivative instruments as economic hedges of purchases and sales of physical natural 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 natural gas related to physical natural gas flow are recognized when the natural gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical natural gas flows. Timing differences occur in two ways:

•unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical natural 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 natural 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 natural 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. 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 natural gas flows. NFE also excludes impairment charges associated with equity method investments, which are non-cash charges considered unusual in nature that occur infrequently and are not indicative of the Company's performance for its ongoing operations. Included in the tax effects are current and deferred income tax expense corresponding with the components of NFE. The Company also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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New Jersey Resources Corporation

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

15. RELATED PARTY TRANSACTIONS

Effective April 1, 2020, NJNG entered into a 5-year agreement for 3 Bcf of firm storage capacity with Steckman Ridge, which expires on March 31, 2025. 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.

Energy Services may periodically enter into storage or park and loan agreements with its affiliated FERC-jurisdictional natural gas storage facility, Steckman Ridge. As of December 31, 2021, Energy Services has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2022.

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Natural Gas Distribution	$	1,558	$	1,568
Energy Services	288		166
Total	$	1,846	$	1,734

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

(Thousands)	December 31, 2021		September 30, 2021
Natural Gas Distribution	$	775	$	778
Energy Services	76		83
Total	$	851	$	861

NJNG and Energy Services have entered into various AMAs, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. As of December 31, 2021, NJNG and Energy Services had one AMA with an expiration date of March 31, 2022.

NJNG has entered into a 5-year transportation precedent agreement with Adelphia Gateway for committed capacity of 130,000 Dths per day, which is expected to begin during the 3rd quarter of fiscal 2022, dependent upon the completion of a compressor.

Energy Services has a 5-year agreement for 3 Bcf of firm storage capacity with Leaf River, which is eliminated in consolidation and expires in March 2024.

In March 2021, NJNG and Clean Energy Ventures entered into a 15-year sublease and PPA agreement related to an onsite solar array and the related energy output at the Company’s headquarters in Wall, New Jersey, the effects of which are immaterial to the consolidated financial statements.

In July 2021, NJNG entered into 16-year lease agreements with various NJR subsidiaries for office space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation.

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

OPERATIONS                                                                                                                                                                                  

Critical Accounting Estimates

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, 2021. Our critical accounting policies have not changed from those reported in the 2021 Annual Report on Form 10-K.

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New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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 a diversified energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in the U.S. and Canada. In addition, we invest in clean energy projects, storage and transportation assets and provide various repair, sales and installation services. A more detailed description of our organizational structure can be found in Item 1. Business of our 2021 Annual Report on Form 10-K.

Reporting Segments

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

In addition to our four reporting segments above, we have non-utility operations that either provide corporate support services or do not meet the criteria to be treated as a separate reporting 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.

Impacts of the COVID-19 Pandemic

We continue to closely monitor developments related to the COVID-19 pandemic and has, when appropriate, taken steps intended to limit potential exposure for our employees and those we serve, including continuity in the safe operation of our business. These steps include working from home for our office-based employees, limiting direct contact with our customers and suspending late payment fees for our utility customers. And while we, along with other businesses, are beginning to return to normal operating practices, this remains an evolving situation. The timing for recovery of businesses and local economies, resurgences or mutations of the virus, and any potential future shutdowns remains unknown. Both NJR and NJNG continue to

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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)                                                                                                                                                             

have sufficient liquidity to meet their current obligations and business operations remain fundamentally unchanged at this time. We cannot predict the nature and extent of impacts to future operations, or its effects on our financial condition, results of operations and cash flows. We will continue to monitor developments affecting our employees, customers, and operations and take additional steps to address the COVID-19 pandemic and its impacts, as necessary.

Operating Results

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

	Three Months Ended
	December 31,
(Thousands)	2021				2020
Net income (loss)
Natural Gas Distribution	$	51,080	46	%	$	49,467	61	%
Clean Energy Ventures	(6,821)		(6)		(10,274)		(13)
Energy Services	65,744		59		38,872		48
Storage and Transportation	2,962		3		3,508		4
Home Services and Other	447		—		(62)		—
Eliminations (1)	(2,100)		(2)		(466)		—
Total	$	111,312	100	%	$	81,045	100	%

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

The increase in net income during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, was driven primarily by increased earnings at Energy Services resulting from AMAs with an investment grade public utility, which commenced November 2021, along with an increase in natural gas prices.

Assets by reporting segment and operations are as follows:

(Thousands)	December 31, 2021				September 30, 2021
Assets
Natural Gas Distribution	$	3,861,240	65	%	$	3,707,461	65	%
Clean Energy Ventures	937,696		16		914,788		16
Energy Services	393,744		7		365,423		6
Storage and Transportation	928,653		15		862,407		15
Home Services and Other	148,368		2		162,134		3
Intercompany assets (1)	(288,544)		(5)		(289,935)		(5)
Total	$	5,981,157	100	%	$	5,722,278	100	%

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

The increase in assets was due primarily to an increase in accounts receivable at our Natural Gas Distribution segment, higher gas in storage at Energy Services, additional investment in utility plant in our Natural Gas Distribution segment, solar asset investments at Clean Energy Ventures and increased infrastructure spend in Storage and Transportation primarily related to the on-going conversion and construction of the southern end of Adelphia Gateway.

Non-GAAP Financial Measures

Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. Energy Services 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 natural gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. To the extent we utilize forwards, futures, or other derivatives to hedge forecasted SREC production, unrealized gains and losses are also eliminated from NFE. NFE also excludes impairment charges associated with equity method investments, which are a non-cash charge considered unusual in nature that occur infrequently and are not indicative of the Company's performance for our ongoing operations. Included in the tax effects are current and deferred income tax expense corresponding with the components of NFE.

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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)                                                                                                                                                             

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, the rate and resulting NFE are subject to change. No adjustment is needed during the fourth quarter, since the actual effective tax rate is calculated 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. Below is a reconciliation of consolidated net income, the most directly comparable GAAP measure, to NFE:

	Three Months Ended
	December 31,
(Thousands, except per share data)	2021		2020
Net income	$	111,312	$	81,045
Add:
Unrealized (gain) on derivative instruments and related transactions	(82,191)		(37,491)
Tax effect	19,536		8,913
Effects of economic hedging related to natural gas inventory (1)	23,577		(7,532)
Tax effect	(5,603)		1,790
NFE tax adjustment	(861)		(2,068)
Net financial earnings	$	65,770	$	44,657
Basic earnings per share	$	1.16	$	0.84
Add:
Unrealized (gain) on derivative instruments and related transactions	(0.86)		(0.39)
Tax effect	0.21		0.09
Effects of economic hedging related to natural gas inventory (1)	0.25		(0.08)
Tax effect	(0.06)		0.02
NFE tax adjustment	(0.01)		(0.02)
Basic NFE per share	$	0.69	$	0.46

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

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

	Three Months Ended
	December 31,
(Thousands)	2021				2020
Net financial earnings (loss)
Natural Gas Distribution	$	51,080	77	%	$	49,467	111	%
Clean Energy Ventures	(6,821)		(10)		(10,274)		(23)
Energy Services	17,567		27		1,500		3
Storage and Transportation	2,962		4		3,508		8
Home Services and Other	447		1		(62)		—
Eliminations (1)	535		1		518		1
Total	$	65,770	100	%	$	44,657	100	%

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

The increase in NFE during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, was due primarily to increased earnings at Energy Services resulting from the commencement of AMAs as previously discussed.

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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)                                                                                                                                                             

Natural Gas Distribution Segment

Overview

Our Natural Gas Distribution segment is comprised of NJNG, a natural gas utility that provides regulated natural gas service throughout Burlington, Middlesex, Monmouth, Morris, Ocean, and Sussex counties in New Jersey to approximately 566,600 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, including those risks associated with COVID-19, which may include but are not limited to impacts to customer growth and customer usage, customer collections, the timing and costs of capital expenditures and construction of infrastructure projects, operating and financing costs, fluctuations in commodity prices and customer conservation efforts. In addition, NJNG may be subject to adverse economic conditions, certain regulatory actions, environmental remediation and severe weather conditions. It is often difficult to predict the impact of events or trends associated with these risks.

NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered to customers on an annual basis. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG generates 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 fiscal year.

As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 4. 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 utility gross margin, promoting clean energy programs and mitigating the risks discussed above.

Base Rate Case

On November 17, 2021, the BPU issued an order adopting a stipulation of settlement approving a $79.0 million increase to base rates, effective December 1, 2021. In addition, the order also included approval for the final increase for the NJ RISE/SAFE II programs, which totaled $269,000. These increases include an overall rate of return on rate base of 6.84 percent, return on common equity of 9.6 percent, a common equity ratio of 54.0 percent and a composite depreciation rate of 2.78 percent.

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 pipeline integrity management and infrastructure programs. Below is a summary of NJNG’s capital expenditures, including accruals, for the three months ended December 31, 2021, and estimates of expected investments for fiscal 2022 and 2023:

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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)                                                                                                                                                             

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.

Infrastructure Investment Program

In February 2019, NJNG filed a petition with the BPU seeking authority to implement a five-year IIP. The IIP consisted of two components: transmission and distribution investments and information technology replacement and enhancements. The total investment for the IIP was approximately $507.0 million. All approved investments will be recovered through annual filings to adjust base rates. In October 2020, the BPU approved the Company’s transmission and distribution component of the IIP for $150.0 million over five years, effective November 1, 2020. NJNG voluntarily withdrew the information technology upgrade component and will seek to recover associated costs in future rate case proceedings.

SAFE II and NJ RISE

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

The BPU approved the 5-year SAFE II program and the associated rate mechanism to replace the remaining unprotected steel mains and services from NJNG’s natural gas distribution system at an estimated cost of approximately $200 million, excluding AFUDC. With the approval of SAFE II, $157.5 million was approved for accelerated cost recovery methodology. The remaining $42.5 million in capital expenditures was requested for recovery in base rate cases, of which $23.4 million was approved in NJNG’s 2019 base rate case and $19.1 million was approved in the 2021 base rate case.

The BPU approved NJNG’s NJ RISE capital infrastructure program, which consists of six capital investment projects estimated to cost $102.5 million, excluding AFUDC, for natural 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 in the most storm-prone areas of NJNG’s service territory. Recovery of NJ RISE investments is included in NJNG’s base rates.

In March 2021, NJNG filed a petition with the BPU requesting the final base rate increase for the recovery associated with NJ RISE and SAFE II capital investments cost of approximately $3.4 million made through June 30, 2021. In June 2021, this filing was consolidated with the 2021 base rate case. On November 17, 2021, the BPU issued an order for the consolidated matter which included approval for the final increase for the NJ RISE and SAFE II programs of $269,000. With this approval, the filings with respect to NJ RISE and SAFE II are complete.

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:

	December 31, 2021	December 31, 2020
Firm customers
Residential	506,677	497,203
Commercial, industrial & other	31,756	30,912
Residential transport	19,338	22,296
Commercial transport	8,735	9,102
Total firm customers	566,506	559,513
Other	55	118
Total customers	566,561	559,631

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New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

During the three months ended December 31, 2021 and 2020, respectively, NJNG added 1,730 and 1,948 new customers. NJNG expects new customer additions, and those customers who added additional natural gas services to their premises to contribute approximately $1.4 million to utility gross margin during fiscal 2022.

NJNG continues to expect to add approximately 28,000 to 30,000 new customers during the three-year period of fiscal 2022 to 2024. Based on information from municipalities and developers, as well as external industry analysts and management's experience, NJNG estimates that approximately 65 percent of the growth will come from new construction markets and 35 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 $6.2 million annually, as calculated under NJNG's CIP tariff.

Energy Efficiency Programs

SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives 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. In March 2021, the BPU approved a three-year SAVEGREEN program consisting of approximately $126.1 million of direct investment, $109.4 million in financing options, and approximately $23.4 million in operation and maintenance expenses, which resulted in a $15.6 million annual recovery increase, effective July 1, 2021.

In May 2020, NJNG filed a petition with the BPU to decrease its EE recovery rate. In October 2020, the BPU approved NJNG to maintain its existing rate, which will result in an annual recovery of approximately $11.4 million, effective November 1, 2020.

In June 2021, NJNG submitted its annual cost recovery filing for the SAVEGREEN programs established from 2010 through 2018. On January 26, 2022, the BPU approved the stipulation, which increases annual recoveries by $2.2 million, effective February 1, 2022.

The following table summarizes, loans, grants, rebates and related investments as of:

(Thousands)	December 31, 2021		September 30, 2021
Loans	$	137,300	$	132,800
Grants, rebates and related investments	106,500		98,100
Total	$	243,800	$	230,900

Program recoveries from customers during the three months ended December 31, 2021 and 2020, were $6.8 million and $3.3 million, respectively. 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 9.6 percent to 10.3 percent.

Conservation Incentive Program/BGSS

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 natural gas supply cost savings achieved and is subject to a variable margin revenue test. Additionally, recovery of the CIP utility gross margin 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.

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New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Weather (1)	$	15,934	$	6,455
Usage	(1,073)		594
Total	$	14,861	$	7,049

(1)Compared with the 20-year average, weather was 17.8 percent warmer-than-normal and 10.0 percent warmer-than-normal during the three months ended December 31, 2021 and 2020, respectively.

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 natural gas costs in comparison to its BGSS 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.

NJNG’s residential and commercial markets are currently open to competition, and its rates are segregated between BGSS (i.e., natural gas commodity) and delivery (i.e., transportation) components. NJNG earns utility gross margin through the delivery of natural gas to its customers and, therefore, is not negatively affected by customers who use its transportation service and purchase natural gas from another supplier. Under an existing order from the BPU, BGSS can be provided by suppliers other than the state’s natural gas utilities; however, customers who purchase natural gas from another supplier continue to use NJNG for transportation service.

During fiscal 2021, NJNG notified the BPU of its intent to provide BGSS bill credits to residential and small commercial sales customers. The actual bill credits given to customers totaled $20.6 million, $19.3 million net of tax, of which $9.5 million was recognized during the three months ended December 31, 2020.

On May 28, 2021, NJNG submitted its annual petition to modify its BGSS, balancing charge and CIP rates. On November 17, 2021, the BPU approved a $2.9 million increase to the annual revenues credited to BGSS, a $13.0 million annual increase related to its balancing charge, as well as changes to CIP rates, which result in a $6.3 million annual recovery decrease, effective December 1, 2021.The balancing charge rate includes the cost of balancing natural gas deliveries with customer usage for sales and transportation customers and balancing charge revenues are credited to BGSS.

On November 19, 2021, NJNG submitted notification of its intent to self-implement an increase to its BGSS rate, which result in an approximately $24.2 million increase to annual revenues credited to BGSS, effective December 1, 2021.

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 NJNG’s 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. Utility gross margin from incentive programs was $3.8 million and $4.6 million during the three months ended December 31, 2021 and 2020, respectively.

40

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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 natural gas sales volumes hedged by each November 1 and at least 25 percent of the projected periodic BGSS natural 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.

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 energy sources. Natural gas commodity prices are shown in the graph below, which illustrates the daily natural gas prices(1) in the Northeast market region, also known as TETCO M-3.

(1) Data sourced from Standard & Poor's Financial Services, LLC Global Platts.

The maximum price per MMBtu was $6.94 and $5.52 and the minimum price was $2.42 and $0.28 for the three months ended December 31, 2021 and 2020, respectively. A more detailed discussion of the impacts of the price of natural gas on operating revenues, natural gas purchases and cash flows can be found in the Operating Results and Cash Flow sections of Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Societal Benefits Charge

NJNG’s qualifying customers are eligible for the USF program, which is administered by the New Jersey Department of Community Affairs, to help make energy bills more affordable.

In April 2021, the BPU approved on a final basis NJNG's annual SBC application to recover remediation expenses, including an increase in the RAC, of approximately $1.3 million annually and an increase to the NJCEP factor, of approximately $6.0 million, which was effective May 1, 2021.

In September 2021, the BPU approved on a final basis NJNG's annual USF compliance filing, which resulted in an annual increase of approximately $4.9 million, effective October 1, 2021.

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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 September 2021, NJNG filed its annual SBC application requesting recovery of remediation expenses, an increase in the RAC of approximately $2.0 million annually and an annual decrease to the NJCEP factor of $500,000. If approved, these changes are expected to be effective April 1, 2022.

Environmental Remediation

NJNG is responsible for the environmental remediation of former MGP sites, which contain contaminated residues from former gas manufacturing operations that ceased operating at these sites by the mid-1950s and, in some cases, had been discontinued many years earlier. Actual MGP remediation costs may vary from management’s estimates due to the developing nature of remediation requirements, regulatory decisions by the NJDEP and related litigation. NJNG reviews these costs at the end of each fiscal year and adjusts its liability and corresponding regulatory asset as necessary to reflect its expected future remediation obligation. Accordingly, NJNG recognized a regulatory asset and an obligation of $126.9 million as of December 31, 2021, a decrease of $8.1 million compared with the prior fiscal period.

In June 2019, NJNG initiated a preliminary assessment of a site in Aberdeen, New Jersey to determine prior ownership and if former MGP operations were active at the location. The preliminary assessment and site investigation activities are ongoing at the Aberdeen, NJ site location and based on initial findings will be moving to remedial investigation phase. The costs associated with preliminary assessment, site investigation and remedial investigation activities are considered immaterial and are included as a component of NJNG’s annual SBC application to recover remediation expenses. We will continue to gather information to further refine and enhance its estimate of potential costs for this site as it becomes available. See Note 13. Commitments and Contingent Liabilities for a more detailed description.

Other regulatory filings and a more detailed discussion of the filings in this section can be found in Note 4. Regulation in the accompanying Unaudited Condensed Consolidated Financial Statements.

Operating Results

NJNG's operating results are as follows:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues	$	274,772	$	195,729
Operating expenses
Natural gas purchases (1)(2)	124,594		59,309
Operation and maintenance	36,431		43,638
Regulatory rider expense (3)	16,671		10,701
Depreciation and amortization	22,893		19,169
Total operating expenses	200,589		132,817
Operating income	74,183		62,912
Other income, net	1,096		3,896
Interest expense, net of capitalized interest	10,995		8,974
Income tax provision	13,204		8,367
Net income	$	51,080	$	49,467

(1)Includes the purchased cost of the natural gas, fees paid to pipelines and storage facilities, adjustments as a result of BGSS incentive programs and hedging transactions. These expenses are passed through to customers and are offset by corresponding revenues.

(2)Includes related party transactions of approximately $2.3 million and $3.2 million for the three months ended December 31, 2021 and 2020, respectively, the majority of which is eliminated in consolidation.

(3)Consists of expenses associated with state-mandated programs, the RAC and energy efficiency programs, and are calculated on a per-therm basis. These expenses are passed through to customers and are offset by corresponding revenues.

Operating Revenues and Natural Gas Purchases

During the three months ended December 31, 2021, compared with the three months ended December 31, 2020, operating revenues increased by 40.4 percent and natural gas purchases increased 110.1 percent.

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OPERATIONS (Continued)                                                                                                                                                             

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

	Three Months Ended
	December 31,
	2021 v. 2020
(Thousands)	Operating revenues		Natural gas purchases
BGSS incentives	$	46,353	$	47,166
Average BGSS rates	14,142		14,142
Bill credits	9,519		9,519
Firm sales	(13,144)		(5,772)
Base rate impact	8,310		—
CIP adjustments	7,812		—
Other (1)	6,051		230
Total increase	$	79,043	$	65,285

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

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 revenues 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
	December 31,
(Thousands)	2021		2020
Operating revenues	$	274,772	$	195,729
Less:
Natural gas purchases	124,594		59,309
Regulatory rider expense	16,671		10,701
Utility gross margin	$	133,507	$	125,719

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.

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

OPERATIONS (Continued)                                                                                                                                                             

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

	Three Months Ended
	December 31,
	2021			2020
($ in thousands)	Margin		Bcf	Margin		Bcf
Utility gross margin/throughput
Residential	$	92,605	12.6	$	85,975	13.6
Commercial, industrial and other	19,102		2.3	17,040		2.4
Firm transportation	17,282		3.6	17,288		3.9
Total utility firm gross margin/throughput	128,989		18.5	120,303		19.9
BGSS incentive programs	3,764		25.1	4,578		25.9
Interruptible/off-tariff agreements	754		6.1	838		4.5
Total utility gross margin/throughput	$	133,507	49.7	$	125,719	50.3

Utility Firm Gross Margin

Utility firm gross margin increased $8.7 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to the increase in base rates as previously discussed.

BGSS Incentive Programs

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

	Three Months Ended
	December 31,
(Thousands)	2021 v. 2020
Storage		$	(1,504)
Off-system sales		1,180
Capacity release		(490)
Total decrease		$	(814)

The decrease in BGSS incentive programs during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, was due primarily to timing differences for storage incentive and lower capacity release volumes, partially offset by increased margins from off-system sales.

Operation and Maintenance Expense

O&M expense decreased $7.2 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to the deferral of bad debt costs through the July 2, 2020 BPU deferral order, partially offset by an increase in compensation and information technology expenditures.

Depreciation Expense

Depreciation expense increased $3.7 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, as a result of additional utility plant being placed into service.

Interest Expense

Interest expense increased $2.0 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased outstanding long-term debt.

Other Income

Other income decreased $2.8 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to decreased AFUDC equity related to infrastructure projects completed and placed in service at the end of fiscal 2021.

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Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Income Tax Provision

Income tax provision increased $4.8 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due to higher operating income and an increase in the annualized effective tax rate applied.

Net Income

Net income increased $1.6 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to higher revenue along with decreased O&M, partially offset by higher depreciation and interest expenses and decreased other income, as previously discussed.

Clean Energy Ventures Segment

Overview

Our Clean Energy Ventures segment actively pursues opportunities in the renewable energy markets. Clean Energy Ventures enters 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 enters into various long-term agreements, including PPAs, to supply energy from commercial solar projects.

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. Clean Energy Ventures is also subject to risks associated with COVID-19, which may include impacts to residential solar customer growth and customer collections, our ability to identify and develop commercial solar asset investments, impacts to our supply chain and our ability to source materials for construction.

The primary contributors toward the value of qualifying clean energy projects are tax incentives and RECs. Changes in the federal statutes related to the ITC and/or relevant state legislation and regulatory policies affecting the market for solar renewable energy credits, could significantly affect future results.

Solar

Solar projects placed in service and related expenditures are as follows:

	Three Months Ended
	December 31,
($ in Thousands)	2021				2020
Placed in service	Projects	MW	Costs		Projects	MW	Costs
Grid-connected (1)	1	1.0	$	3,120	1	2.9	$	3,683	(2)
Net-metered:
Residential	53	0.6	1,553		46	0.5	1,599
Total placed in service	54	1.6	$	4,673	47	3.4	$	5,282

(1)Includes projects subject to sale leaseback arrangements.

(2)Includes an operational 2.9 MW commercial solar project acquired in December 2020.

Since inception, Clean Energy Ventures has constructed a total of 369.3 MW of solar capacity. Projects that were placed in service through December 31, 2019, qualified for a 30-percent federal ITC. The credit declined to 26 percent for property under construction during 2020 and was originally scheduled to decline to 22 percent for property under construction during 2021 and 10 percent for any property that is under construction after 2021. On December 27, 2020, the 26 percent federal ITC was extended through the end of 2022. The credit declines to 22 percent after 2022 and to 10 percent after 2023.

Projects placed in service after December 31, 2019, also qualified for a 30 percent federal ITC if five percent or more of the total costs of a solar property are incurred before the end of the applicable year and there are continuous efforts to advance towards completion of the project, based on the IRS guidance around the ITC safe harbor determination. We have taken steps to preserve the ITC at the higher rate for certain solar projects that are completed after the scheduled reduction in rates, in accordance with IRS guidance.

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

OPERATIONS (Continued)                                                                                                                                                             

Clean Energy Ventures may enter into transactions to sell certain of its commercial solar assets concurrent with agreements to lease the assets back over a period of five to 15 years. The Company will continue to operate the solar assets and are responsible for related expenses and entitled to retain the revenue generated from RECs and energy sales. The ITCs and other tax benefits associated with these solar projects transfer to the buyer if applicable; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, for solar projects financed under sale leasebacks for which the assets were sold during the first 5 years of in-service life, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Unaudited Condensed Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. During the three months ended December 31, 2021 and 2020, Clean Energy Ventures received proceeds of $3.3 million and $12.1 million, respectively, in connection with the sale leaseback of commercial solar assets.

As part of its solar investment portfolio, Clean Energy Ventures operates a residential and small commercial solar program, The Sunlight Advantage®, that provides qualifying homeowners and small business owners the opportunity to have a solar system installed at their home or place of business with no installation or maintenance expenses. Clean Energy Ventures owns, operates and maintains the system over the life of the contract in exchange for monthly payments.

For solar installations placed in-service in New Jersey prior to April 30, 2020, 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.

In December 2019, the BPU established the TREC as pursuant to the successor program to the SREC program. TRECs provide a fixed compensation base multiplied by an assigned project factor in order to determine their value. The project factor is determined by the type and location of the project, as defined. All TRECs generated are required to be purchased monthly by a TREC program administrator as appointed by the BPU.

SREC and TREC activity consisted of the following:	Three Months Ended
	December 31,
	2021		2020
	SRECs	TRECs	SRECs	TRECs
Inventory balance as of October 1,	108,104	6,944	35,011	9,270
RECs generated	92,172	6,085	87,208	4,683
RECs delivered	(12,200)	(7,240)	(6,095)	(321)
Inventory balance as of September 30,	188,076	5,789	116,124	13,632

The average SREC sales price was $235 and $212 during the three months ended December 31, 2021 and 2020, respectively, and the average TREC price was $139 and $147 during the three months ended December 31, 2021 and 2020.

Clean Energy Ventures hedges its expected SREC production through the use of forward sales contracts. The following table reflects the hedged percentage of our projected inventory related to its in-service commercial and residential assets:

Energy Year (1)	Percent of SRECs Hedged
2022	99%
2023	99%
2024	95%
2025	44%
2026	21%

(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 or TRECs by our solar assets. All related costs are included as a component of O&M expenses on the Unaudited Condensed Consolidated Statements of Operations, including such expenses as facility maintenance and broker fees.

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

OPERATIONS (Continued)                                                                                                                                                             

Operating Results

Clean Energy Ventures’ financial results are summarized as follows:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues	$	10,183	$	6,370
Operating expenses
Operation and maintenance	8,922		9,201
Depreciation and amortization	5,233		5,433
Total operating expenses	14,155		14,634
Operating loss	(3,972)		(8,264)
Other income (expense), net	532		(62)
Interest expense, net	5,427		5,034
Income tax benefit	(2,046)		(3,086)
Net loss	$	(6,821)	$	(10,274)

Operating Revenues

Operating revenues increased $3.8 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased SREC and electricity sales.

Net Loss

Net loss decreased $3.5 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to the increased operating revenues, as previously discussed.

Energy Services Segment

Overview

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

Energy Services also provides management of transportation and storage assets for natural gas producers and regulated utilities. 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, Energy Services 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, Energy Services 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 anticipated transactional cash flows and to help manage volatility in natural gas market prices. Generally, when its transportation and storage contracts are exposed to periods of increased market volatility, Energy Services is able to implement strategies that allow it to capture margin by improving the respective time or geographic spreads on a forward basis.

Energy Services accounts for its physical commodity contracts and its financial derivative instruments at fair value on the Unaudited Condensed Consolidated Balance Sheets. Changes in the fair value of physical commodity contracts and financial derivative instruments are included in earnings as a component of operating revenues or natural gas purchases on the Unaudited

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

OPERATIONS (Continued)                                                                                                                                                             

Condensed Consolidated Statements of Operations. Volatility in reported net income at Energy Services 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. Volatility in earnings can also occur as a result of timing differences between the settlement of financial derivatives and the sale of the underlying physical commodity. For example, when a financial instrument settles and the physical natural gas is injected into inventory, 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 from storage and sold, at which time Energy Services realizes the entire margin on the transaction.

During December 2020, Energy Services entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts. The utility provides certain asset management services and Energy Services may deliver natural gas to the utility in exchange for aggregate net proceeds of approximately $500 million, payable through November 1, 2030. The AMAs include a series of initial and permanent releases, which commenced on November 1, 2021. NJR will receive approximately $260 million in cash from fiscal 2022 through fiscal 2024 and $34 million per year from fiscal 2025 through fiscal 2031 under the agreements. During the three months ended December 31, 2021, Energy Services recognized $22.1 million of operating revenue on the Unaudited Condensed Consolidated Statements of Operations. Amounts received in excess of revenue totaling $64.7 million are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets.

Operating Results

Energy Services’ financial results are summarized as follows:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues (1)	$	369,244	$	229,477
Operating expenses
Natural gas purchases (including demand charges (2)(3))	278,687		173,837
Operation and maintenance	3,751		4,016
Depreciation and amortization	28		42
Total operating expenses	282,466		177,895
Operating income	86,778		51,582
Other income, net	146		92
Interest expense, net	675		680
Income tax provision	20,505		12,122
Net income	$	65,744	$	38,872

(1)Includes related party transactions of approximately $3.5 million and $2.1 million for the three months ended December 31, 2021 and 2020, respectively, which are eliminated in consolidation.

(2)Costs associated with pipeline and storage capacity 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 $225,000 and $166,000 for the three months ended December 31, 2021 and 2020, respectively, a portion of which is eliminated in consolidation.

Energy Services' portfolio of financial derivative instruments are composed of:

	Three Months Ended
	December 31,
(in Bcf)	2021	2020
Net short futures contracts	22.2	26.5

During the three months ended December 31, 2021 and 2020, the net short position resulted in an unrealized gain of $22.8 million and $17.0 million, respectively.

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

OPERATIONS (Continued)                                                                                                                                                             

Operating Revenues and Natural Gas Purchases

Operating revenues increased $139.8 million and natural gas purchases increased $104.9 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020. The increase in operating revenues and gas purchases are due primarily to a 118.8 percent increase in natural gas prices. To a lesser extent, operating revenues also increased due to AMAs that commenced in November 2021, as previously discussed.

Future results at Energy Services 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 warmer temperatures, and reduced volatility can negatively impact Energy Services' earnings. See Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution Segment for TETCO M-3 Daily Prices, which illustrates the daily natural gas prices in the Northeast market region.

Income Tax Provision

Income tax provision increased $8.4 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased operating income related to higher operating revenue, as discussed above.

Net Income

Net income increased $26.9 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased operating income, partially offset by increased income taxes, as previously discussed.

Non-GAAP Financial Measures

Management uses financial margin and NFE, non-GAAP financial measures, when evaluating the operating results of Energy Services. Financial margin and NFE are based on removing timing differences associated with certain derivative instruments. GAAP also 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 Energy Services, as the adjustment primarily relates to timing differences associated with certain derivative instruments which impacts the estimate of the annual effective tax rate for NFE. No adjustment is needed during the fourth quarter, since the actual effective tax rate is calculated at year end.

Management views these measures as representative of the overall expected economic result and uses these measures to compare Energy Services' 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, Energy Services' 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 Energy Services 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 natural gas flows.

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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)                                                                                                                                                             

Financial Margin

The following table is a computation of Energy Services' financial margin:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues (1)	$	369,244	$	229,477
Less: Natural gas purchases	278,687		173,837
Add:
Unrealized (gain) on derivative instruments and related transactions	(85,647)		(38,781)
Effects of economic hedging related to natural gas inventory (2)	23,577		(7,532)
Financial margin	$	28,487	$	9,327

(1)Includes unrealized losses related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $3.5 million and $1.3 million for the three months ended December 31, 2021 and 2020, respectively.

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

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating income	$	86,778	$	51,582
Add:
Operation and maintenance	3,751		4,016
Depreciation and amortization	28		42
Subtotal	90,557		55,640
Add:
Unrealized (gain) on derivative instruments and related transactions	(85,647)		(38,781)
Effects of economic hedging related to natural gas inventory	23,577		(7,532)
Financial margin	$	28,487	$	9,327

Financial margin increased $19.2 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, resulting primarily from AMAs, which commenced November 2021, as previously discussed.

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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)                                                                                                                                                             

Net Financial Earnings

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Net income	$	65,744	$	38,872
Add:
Unrealized (gain) on derivative instruments and related transactions	(85,647)		(38,781)
Tax effect (1)	20,357		9,219
Effects of economic hedging related to natural gas inventory	23,577		(7,532)
Tax effect	(5,603)		1,790
Net income to NFE tax adjustment	(861)		(2,068)
Net financial earnings	$	17,567	$	1,500

(1)Includes taxes related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $(821,000) and $(306,000) for the three months ended December 31, 2021 and 2020, respectively.

NFE increased $16.1 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to higher financial margin, as previously discussed.

Future results are subject to Energy Services' 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.

Storage and Transportation Segment

Overview

Our Storage and Transportation segment invests in natural gas assets, such as natural gas transportation and storage facilities. We believe that acquiring, owning and developing these storage and transportation assets, which operate under a tariff structure that has either cost- or market-based rates, can provide us a growth opportunity. Our Storage and Transportation segment is subject to various risks, including the construction, development and operation of our transportation and storage assets, obtaining necessary governmental, environmental and regulatory approvals, our ability to obtain necessary property rights and our ability to obtain financing at reasonable costs for the construction, operation and maintenance of our assets. In addition, our storage and transportation assets may be subject to risk associated with the COVID-19 pandemic, such as disruption to the supply chain and availability of critical equipment and supplies, disruptions to the availability of our specialized workforce and contractors and changes to demand for natural gas, transportation and other downstream activities.

Our Storage and Transportation segment is comprised of Leaf River, a 32.2 million Dth salt dome natural gas storage facility that operates under market-based rates and Adelphia Gateway, an existing 84-mile pipeline in southeastern Pennsylvania. Adelphia Gateway operates under cost of service rates but can enter into negotiated rates with counterparties. The northern portion of the pipeline was operational upon acquisition and it currently serves two natural gas generation facilities. On October 5, 2020, we began the conversion of the southern zone of the pipeline to natural gas.

Our Storage and Transportation segment also has a 50 percent ownership interest in Steckman Ridge, a storage facility that operates under market-based rates and a 20 percent interest in PennEast, a partnership whose purpose was to construct and operate a 120-mile natural gas pipeline that would have extended from northeast Pennsylvania to western New Jersey.

PennEast received a Certificate of Public Convenience and Necessity for the project from FERC in January 2018. However, because of numerous regulatory and legal challenges, we evaluated our equity investment in PennEast for impairment during fiscal 2021, and determined that it was other-than-temporarily impaired. We estimated the fair value of our investment in

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

OPERATIONS (Continued)                                                                                                                                                             

PennEast using probability weighted scenarios assigned to discounted future cash flows. The impairment is the result of management's estimates and assumptions regarding the likelihood of certain outcomes related to required regulatory approvals and pending legal matters, the timing and magnitude of construction costs and in-service dates, the evaluation of the current environmental and political climate as it relates to interstate pipeline development, and transportation capacity revenues and discount rates.

During the third quarter of fiscal 2021, the PennEast partnership determined that this project is no longer supported, and all further development has ceased. The Company recognized an other-than-temporary impairment charge of $92.0 million, or approximately $74.5 million, net of income taxes, which represents the best estimate of the salvage value of the remaining assets of the project. Other-than-temporary impairments are recorded in equity in (losses) earnings from affiliates in the Unaudited Condensed Consolidated Statements of Operations.

On December 16, 2021, the FERC dismissed PennEast’s pending applications. The order vacates the certificate authorization for the PennEast pipeline project in light of PennEast’s response to FERC staff’s November 23, 2021 request for a status update, in which PennEast informed the Commission it is no longer developing the project. The order vacates the certificate authorization, subject to leave of the U.S. Court of Appeals for the D.C. Circuit where the Commission’s certificate and rehearing orders are under review.

As of December 31, 2021, our investments in Steckman Ridge and PennEast were $108.8 million and $5.5 million, respectively.

Operating Results

The financial results of our Storage and Transportation segment are summarized as follows:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues (1)	$	12,143	$	13,104
Operating expenses
Natural gas purchases	704		233
Operation and maintenance	7,430		6,542
Depreciation and amortization	2,133		2,640
Total operating expenses	10,267		9,415
Operating income	1,876		3,689
Other income, net	2,509		1,254
Interest expense, net	2,136		3,982
Income tax provision	343		646
Equity in earnings of affiliates	1,056		3,193
Net income	$	2,962	$	3,508

(1)Includes related party transactions of approximately $559,000 and $657,000 for the three months ended December 31, 2021 and 2020, respectively, which are eliminated in consolidation.

Operating Revenues

Operating revenues decreased $1.0 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to a decrease in hub services revenue at Leaf River.

Equity in earnings of affiliates decreased $2.1 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to decreased AFUDC equity related to our investment in PennEast, which has ceased all further development.

Operation and Maintenance Expense

O&M increased $888,000 during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased contractor expense and insurance costs.

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Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Interest Expense

Interest expense decreased $1.8 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to reduced debt related to the PennEast project.

Net Income

Net income decreased $546,000 during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to lower equity in earnings of affiliates partially offset by decreased interest expense as previously discussed.

Home Services and Other Operations

Overview

The financial results of Home Services and Other consist primarily of the operating results of NJRHS. NJRHS provides service, sales and installation of appliances to service contract customers and has been focused on growing its installation business and expanding its service contract customer base. Home Services and Other also includes organizational expenses incurred at NJR and home warranty contract income at NJR Retail.

Operating Results

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues	$	13,951	$	12,577
Operation and maintenance	$	12,885	$	10,321
Other income (expense), net	$	75	$	(824)
Interest expense, net	$	244	$	1,116
Net income (loss)	$	447	$	(62)

Operating Revenues

Operating revenues increased $1.4 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased installation revenue at NJRHS.

Operation and Maintenance Expense

O&M increased $2.6 million during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased compensation and contractor expenses.

Net Income (Loss)

Net income increased $509,000 during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, due primarily to increased revenue and other income along with decreased interest expense, partially offset by increased O&M, as previously discussed.

Liquidity and Capital Resources

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

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

OPERATIONS (Continued)                                                                                                                                                             

Our consolidated capital structure was as follows:

	December 31, 2021		September 30, 2021
Common stock equity	38	%	38	%
Long-term debt	50		51
Short-term debt	12		11
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. NJR raised approximately $3.8 million of equity through the DRP by issuing approximately 105,000 shares of common stock during the three months ended December 31, 2021, and raised $3.9 million during the three months ended December 31, 2020, by issuing approximately 140,000 shares of treasury stock. There were no shares of common stock issued through the waiver discount feature of the DRP during the three months ended December 31, 2021 and 2020.

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 December 31, 2021, we had repurchased a total of approximately 17.8 million of those shares and may repurchase an additional 1.7 million shares under the approved program. There were no shares repurchased during the three months ended December 31, 2021 and 2020.

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, as borrowers, respectively, 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 flows from operations will be sufficient to satisfy our working capital, capital expenditures and dividend requirements for at least the next 12 months. NJR, NJNG, Clean Energy Ventures, Storage and Transportation and Energy Services 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 and meter or solar asset sale leasebacks.

We believe that as of December 31, 2021, NJR and NJNG were, and currently are, in compliance with all existing debt covenants, both financial and non-financial.

As a result of the COVID-19 pandemic there have been disruptions, uncertainty and volatility in the credit and capital markets. We have been able to obtain sufficient financing to meet its funding requirements for operations and capital expenditures, however, our ability to access funds from financial institutions at a reasonable cost may impact the nature and timing of future capital market transactions.

Short-Term Debt

We use our short-term borrowings primarily to finance Energy Services' short-term liquidity needs, Storage and Transportation investments, share repurchases and, on an initial basis, Clean Energy Ventures' investments. Energy Services' use of high-volume storage facilities and anticipated pipeline park-and-loan arrangements, combined with related economic hedging activities in the volatile wholesale natural gas market, create significant short-term cash requirements.

As of December 31, 2021, NJR had a revolving credit facility totaling $500 million, with $169.9 million available under the facility.

NJNG satisfies its debt needs by issuing short-term 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.

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Part I

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

OPERATIONS (Continued)                                                                                                                                                             

NJNG’s commercial paper is sold through several commercial banks under an issuing and paying agency agreement and is supported by the $250 million NJNG Credit Facility. As of December 31, 2021, 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 $71.9 million.

Short-term borrowings were as follows:

	Three Months Ended
(Thousands)	December 31, 2021
NJR
Notes Payable to banks:
Balance at end of period		$	310,550
Weighted average interest rate at end of period		1.13		%
Average balance for the period		$	257,651
Weighted average interest rate for average balance		1.26		%
Month end maximum for the period		$	337,800
NJNG
Commercial Paper and Notes Payable to banks:
Balance at end of period		$	177,400
Weighted average interest rate at end of period		0.55		%
Average balance for the period		$	7,531
Weighted average interest rate for average balance		0.32		%
Month end maximum for the period		$	177,700

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 the November through January time frame.

NJR

Based on its average borrowings during the three months ended December 31, 2021, NJR's average interest rate was 1.26 percent, resulting in interest expense of approximately $818,000.

During fiscal 2021, NJR entered into a Second Amended and Restated Credit Agreement governing a $500 million NJR Credit Facility. The NJR Credit Facility expires on September 2, 2026, subject to two mutual options for a one-year extension beyond that date. The NJR Credit Facility permits the borrowing of revolving loans and swingline loans, as well as a $75 million sublimit for the issuance of letters of credit. The NJR Credit Facility also includes an accordion feature, which would allow NJR, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit Facility in increments of $50 million up to a maximum of $250 million. Certain of NJR’s unregulated subsidiaries have guaranteed all of NJR’s obligations under the NJR Credit Facility. The credit facility is used primarily to finance its share repurchases, to satisfy Energy Services’ short-term liquidity needs and to finance, on an initial basis, unregulated investments.

As of December 31, 2021, NJR had eight letters of credit outstanding totaling $19.6 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

As noted above, based on its average borrowings during the three months ended December 31, 2021, NJNG's average interest rate was 0.32 percent, resulting in interest expense of approximately $132,000.

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Part I

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

OPERATIONS (Continued)                                                                                                                                                             

During fiscal 2021, NJNG entered into a Second Amended and Restated Credit Agreement governing a $250 million, NJNG Credit Facility. The NJNG Credit Facility expires on September 2, 2026, subject to two mutual options for a one-year extension beyond that date. The NJNG Credit Facility permits the borrowing of revolving loans and swingline loans, as well as a $30 million sublimit for the issuance of letters of credit. The NJNG Credit Facility also includes an accordion feature, which would allow NJNG, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJNG Credit Facility in minimum increments of $50 million up to a maximum of $100 million.

As of December 31, 2021, 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.

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 .70 to 1.00 for NJR and .65 to 1.00 for NJNG. 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 December 31, 2021, NJR had the following outstanding:

•$50 million of 3.25 percent senior notes due September 17, 2022;

•$50 million of 3.20 percent senior notes due August 18, 2023;

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

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

•$100 million of 3.96 percent senior notes due June 8, 2028;

•$150 million of 3.29 percent senior notes due July 17, 2029;

•$130 million of 3.50 percent senior notes due July 23, 2030;

•$120 million of 3.13 percent senior notes due September 1, 2031;

•$130 million of 3.60 percent senior notes due July 23, 2032; and

•$80 million of 3.25 percent senior notes due September 1, 2033.

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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)                                                                                                                                                             

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

NJNG

As of December 31, 2021, NJNG's long-term debt consisted of $1.2 billion in fixed-rate debt issuances secured by the Mortgage Indenture, with maturities ranging from 2024 to 2061, and $28.7 million in finance leases with various maturities ranging from 2021 to 2028.

On October 28, 2021, NJNG entered into a Note Purchase Agreement for $100 million of its senior notes, of which $50 million were issued at an interest rate of 2.97 percent, maturing in 2051, and $50 million were issued at an interest rate of 3.07 percent, maturing in 2061. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

NJR is not obligated directly or contingently with respect to the NJNG’s fixed-rate debt issuances.

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 70 percent for NJR and 65 percent for NJNG 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.

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 of 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.

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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)                                                                                                                                                             

Sale Leaseback

NJNG

NJNG received $17.3 million in the three months ended December 31, 2021, in connection with the sale leaseback of its natural gas meters. NJNG records a financing 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 continues to evaluate this sale leaseback program based on current market conditions. Natural gas meters are excepted from the lien on NJNG property under the Mortgage Indenture. There were no natural gas meter sale leasebacks recorded during the three months ended December 31, 2020.

Clean Energy Ventures

Clean Energy Ventures enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over a period of five to 15 years. These transactions are considered failed sale leasebacks for accounting purposes and are therefore treated as financing obligations, which are typically secured by the renewable energy facility asset and its future cash flows from RECs and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if applicable; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Clean Energy Ventures continues to operate the solar assets, including related expenses, and retain the revenue generated from RECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. During the three months ended December 31, 2021 and 2020, Clean Energy Ventures received proceeds of $3.3 million and $12.1 million, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets.

Contractual Obligations

As of December 31, 2021, there were NJR guarantees covering approximately $213.4 million of natural gas purchases and Energy Services demand fee commitments and ten outstanding letters of credit totaling $20.3 million, as previously mentioned, not yet reflected in accounts payable on the Unaudited Condensed Consolidated Balance Sheets.

NJNG's total capital expenditures are projected to be between $330 million and $370 million during fiscal 2022. Total capital expenditures spent or accrued during the three months ended December 31, 2021, were $59.7 million. NJNG expects to fund its obligations with a combination of cash flows 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 December 31, 2021, NJNG's future MGP expenditures are estimated to be $126.9 million. For a more detailed description of MGP expenditures see Note 13. 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.

During the three months ended December 31, 2021, our Storage and Transportation segment had capital expenditures spent or accrued for the Adelphia Gateway project totaling $53.7 million and capital expenditures spent or accrued for Leaf River totaling $6.7 million. During fiscal 2022, we expect expenditures related to the Adelphia Gateway project to be between $90 million and $110 million and expenditures related to Leaf River to be between $6 million and $10 million.

During the three months ended December 31, 2021, total capital expenditures spent or accrued related to the purchase and installation of solar equipment were $32.1 million. Clean Energy Ventures' expenditures include clean energy projects that support our goal to promote renewable energy. Accordingly, Clean Energy Ventures enters into agreements to install solar equipment involving both residential and commercial projects. We estimate solar-related capital expenditures for projects during fiscal 2022 to be between $235 million and $301 million.

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 sourcing projects that meet our investment criteria, 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 or unforeseen events and the ability to access capital or allocation of capital to other investments or business opportunities.

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

OPERATIONS (Continued)                                                                                                                                                             

Energy Services does not currently anticipate any significant capital expenditures during fiscal 2022 and 2023.

During December 2020, Energy Services entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts. The utility provides certain asset management services and Energy Services may deliver natural gas to the utility in exchange for aggregate net proceeds of approximately $500 million, payable through November 1, 2030. The AMAs include a series of initial and permanent releases, which commenced on November 1, 2021. NJR will receive approximately $260 million in cash from fiscal 2022 through fiscal 2024 and $34 million per year from fiscal 2025 through fiscal 2031 under the agreements. During the three months ended December 31, 2021, Energy Services recognized $22.1 million of operating revenue on the Unaudited Condensed Consolidated Statements of Operations. Amounts received in excess of revenue totaling $64.7 million are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets.

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, 2021.

Cash Flows

Operating Activities

Cash flows (used in) operating activities during the three months ended December 31, 2021, totaled $(37.4) million, compared with cash flows from operating activities totaling $31.7 million during the three months ended December 31, 2020. 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 natural 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 decrease of $69.1 million in operating cash flows during the three months ended December 31, 2021, compared with the three months ended December 31, 2020, was due primarily to increases in working capital requirements related to higher accounts receivable and increases in natural gas in storage, partially offset by increased deferred revenue.

Investing Activities

Cash flows (used in) investing activities totaled $(164.1) million during the three months ended December 31, 2021, compared with $(108.8) million during the three months ended December 31, 2020. The increase of $55.3 million was due primarily to an increase in capital expenditures of $57.2 million for Storage and Transportation related to the conversion of the southern portion of Adelphia's pipeline to natural gas.

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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)                                                                                                                                                             

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 natural gas management and marketing activities at Energy Services and clean energy investments at Clean Energy Ventures.

Cash flows from financing activities totaled $198.0 million during the three months ended December 31, 2021, compared with cash flows (used in) financing activities of $(17.6) million during the three months ended December 31, 2020. The increase of $215.6 million is due primarily to the $100 million issuance of long-term debt at NJNG, increased short-term debt activity at NJR and NJNG, along with proceeds of $17.3 million for meter sale leasebacks at NJNG, partially offset by lower proceeds from solar sale leasebacks at Clean Energy Ventures.

Credit Ratings

The table below summarizes NJNG's credit ratings as of December 31, 2021, issued by two rating entities, Moody's and Fitch:

	Moody's	Fitch
Corporate Rating	N/A	A-
Commercial Paper	P-2	F-2
Senior Secured	A1	A+
Ratings Outlook	Stable	Stable

The Fitch ratings and outlook were reaffirmed on March 15, 2021. The Moody's ratings and outlook were reaffirmed on May 11, 2021. NJNG's Moody's and Fitch 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 unregulated 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

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

costs is governed by the BPU. Energy Services 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, 2021			(Decrease) in Fair Market Value		Amounts Settled		December 31, 2021
Natural Gas Distribution		$	2,033		2,759		—		$	4,792
Energy Services		(29,487)			23,387		(28,898)		22,798
Total		$	(27,454)		26,146		(28,898)		$	27,590

There were no changes in methods of valuations during the three months ended December 31, 2021.

The following is a summary of fair market value of financial derivatives as of December 31, 2021, excluding foreign exchange contracts discussed below, by method of valuation and by maturity for each fiscal year period:

(Thousands)	2022		2023	2023 - 2025		After 2025		Total Fair Value
Price based on NYMEX/CME	$	(135)	(37)		—		—		$	(172)
Price based on ICE	25,340		1,222		1,200		—		27,762
Total	$	25,205	1,185		1,200		—		$	27,590

The following is a summary of financial derivatives by type as of December 31, 2021:

		Volume Bcf	Price per MMBtu(1)	Amounts included in Derivatives (Thousands)
Natural Gas Distribution	Futures	24.0	$0.00 - $9.77		$	4,792
Energy Services	Futures	(22.0)	$2.41 - $8.62		22,969
	Swaps	(0.2)	$2.72 - $3.08		(171)
Total					$	27,590

(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, 2021			(Decrease) in Fair Market Value		Amounts Settled		December 31, 2021
Natural Gas Distribution - Prices based on other external data		$	20		231		21		$	230
Energy Services - Prices based on other external data		(34,678)			1,660		(1,585)		(31,433)
Total		$	(34,658)		1,891		(1,564)		$	(31,203)

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

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 $8.0 million. This analysis does not include potential changes to reported credit adjustments embedded in the $27.3 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	$	—	$	(3,980)	$	(7,960)	$	(11,939)	$	(15,919)
Ending derivative fair value	$	27,291	$	23,311	$	19,331	$	15,352	$	11,372
Percent decrease in NYMEX natural gas futures prices	0%		(5)%		(10)%		(15)%		(20)%
Estimated change in derivative fair value	$	—	$	3,980	$	7,960	$	11,939	$	15,919
Ending derivative fair value	$	27,291	$	31,271	$	35,251	$	39,230	$	43,210

Wholesale Credit Risk

The following is a summary of gross and net credit exposures, grouped by investment and non-investment grade counterparties, as of December 31, 2021. Gross credit exposure for Energy Services 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. Gross credit exposure for Storage and Transportation is defined as demand and estimated usage fees for contracted services and/or market value of loan balances 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.

Energy Services', Clean Energy Ventures' and Storage and Transportation's counterparty credit exposure as of December 31, 2021, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	156,349		$	136,579
Noninvestment grade		9,441			259
Internally rated investment grade		23,244			18,672
Internally rated noninvestment grade		27,713			12,980
Total		$	216,747		$	168,490

NJNG's counterparty credit exposure as of December 31, 2021, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	29,479		$	28,302
Noninvestment grade		1,575			—
Internally rated investment grade		498			14
Internally rated noninvestment grade		2,303			109
Total		$	33,855		$	28,425

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.

62

New Jersey Resources Corporation

Part I

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

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.

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 Operations of our Annual Report on Form 10-K for the period ended September 30, 2021.

Effects of Inflation

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

ITEM 4. CONTROLS AND PROCEDURES                                                                                                                             

Disclosure Controls and Procedures

Under the supervision and with the participation of 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 SEC'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 December 31, 2021, that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

63

New Jersey Resources Corporation

Part II

ITEM 1. LEGAL PROCEEDINGS                                                                                                                                                

Information regarding reportable legal proceedings is contained in Part I, Item 3. Legal Proceedings in our Annual Report on Form 10-K for the year ended September 30, 2021, and is set forth in Part I, Item 1, Note 13. Commitments and Contingent Liabilities-Legal Proceedings on the Unaudited Condensed Consolidated Financial Statements, which is incorporated by reference. No legal proceedings became reportable during the quarter ended December 31, 2021, 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 2021 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 2021 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 December 31, 2021:

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
10/01/21 -10/31/21	—	—		—	1,685,053
11/01/21 - 11/30/21	—	—		—	1,685,053
12/01/21 - 12/31/21	—	—		—	1,685,053
Total	—	$	—	—	1,685,053

The stock repurchase plan, which was authorized by our Board of Directors, became effective in September 1996 and as of December 31, 2021, included 19.5 million shares of common stock for repurchase, of which, approximately 1.7 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.

64

New Jersey Resources Corporation

Part II

ITEM 6. EXHIBITS                                                                                                                                                                         

Exhibit
Number Exhibit Description

4.1	$100,000,000 Note Purchase Agreement, dated as of October 28, 2021, by and among New Jersey Natural Gas Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K, as filed on November 3, 2021)
4.2	Tenth Supplemental Indenture, dated as of October 1, 2021, by and between New Jersey Natural Gas Company and U.S. Bank National Association, as Trustee (incorporated by reference to Exhibit 4.2 to the Current Report on Form 8-K, as filed on November 3, 2021)
4.3	Third Amendment to the Shelf Note Purchase Agreement dated as of June 30, 2011, dated as of November 1, 2021 among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto (incorporated by reference to Exhibit 4.3 to the Current Report on Form 8-K, as filed on November 3, 2021)
4.4	First Amendment to the Note Purchase Agreement dated as of March 22, 2016, dated as of November 1, 2021 among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto (incorporated by reference to Exhibit 4.4 to the Current Report on Form 8-K, as filed on November 3, 2021)
4.5	First Amendment to the Note Purchase Agreement dated as of June 8, 2018, dated as of November 1, 2021 among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto (incorporated by reference to Exhibit 4.5 to the Current Report on Form 8-K, as filed on November 3, 2021)
4.6	First Amendment to the Note Purchase Agreement dated as of July 17, 2019, dated as of November 1, 2021 among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto (incorporated by reference to Exhibit 4.6 to the Current Report on Form 8-K, as filed on November 3, 2021)
4.7	First Amendment to the Note Purchase Agreement dated as of May 14, 2020, dated as of November 1, 2021 among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto (incorporated by reference to Exhibit 4.7 to the Current Report on Form 8-K, as filed on November 3, 2021)
4.8	First Amendment to the Note Purchase Agreement dated as of September 1, 2020, dated as of November 1, 2021 among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto (incorporated by reference to Exhibit 4.8 to the Current Report on Form 8-K, as filed on November 3, 2021)
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 December 31, 2021, furnished in iXBRL (Inline eXtensible Business Reporting Language))
104+	Cover Page Interactive Data File included in Exhibit 101

________________________________

+    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 Exchange Act.

65

New Jersey Resources Corporation

Part II

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		NEW JERSEY RESOURCES CORPORATION
		(Registrant)
Date:	February 3, 2022
		By:/s/ Roberto F. Bel
		Roberto F. Bel
		Senior Vice President and
		Chief Financial Officer

66

EX-31.1

EXHIBIT 31.1

CERTIFICATION OF THE PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

 I, Stephen D. Westhoven, 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 the registrant's board of directors (or persons performing the equivalent functions):

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

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

Date:	February 3, 2022	By:	/s/ Stephen D. Westhoven
			Stephen D. Westhoven
			President and 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, Roberto F. Bel, 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 the registrant's board of directors (or persons performing the equivalent functions):

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

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

Date:	February 3, 2022	By:	/s/ Roberto F. Bel
			Roberto F. Bel
			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, Stephen D. Westhoven 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 December 31, 2021, 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:	February 3, 2022	By:	/s/ Stephen D. Westhoven
			Stephen D. Westhoven
			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, Roberto F. Bel 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 December 31, 2021, 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:	February 3, 2022	By:	/s/ Roberto F. Bel
			Roberto F. Bel
			Senior Vice President and Chief Financial Officer

XML

Cover Page - shares	3 Months Ended
	Dec. 31, 2021	Jan. 31, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	001-08359
Entity Registrant Name	NEW JERSEY RESOURCES CORPORATION
Entity Incorporation, State or Country Code	NJ
Entity Tax Identification Number	22-2376465
Entity Address, Address Line One	1415 Wyckoff Road
Entity Address, City or Town	Wall
Entity Address, State or Province	NJ
Entity Address, Postal Zip Code	07719
City Area Code	(732)
Local Phone Number	938‑1480
Title of 12(b) Security	Common Stock - $2.50 Par Value
Trading Symbol	NJR
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Business	false
Entity Common Stock, Shares Outstanding		96,061,402
Entity Central Index Key	0000356309
Current Fiscal Year End Date	--09-30
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Amendment Flag	false

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
OPERATING REVENUES
Utility	$ 274,435	$ 195,729
Nonutility	401,407	258,576
Total operating revenues	675,842	454,305
Natural gas purchases:
Gas purchases - Related parties	1,846	1,734
Operation and maintenance	68,984	73,636
Regulatory rider expenses	16,671	10,701
Depreciation and amortization	30,393	27,362
Total operating expenses	518,957	342,825
OPERATING INCOME	156,885	111,480
Other income, net	4,136	4,117
Interest expense, net of capitalized interest	19,477	19,786
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	141,544	95,811
Income tax provision	30,807	17,441
Equity in earnings of affiliates	575	2,675
NET INCOME	$ 111,312	$ 81,045
EARNINGS PER COMMON SHARE
Basic (usd per share)	$ 1.16	$ 0.84
Diluted (usd per share)	$ 1.16	$ 0.84
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic (in shares)	95,944	96,114
Diluted (in shares)	96,356	96,415
Regulated
Natural gas purchases:
Gas purchases - Utility and Nonutility	$ 122,269	$ 56,145
Unregulated
Natural gas purchases:
Gas purchases - Utility and Nonutility	$ 278,794	$ 173,247

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Net income	$ 111,312	$ 81,045
Other comprehensive income, net of tax
Reclassifications of losses to net income on derivatives designated as hedging instruments, net of tax of $(79) and $(112), respectively	264	231
Adjustment to postemployment benefit obligation, net of tax of $(233) and $(245), respectively	766	812
Other comprehensive income	1,030	1,043
Comprehensive income	$ 112,342	$ 82,088

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Tax on reclassifications of losses to net income on derivatives	$ (79)	$ (112)
Tax on adjustment to postemployment benefit obligation	$ (233)	$ (245)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
CASH FLOWS (USED IN) FROM OPERATING ACTIVITIES
Net income	$ 111,312	$ 81,045
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) on derivative instruments	(82,191)	(37,491)
Depreciation and amortization	30,393	27,362
Amortization of acquired wholesale energy contracts	589	716
Allowance for equity used during construction	(2,494)	(4,931)
Allowance for doubtful accounts	550	3,970
Non cash lease expense	889	1,324
Deferred income taxes	14,855	17,667
Equivalent value of ITCs recognized on equipment financing	(727)	0
Manufactured gas plant remediation costs	(12,368)	(1,274)
Equity in earnings, net of distributions received from equity investees and impairments	481	(1,189)
Cost of removal - asset retirement obligations	(282)	(256)
Contributions to postemployment benefit plans	(1,942)	(1,670)
Taxes related to stock-based compensation	(166)	76
Changes in:
Components of working capital	(153,195)	(74,434)
Other noncurrent assets	(1,529)	11,806
Other noncurrent liabilities	58,418	9,002
Cash flows (used in) from operating activities	(37,407)	31,723
Expenditures for:
Cost of removal	(9,114)	(14,765)
Distribution from equity investees in excess of equity in earnings	244	1,413
Investments in equity investees	0	(286)
Cash flows (used in) investing activities	(164,054)	(108,753)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Proceeds from long-term debt	100,000	0
Payments of long-term debt	(1,810)	(5,203)
Proceeds from short-term debt, net	110,650	9,000
Proceeds from sale leaseback transaction - solar	3,300	12,124
Proceeds from sale leaseback transaction	17,300	0
Payments of common stock dividends	(31,841)	(31,902)
Proceeds from issuance of common stock - DRP	3,805	3,911
Tax withholding payments related to net settled stock compensation	(3,433)	(5,534)
Cash flows from (used in) financing activities	197,971	(17,604)
Change in cash, cash equivalents and restricted cash	(3,490)	(94,634)
Cash, cash equivalents and restricted cash at beginning of period	6,043	119,423
Cash, cash equivalents and restricted cash at end of period	2,553	24,789
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	(117,010)	(108,143)
Inventories	(48,866)	5,792
Recovery of natural gas costs	(4,505)	(10,542)
Natural gas purchases payable	(18,752)	24,146
Natural gas purchases payable - related parties	(10)	74
Deferred revenue	51,107	(819)
Accounts payable and other	(44,374)	(38,413)
Prepaid expenses	(6,951)	(5,045)
Prepaid and accrued taxes	31,205	10,568
Restricted broker margin accounts	(459)	38,986
Customers' credit balances and deposits	6,080	7,014
Other current assets	(660)	1,948
Total	(153,195)	(74,434)
Cash paid (received) for:
Interest (net of amounts capitalized)	13,935	11,298
Income taxes	(229)	230
Accrued capital expenditures	57,129	4,205
Utility plant
Expenditures for:
Payments to acquire PP&E	(64,350)	(64,481)
Solar equipment
Expenditures for:
Payments to acquire PP&E	(25,380)	(22,335)
Storage and Transportation and other
Expenditures for:
Payments to acquire PP&E	$ (65,454)	$ (8,299)

XML

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 3,397,776	$ 3,324,611
Construction work in progress	158,052	182,196
Nonutility plant and equipment, at cost	1,136,718	1,124,896
Construction work in progress	452,685	365,346
Total property, plant and equipment	5,145,231	4,997,049
Accumulated depreciation and amortization, utility plant	(622,934)	(611,827)
Accumulated depreciation and amortization, nonutility plant and equipment	(179,194)	(171,709)
Property, plant and equipment, net	4,343,103	4,213,513
CURRENT ASSETS
Cash and cash equivalents	1,259	4,749
Customer accounts receivable
Billed	266,815	212,838
Unbilled revenues	72,949	10,351
Allowance for doubtful accounts	(24,767)	(24,652)
Regulatory assets	38,653	30,118
Natural gas in storage, at average cost	242,692	193,606
Materials and supplies, at average cost	19,341	19,561
Prepaid expenses	15,117	8,166
Prepaid and accrued taxes	23,246	51,211
Derivatives, at fair value	39,783	35,251
Restricted broker margin accounts	42,716	72,840
Other current assets	22,518	20,235
Total current assets	760,322	634,274
NONCURRENT ASSETS
Investments in equity method investees	114,249	114,529
Regulatory assets	528,074	522,099
Operating lease assets	173,617	173,928
Derivatives, at fair value	1,978	3,403
Intangible assets, net	4,337	5,029
Software costs	5,464	5,582
Other noncurrent assets	50,013	49,921
Total noncurrent assets	877,732	874,491
Total assets	5,981,157	5,722,278
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding December 31, 2021 — 95,961,710; September 30, 2021 — 95,709,662	241,274	240,644
Premium on common stock	513,134	502,584
Accumulated other comprehensive loss, net of tax	(33,498)	(34,528)
Treasury stock at cost and other; shares December 31, 2021 — 762,344; September 30, 2021 — 762,313	(15,067)	(12,448)
Retained earnings	1,011,135	934,610
Common stock equity	1,716,978	1,630,862
Long-term debt	2,274,176	2,162,164
Total capitalization	3,991,154	3,793,026
CURRENT LIABILITIES
Current maturities of long-term debt	74,461	72,840
Short-term debt	487,950	377,300
Natural gas purchases payable	149,945	168,697
Natural gas purchases payable to related parties	851	861
Deferred revenue	52,852	1,745
Accounts payable and other	168,197	223,497
Dividends payable	34,786	34,768
Accrued taxes	6,596	3,356
Regulatory liabilities	18,999	28,007
New Jersey Clean Energy Program	14,416	16,308
Derivatives, at fair value	30,049	87,145
Operating lease liabilities	4,531	4,300
Restricted broker margin accounts	15,475	0
Customers' credit balances and deposits	38,666	32,586
Total current liabilities	1,097,774	1,051,410
NONCURRENT LIABILITIES
Deferred income taxes	178,654	163,530
Deferred investment tax credits	2,930	3,010
Deferred revenue	14,621	847
Derivatives, at fair value	15,261	13,497
Manufactured gas plant remediation	126,872	135,012
Postemployment employee benefit liability	167,335	169,267
Regulatory liabilities	190,714	193,051
Operating lease liabilities	141,356	141,363
Asset retirement obligation	46,541	46,306
Other noncurrent liabilities	7,945	11,959
Total noncurrent liabilities	892,229	877,842
Commitments and contingent liabilities (Note 13)
Total capitalization and liabilities	$ 5,981,157	$ 5,722,278

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2021	Sep. 30, 2021
Statement of Financial Position [Abstract]
Common stock, par value (usd per share)	$ 2.50	$ 2.50
Common stock, shares authorized (in shares)	150,000,000	150,000,000
Common stock, shares outstanding (in shares)	95,961,710	95,709,662
Treasury stock at cost and other, shares (in shares)	762,344	762,313

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Unaudited) - USD ($) $ in Thousands		Total	Common Stock	Premium on Common Stock	Accumulated Other Comprehensive (Loss) Income	Treasury Stock And Other	Retained Earnings
Balance as of beginning of period (in shares) at Sep. 30, 2020			95,949,000
Balance as of beginning of period at Sep. 30, 2020		$ 1,643,896	$ 240,243	$ 491,982	$ (44,315)	$ 8,485	$ 947,501
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		81,045					81,045
Other comprehensive income		1,043			1,043
Common stock issued:
Incentive compensation plan (in shares)			50,000
Incentive compensation plan		5,534	$ 124	5,410
Dividend reinvestment plan (in shares)	[1]		140,000
Dividend reinvestment plan	[1]	1,091		(4,502)		5,593
Cash dividend declared		(31,966)					(31,966)
Treasury stock and other		(2,429)				(2,429)
Balance as of end of period (in shares) at Dec. 31, 2020			96,139,000
Balance as of end of period at Dec. 31, 2020		$ 1,698,214	$ 240,367	492,890	(43,272)	11,649	996,580
Balance as of beginning of period (in shares) at Sep. 30, 2021		95,709,662	95,710,000
Balance as of beginning of period at Sep. 30, 2021		$ 1,630,862	$ 240,644	502,584	(34,528)	(12,448)	934,610
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		111,312					111,312
Other comprehensive income		1,030			1,030
Common stock issued:
Incentive compensation plan (in shares)			147,000
Incentive compensation plan		7,502	$ 367	7,135
Dividend reinvestment plan (in shares)			105,000
Dividend reinvestment plan		3,678	$ 263	3,415
Cash dividend declared		(34,787)					(34,787)
Treasury stock and other (in shares)			0
Treasury stock and other		$ (2,619)				(2,619)
Balance as of end of period (in shares) at Dec. 31, 2021		95,961,710	95,962,000
Balance as of end of period at Dec. 31, 2021		$ 1,716,978	$ 241,274	$ 513,134	$ (33,498)	$ (15,067)	$ 1,011,135

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

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CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Cash dividend declared per share (usd per share)	$ 0.3625	$ 0.3325

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NATURE OF THE BUSINESS

3 Months Ended

Dec. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

NATURE OF THE BUSINESS

1. NATURE OF THE BUSINESS

The Company provides regulated natural gas distribution services, transmission and storage services and operates certain unregulated businesses primarily through the following:

NJNG provides natural gas utility service to approximately 566,600 customers throughout Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex counties in New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment.

NJRCEV, the Company's clean energy subsidiary, comprises the Clean Energy Ventures segment and invests in, owns and operates clean energy projects, including commercial and residential solar installations located in New Jersey, Connecticut, Rhode Island and New York.

NJRES comprises the Energy Services segment. Energy Services maintains and transacts around a portfolio of natural gas transportation and storage capacity contracts and provides physical wholesale energy, retail energy and energy management services in the U.S. and Canada.

NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, invests in energy-related ventures through its subsidiaries. The Company operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River and Adelphia Gateway, and is subject to rate regulation by FERC. The Company holds a 50 percent combined ownership interest in Steckman Ridge, located in Pennsylvania and 20 percent ownership interest in PennEast, which are accounted for under the equity method of accounting.

NJR Retail Holdings Corporation has two principal subsidiaries, NJRHS, which provides heating, central air conditioning, standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey, and CR&R, which owns commercial real estate. NJRHS and CR&R are included in Home Services and Other operations.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by the Company in accordance with the rules and regulations of the SEC and GAAP. The September 30, 2021 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 the Company's 2021 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 the Company'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, 2022. Intercompany transactions and accounts have been eliminated.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires the Company to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosure of contingencies during the reporting period. On a quarterly basis or more frequently whenever events or changes in circumstances indicate a need, the Company evaluates its estimates, including those related to the calculation of the fair value of derivative instruments, debt, equity method investments, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, long-lived assets, regulatory assets and liabilities, income taxes, pensions and other postemployment benefits, contingencies related to environmental matters and litigation. Asset retirement obligations are evaluated as often as needed. The Company’s estimates are based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources.

The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.

In March 2020, COVID-19 was declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention and has spread globally, including throughout the U.S. The Company’s Unaudited Condensed Consolidated Financial Statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the balance sheet date and reported amounts of revenue and expenses during the reporting periods presented.

The Company continues to closely monitor developments related to the COVID-19 pandemic and has, when appropriate, taken steps to ensure business continuity in the safe operation of its business. These steps include working from home for office-based employees, limiting direct contact with customers and suspending late payment fees for utility customers. While the Company and many businesses are beginning to return to normal operating practices, this remains an evolving situation. The timing for recovery of businesses and local economies, resurgences or mutations of the virus, and any potential future shutdowns remains unknown. Both the Company and NJNG continue to have sufficient liquidity to meet their current obligations and business operations remain fundamentally unchanged at this time. The Company will continue to monitor developments affecting its employees, customers, and operations and take additional steps to address the COVID-19 pandemic and its impacts, as necessary. The Company considered the impacts of COVID-19 on the assumptions and estimates used and determined that there have been no material adverse impacts on the Company’s results of operations as of December 31, 2021.

Revenues

Revenues from the sale of natural gas to NJNG customers are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for unbilled revenue. NJNG records unbilled revenue for natural gas services. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the month. At the end of each month, the amount of natural gas delivered to each customer after the last meter reading through the end of the respective accounting period is estimated, and recognizes unbilled revenues related to these amounts. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects, unaccounted-for natural gas and the most current tariff rates.

Clean Energy Ventures recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the transfer of certificates as per contractual settlement schedules. The Clean Energy Act of 2018 established guidelines for the closure of the SREC registration program to new applicants in New Jersey. The SREC program officially closed to new qualified solar projects on April 30, 2020.

In December 2019, the BPU established the TREC as the successor to the SREC program. TRECs provide a fixed compensation base multiplied by an assigned project factor in order to determine their value. The project factor is determined by the type and location of the project, as defined. All TRECs generated are required to be purchased monthly by a TREC program administrator as appointed by the BPU.

In June 2020, Clean Energy Ventures began generating TRECs for qualified new residential and commercial solar projects placed into service following the close of the SREC program. TREC revenue is recognized when TRECs are generated and are transferred monthly based upon metered solar electricity activity.

Revenues for Energy Services are recognized when the natural gas is physically delivered to the customer. In addition, changes in the fair value of derivatives that economically hedge the forecasted sales of the natural gas are recognized in operating revenues as they occur, as noted above. Energy Services also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues.

During December 2020, Energy Services entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts, which commenced on November 1, 2021. The AMAs include a series of temporary and permanent releases and revenue under these agreements is recognized as the performance obligations are satisfied. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis

over the agreed upon term. For permanent releases of pipeline capacity, which represent a transfer of contractual rights for such capacity, revenue is recognized upon the transfer of the underlying contractual rights. During the three months ended December 31, 2021, Energy Services recognized $22.1 million of operating revenue on the Unaudited Condensed Consolidated Statements of Operations. Amounts received in excess of revenue totaling $64.7 million are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets.

The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, related usage fees and hub services for the use of storage space, injections and withdrawals from their natural gas storage facility and the delivery of natural gas to customers. Demand fees are recognized as revenue over the term of the related agreement while usage fees and hub services revenues are recognized as services are performed.

Revenues from all other activities are recorded in the period during which products or services are delivered and accepted by customers, or over the related contractual term. See Note 3. Revenue for further information.

Cash and Cash Equivalents

Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to irrevocable letters of credit at Leaf River and escrow balances for utility plant projects at NJNG, which are recorded in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets, respectively.

The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Unaudited Condensed Consolidated Balance Sheets to the total amounts in the Unaudited Condensed Consolidated Statements of Cash Flows as follows:

(Thousands)	December 31, 2021		September 30, 2021		December 31, 2020
Balance Sheet
Cash and cash equivalents	$	1,259	$	4,749	$	22,358
Restricted cash in other noncurrent assets	$	1,294	$	1,294	$	2,431
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	2,553	$	6,043	$	24,789

Allowance for Doubtful Accounts

The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations, and macroeconomic factors, such as unemployment rates among others, including the estimated impact of the ongoing pandemic on the outstanding balances.

In December 2021, the Company deferred a portion of costs incurred related to bad debt for NJNG associated with customer accounts receivable as a regulatory asset resulting from the impacts of the ongoing COVID-19 pandemic. See Note 4. Regulation for additional information.

Loans Receivable

NJNG currently 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 fair value on the Unaudited Condensed Consolidated Balance Sheets. The Company has $14.1 million and $14.2 million recorded in other current assets and $32.6 million and $32.3 million in other noncurrent assets as of December 31, 2021 and September 30, 2021, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans. The Company regularly evaluates the credit quality and collection profile of its customers. If NJNG determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of December 31, 2021 and September 30, 2021, the Company has not recorded any impairments for SAVEGREEN loans.

Natural Gas in Storage

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

	December 31, 2021				September 30, 2021
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	110,673	22.7		$	115,824	27.6
Energy Services		132,019		28.9		77,782		18.8
Total		$	242,692	51.6		$	193,606	46.4

Software Costs

The Company capitalizes certain costs, such as software design and configuration, coding, testing and installation, that are incurred to purchase or create and implement computer software for internal use. Capitalized costs include external costs of materials and services utilized in developing or obtaining internal-use software and payroll and payroll-related costs for employees who are directly associated with and devote time to the internal-use software project. Maintenance costs are expensed as incurred. Upgrades and enhancements are capitalized if it is probable that such expenditures will result in additional functionality. Amortization is recorded on the straight-line basis over the estimated useful lives.

The following tables present the software costs included in the Unaudited Condensed Consolidated Financial Statements:

(Thousands)	December 31, 2021		September 30, 2021
Balance Sheets
Utility plant, at cost	$	16,777	$	16,543
Construction work in progress	$	11,725	$	7,801
Nonutility plant and equipment, at cost	$	341	$	338
Construction work in progress	$	1	$	8
Accumulated depreciation and amortization, utility plant	$	(1,644)	$	(1,333)
Accumulated depreciation and amortization, nonutility plant and equipment	$	(16)	$	(29)
Software costs	$	5,464	$	5,582

	Three Months Ended
	December 31,
Statements of Operations	2021		2020
Operation and maintenance (1)	$	2,523	$	1,924
Depreciation and amortization	$	299	$	253

(1)During the three months ended December 31, 2021 and 2020, approximately $113,000 and $77,000, respectively, was amortized from software costs into O&M.

Sale Leasebacks

NJNG utilizes sale leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease or repurchase the asset at the end of the term. Proceeds from sale leaseback transactions are accounted for as financing arrangements and are included in long-term debt on the Unaudited Condensed Consolidated Balance Sheets. NJNG received $17.3 million during the three months ended December 31, 2021, in connection with the sale leaseback of its natural gas meters. There were no natural gas meter sale leasebacks recorded during the three months ended December 31, 2020.

In addition, for certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third parties and the concurrent leaseback of the assets. For sale leaseback transactions where the Company has concluded that the arrangement does not qualify as a sale as the Company retains control of the underlying assets and, as such, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the buyer-lessor that constitute a payment to acquire the

solar energy asset as a financing arrangement, which is recorded as a component of debt on the Unaudited Condensed Consolidated Balance Sheets.

The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from RECs and energy sales. The ITCs and other tax benefits associated with these solar projects transfer to the buyer; however, the payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax attributes. Accordingly, Clean Energy Ventures recognizes the equivalent value of the tax attributes in other income on the Unaudited Condensed Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease.

During the three months ended December 31, 2021 and 2020, Clean Energy Ventures received proceeds of $3.3 million and $12.1 million, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets.

Accumulated Other Comprehensive (Loss) Income

The following table presents the changes in the components of accumulated other comprehensive (loss) income, net of related tax effects during the three months ended December 31, 2021 and 2020:

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2021	$	(9,376)	$	(25,152)		$	(34,528)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive loss, net of tax of $(79), $(233), $(312), respectively	264		766		(1)	1,030
Balance at December 31, 2021	$	(9,112)	$	(24,386)		$	(33,498)
Balance at September 30, 2020	$	(10,397)	$	(33,918)		$	(44,315)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive loss, net of tax of $(112), $(245) and $(357)	231		812		(1)	1,043
Balance at December 31, 2020	$	(10,166)	$	(33,106)		$	(43,272)

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

Reclassification

Certain prior period amounts related to deferred revenue within current liabilities on the Unaudited Condensed Consolidated Balance Sheets and Unaudited Consolidated Condensed Statements of Cash Flows have been reclassified to conform to the current period presentation.

Recently Adopted Updates to the Accounting Standards Codification

Income Taxes

In December 2019, the FASB issued ASU No. 2019-12, an amendment to ASC 740, Income Taxes, which simplifies the accounting for income taxes and changes the accounting for certain income tax transactions, among other minor improvements. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. The amendments in this update were either not applicable, currently applied, or did not have a material impact on the Company's financial position, results of operations, cash flows or disclosures.

Investments - Equity Securities, Investments - Equity Method and Joint Ventures and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, an amendment to ASC 321, Investments - Equity Securities, ASC 323, Investments - Equity Method and Joint Ventures, and ASC 815, Derivatives and Hedging, which clarifies the interactions between the three ASU topics. The update requires an entity to evaluate observable transactions that necessitate applying or discontinuing the equity method of accounting when applying the measurement alternative in Topic 321. This evaluation occurs prior to applying or upon ceasing the equity method. The update also states that when applying paragraph 815-10-15-141(a) for

forward contracts and purchased options, an entity is not required to assess whether the underlying securities will be accounted for under the equity method in accordance with Topic 323 or fair value method under Topic 825 upon settlement or exercise. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures.

Other

In October 2020, the FASB issued ASU No. 2020-10, Codification Improvements, which clarifies application of various provisions in the ASC by amending and adding new headings, cross referencing to other guidance, and refining or correcting terminology. It also improves the consistency by amending the ASC to include all disclosure guidance in the appropriate section. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures.

Other Recent Updates to the Accounting Standards Codification

Debt and Other

In August 2020, the FASB issued ASU No. 2020-06, an amendment to ASC 470, Debt, and ASC 815, Derivatives and Hedging, which changes the accounting for convertible instruments by reducing the number of acceptable accounting models to three models including, the embedded derivative, substantial premium, and traditional no proceeds allocated models. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it on either a modified or a full retrospective basis. The Company does not currently have convertible debt instruments and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption.

In May 2021, the FASB issued ASU No. 2021-04, an amendment to ASC 470, Debt, ASC 260, Earnings per Share, ASC 718, Stock Compensation, and ASC 815, Derivatives and Hedging. The update impacts equity-classified written call options that remain equity-classified after a modification or exchange. The guidance is effective for the Company beginning October 1, 2022, and will be applied on a prospective basis. The Company does not currently have equity-classified written call options and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Leases

In July 2021, the FASB issued ASU No. 2021-05, an amendment to ASC 842, Leases, which requires a lessor to classify a lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another classification, including sales-type or direct financing would trigger a loss at the lease commencement date. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it either on a retrospective basis to leases that have commenced or have been modified under ASC 842 or on a prospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Business Combinations

In October 2021, the FASB issued ASU No. 2021-08, an amendment to ASC 805, Business Combinations, which requires that an acquirer recognize, and measure contract assets and contract liabilities acquired in a business combination in accordance with Topic 606, Revenue from Contracts with Customers. The guidance is effective for the Company beginning October 1, 2023, and will be applied on a prospective basis to new acquisitions following the date of adoption. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

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REVENUE

3 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

REVENUE

3. REVENUE

Revenue is recognized when a performance obligation is satisfied by transferring control of a product or service to a customer. Revenue is measured based on consideration specified in a contract with a customer using the output method of progress. The Company elected to apply the invoice practical expedient for recognizing revenue, whereby the amounts invoiced to customers represent the value to the customer and the Company’s performance completion as of the invoice date. Therefore, the Company does not disclose related unsatisfied performance obligations. The Company also elected the practical expedient to exclude from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales tax net in operating revenues on the Unaudited Condensed Consolidated Statements of Operations.

Below is a listing of performance obligations that arise from contracts with customers, along with details on the satisfaction of each performance obligation, the significant payment terms and the nature of the goods and services being transferred, by reporting segment and other business operations:

Revenue Recognized Over Time:
Segment	Performance Obligation	Description
Natural Gas Distribution	Natural gas utility sales	NJNG's performance obligation is to provide natural gas to residential, commercial and industrial customers as demanded, based on regulated tariff rates, which are established by the BPU. Revenues from the sale of natural gas are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for quantities consumed but not billed during the period. Payment is due each month for the previous month's deliveries. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the billing period. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects and the most current tariff rates. NJNG is entitled to be compensated for performance completed until service is terminated. Customers may elect to purchase the natural gas commodity from NJNG or may contract separately to purchase natural gas directly from third-party suppliers. As NJNG is acting as an agent on behalf of the third-party supplier, revenue is recorded for the delivery of natural gas to the customer.
Clean Energy Ventures	Commercial solar electricity	Clean Energy Ventures operates wholly-owned solar projects that recognize revenue as electricity is generated and transferred to the customer. The performance obligation is to provide electricity to the customer in accordance with contract terms or the interconnection agreement and is satisfied upon transfer of electricity generated. Revenue is recognized as invoiced and the payment is due each month for the previous month's services.
Clean Energy Ventures	Residential solar electricity	Clean Energy Ventures provides access to residential rooftop and ground-mount solar equipment to customers who then pay the Company a monthly fee. The performance obligation is to provide electricity to the customer based on generation from the underlying residential solar asset and is satisfied upon transfer of electricity generated. Revenue is derived from the contract terms and is recognized as invoiced, with the payment due each month for the previous month's services.
Clean Energy Ventures	Transition renewable energy certificates	Clean Energy Ventures generates TRECs, which are created for every MWh of electricity produced by a solar generator. The performance obligation of Clean Energy Ventures is to generate electricity and TRECs, which are purchased monthly by a REC Administrator. Revenue is recognized upon generation.
Energy Services	Natural gas services	The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers in line with the terms of the contract and based on the services provided. Payment is due upon receipt of the invoice. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed upon term.
Storage and Transportation	Natural gas services	The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as customers receive the benefits of its service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement.
Home Services and Other	Service contracts	Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice.

Revenue Recognized at a Point in Time:
Energy Services	Natural gas services	For a permanent release of pipeline capacity, the performance obligation of NJRES is the release of the pipeline capacity associated with certain natural gas transportation contracts and the transfer of the underlying contractual rights to the counterparty. Revenue is recognized upon the transfer of the underlying contractual rights.
Storage and Transportation	Natural gas services	The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from usage fees and hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Usage fees and hub services revenues are recognized as services are performed.
Home Services and Other	Installations	Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators to customers. The distinct performance obligation is the installation of the contracted appliance, which is satisfied at the point in time the item is installed. The transaction price for each installation differs accordingly. Revenue is recognized at a point in time upon completion of the installation, which is when the customer is billed.

Disaggregated revenues from contracts with customers by product line and by reporting segment and other business operations during the three months ended December 31, 2021 and 2020, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales (1)	$	223,796	—		—	—	—	$	223,796
Natural gas services	—		—		27,879	12,143	—	40,022
Service contracts	—		—		—	—	8,467	8,467
Installations and maintenance	—		—		—	—	5,484	5,484
Renewable energy certificates	—		846		—	—	—	846
Electricity sales	—		6,470		—	—	—	6,470
Eliminations (2	(337)		—		—	(559)	(99)	(995)
Revenues from contracts with customers	223,459		7,316		27,879	11,584	13,852	284,090
Alternative revenue programs (3)	10,654		—		—	—	—	10,654
Derivative instruments	40,322		2,867	(4)	341,365	—	—	384,554
Eliminations (2)	—		—		(3,456)	—	—	(3,456)
Revenues out of scope	50,976		2,867		337,909	—	—	391,752
Total operating revenues	$	274,435	10,183		365,788	11,584	13,852	$	675,842
2020
Natural gas utility sales	$	189,364	—		—	—	—	$	189,364
Natural gas services	—		—		6,428	13,104	—	19,532
Service contracts	—		—		—	—	8,259	8,259
Installations and maintenance	—		—		—	—	4,318	4,318
Renewable energy certificates	—		690		—	—	—	690
Electricity sales	—		4,388		—	—	—	4,388
Eliminations (1)	—		—		—	(657)	(167)	(824)
Revenues from contracts with customers	189,364		5,078		6,428	12,447	12,410	225,727
Alternative revenue programs (3)	1,568		—		—	—	—	1,568
Derivative instruments	4,797		1,292	(4)	223,049	—	—	229,138
Eliminations (2)	—		—		(2,128)	—	—	(2,128)
Revenues out of scope	6,365		1,292		220,921	—	—	228,578
Total operating revenues	$	195,729	6,370		227,349	12,447	12,410	$	454,305

(1)Includes building rent related to the Wall headquarters, which is eliminated in consolidation.

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

(3)Includes CIP revenue.

(4)Includes SREC revenue.

Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the three months ended December 31, 2021 and 2020, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	151,308	2,972	—	—	13,775	$	168,055
Commercial and industrial	47,184		4,344	27,879	11,584	77	91,068
Firm transportation	22,675		—	—	—	—	22,675
Interruptible and off-tariff	2,292		—	—	—	—	2,292
Revenues out of scope	50,976		2,867	337,909	—	—	391,752
Total operating revenues	$	274,435	10,183	365,788	11,584	13,852	$	675,842
2020
Residential	$	137,224	2,722	—	—	12,204	$	152,150
Commercial and industrial	29,229		2,356	6,428	12,447	206	50,666
Firm transportation	21,104		—	—	—	—	21,104
Interruptible and off-tariff	1,807		—	—	—	—	1,807
Revenues out of scope	6,365		1,292	220,921	—	—	228,578
Total operating revenues	$	195,729	6,370	227,349	12,447	12,410	$	454,305

Customer Accounts Receivable/Credit Balances and Deposits

The timing of revenue recognition, customer billings and cash collections resulting in accounts receivables, billed and unbilled, and customers’ credit balances and deposits on the Unaudited Condensed Consolidated Balance Sheets during the three months ended December 31, 2021 and 2020, are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of September 30, 2021	$	212,838	$	10,351	$	32,586
Increase	53,977		62,598		6,080
Balance as of December 31, 2021	$	266,815	$	72,949	$	38,666
Balance as of September 30, 2020	$	134,173	$	9,226	$	25,934
Increase	63,468		44,568		7,014
Balance as of December 31, 2020	$	197,641	$	53,794	$	32,948

The following table provides information about receivables, which are included within accounts receivable, billed and unbilled, and customers’ credit balances and deposits, respectively, on the Unaudited Condensed Consolidated Balance Sheets as of December 31, 2021 and September 30, 2021:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
December 31, 2021
Customer accounts receivable
Billed	$	102,890	4,608	153,014	4,339	1,964	$	266,815
Unbilled	71,542		1,407	—	—	—	72,949
Customers' credit balances and deposits	(38,666)		—	—	—	—	(38,666)
Total	$	135,766	6,015	153,014	4,339	1,964	$	301,098
September 30, 2021
Customer accounts receivable
Billed	$	54,514	5,534	147,087	3,956	1,747	$	212,838
Unbilled	8,427		1,924	—	—	—	10,351
Customers' credit balances and deposits	(32,586)		—	—	—	—	(32,586)
Total	$	30,355	7,458	147,087	3,956	1,747	$	190,603

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REGULATION

3 Months Ended

Dec. 31, 2021

Regulated Operations [Abstract]

REGULATION

4. 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 filings to the BPU for review of its BGSS, CIP and other programs and related rates. Annual rate changes are typically requested to be effective at the beginning of the following fiscal year. The current base rates include a weighted average cost of capital of 6.84 percent and a return on common equity of 9.6 percent. All rate and program changes are subject to proper notification and BPU review and approval. In addition, NJNG is permitted to implement certain BGSS rate changes on a provisional basis with proper notification to the BPU.

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

(Thousands)	December 31, 2021		September 30, 2021
Regulatory assets-current
New Jersey Clean Energy Program	$	14,416	$	16,308
Conservation Incentive Program	22,493		11,839
Other current regulatory assets	1,371		1,554
Total current regulatory assets	$	38,280	$	29,701
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	64,662	$	58,483
Liability for future expenditures	126,881		135,012
Deferred income taxes	39,613		39,694
SAVEGREEN	37,342		32,941
Postemployment and other benefit costs	114,515		117,194
Deferred storm damage costs	3,800		4,343
Cost of removal	99,160		99,238
Other noncurrent regulatory assets	38,685		32,695
Total noncurrent regulatory assets	$	524,658	$	519,600
Regulatory liability-current
Overrecovered natural gas costs	$	11,659	$	5,510
Derivatives at fair value, net	7,340		22,497
Total current regulatory liabilities	$	18,999	$	28,007
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	189,131	$	190,386
Derivatives at fair value, net	—		1,166
Other noncurrent regulatory liabilities	688		336
Total noncurrent regulatory liabilities	$	189,819	$	191,888

(1)Reflects the re-measurement and subsequent amortization of NJNG's net deferred tax liabilities as a result of the change in federal tax rates enacted in the Tax Act.

At December 31, 2021, other noncurrent regulatory assets include deferred pandemic costs of $10.7 million primarily related to a portion of bad debt associated with customer accounts receivable resulting from the impacts of the ongoing COVID-19 pandemic. These costs are eligible for future regulatory recovery.

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

(Thousands)	December 31, 2021		September 30, 2021
Total current regulatory assets	$	373	$	417
Total noncurrent regulatory assets	$	3,416	$	2,499
Total noncurrent regulatory liabilities	$	895	$	1,163

The assets are comprised primarily of the tax benefit associated with the equity component of AFUDC and the liability consists primarily of scheduling penalties. Recovery of regulatory assets is subject to FERC approval.

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

•On November 17, 2021, the BPU issued an order adopting a stipulation of settlement approving a $79.0 million increase to base rates, effective December 1, 2021. In addition, the order also included approval for the final increase for the NJ RISE/SAFE II programs, which totaled $269,000. The increase includes an overall rate of return on rate base of 6.84 percent, return on common equity of 9.6 percent, a common equity ratio of 54.0 percent and a depreciation rate of 2.78 percent.

•On November 17, 2021, the BPU approved a $2.9 million increase to the annual revenues credited to BGSS, a $13.0 million annual increase related to its balancing charge, as well as changes to CIP rates, which will result in a $6.3 million decrease to the annual recovery, effective December 1, 2021.

•On November 19, 2021, NJNG submitted notification of its intent to self-implement an increase to its BGSS rate which will result in an approximately $24.2 million increase to annual revenues credited to BGSS, effective December 1, 2021.

•On January 26, 2022, the BPU approved a stipulation to resolve the current EE annual cost recovery filing, which will increase annual recoveries by $2.2 million, effective February 1, 2022.

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DERIVATIVE INSTRUMENTS

3 Months Ended

Dec. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE INSTRUMENTS

5. DERIVATIVE INSTRUMENTS

The Company is subject primarily 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 is exposed to foreign currency and interest rate risk and may utilize foreign currency derivatives to hedge Canadian dollar denominated natural gas purchases and/or sales and interest rate derivatives to reduce exposure to fluctuations in interest rates. All of these types of contracts are accounted for as derivatives, unless the Company elects NPNS, which is done on a contract-by-contract election. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company’s fair value measurement policies and level disclosures associated with the Company’s derivative instruments, see Note 6. Fair Value.

Energy Services

Energy Services 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 natural gas purchases or operating revenues, as appropriate for Energy Services, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of natural 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 natural gas purchases or operating revenues.

Energy Services 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. Energy Services may utilize foreign currency derivatives to lock in the exchange rates 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 natural gas purchase agreements.

As a result of Energy Services 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 natural 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. Energy Services 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.

Natural Gas Distribution

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 a portfolio basis. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as 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 natural 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.

Clean Energy Ventures

The Company elects NPNS accounting treatment on PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to do so, the Company can and may elect to treat certain contracts as normal.

Fair Value of Derivatives

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

			Derivatives at Fair Value
			December 31, 2021						September 30, 2021
(Thousands)	Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	234		$	4		$	36		$	16
Financial commodity contracts	Derivatives - current		5,032			240			2,046			13
Energy Services:
Physical commodity contracts	Derivatives - current		2,285			18,592			2,818			24,592
	Derivatives - noncurrent		135			15,261			333			13,237
Financial commodity contracts	Derivatives - current		32,164			11,209			30,226			62,521
	Derivatives - noncurrent		1,843			—			3,068			260
Foreign currency contracts	Derivatives - current		68			4			125			3
	Derivatives - noncurrent		—			—			2			—
Total fair value of derivatives			$	41,761		$	45,310		$	38,654		$	100,642

Offsetting of Derivatives

The Company transacts under master netting arrangements or equivalent agreements that allow it to offset derivative assets and liabilities with the same counterparty. However, the Company’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 the Company has the right to offset but elects not to, financial collateral, as well as the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(Thousands)	Amounts Presented on Balance Sheets (1)			Offsetting Derivative Instruments (2)			Financial Collateral Received/Pledged (3)			Net Amounts (4)
As of December 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	2,420		$	(908)		$	(200)		$	1,312
Financial commodity contracts		34,007			(9,247)			—			24,760
Foreign currency contracts		68			(4)			—			64
Total Energy Services		$	36,495		$	(10,159)		$	(200)		$	26,136
Natural Gas Distribution
Physical commodity contracts		$	234		$	—		$	—		$	234
Financial commodity contracts		5,032			(240)			—			4,792
Total Natural Gas Distribution		$	5,266		$	(240)		$	—		$	5,026
Derivative liabilities:
Energy Services
Physical commodity contracts		$	33,853		$	(908)		$	—		$	32,945
Financial commodity contracts		11,209			(9,247)			—			1,962
Foreign currency contracts		4			(4)			—			—
Total Energy Services		$	45,066		$	(10,159)		$	—		$	34,907
Natural Gas Distribution
Physical commodity contracts		$	4		$	—		$	—		$	4
Financial commodity contracts		240			(240)			—			—
Total Natural Gas Distribution		$	244		$	(240)		$	—		$	4
As of September 30, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	3,151		$	(894)		$	(700)		$	1,557
Financial commodity contracts		33,294			(33,294)			20,532			20,532
Foreign currency contracts		127			(3)						124
Total Energy Services		$	36,572		$	(34,191)		$	19,832		$	22,213
Natural Gas Distribution
Physical commodity contracts		$	36		$	(8)		$	—		$	28
Financial commodity contracts		2,046			(13)			—			2,033
Total Natural Gas Distribution		$	2,082		$	(21)		$	—		$	2,061
Derivative liabilities:
Energy Services
Physical commodity contracts		$	37,829		$	(894)		$	—		$	36,935
Financial commodity contracts		62,781			(33,294)			—			29,487
Foreign currency contracts		3			(3)			—			—
Total Energy Services		$	100,613		$	(34,191)		$	—		$	66,422
Natural Gas Distribution
Physical commodity contracts		$	16		$	(8)		$	—		$	8
Financial commodity contracts		13			(13)			—			—
Total Natural Gas Distribution		$	29		$	(21)		$	—		$	8

(1)Derivative assets and liabilities are presented on a gross basis on 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.

Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical natural 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 natural 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 Energy Services, although the Company's intended economic results relating to the entire transaction are unaffected.

The following table presents the effect of derivative instruments recognized on the Unaudited Condensed Consolidated Statements of Operations for the periods set forth below:

(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended
		December 31,
Derivatives not designated as hedging instruments:		2021		2020
Energy Services:
Physical commodity contracts	Operating revenues	$	150	$	5,252
Physical commodity contracts	Natural gas purchases	1,505		(5,054)
Financial commodity contracts	Natural gas purchases	61,189		47,755
Foreign currency contracts	Natural gas purchases	—		200
Total unrealized and realized loss		$	62,844	$	48,153

NJNG’s derivative contracts are part of the Company's risk management activities that relate to its natural gas purchases and BGSS incentive programs. 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 for the periods set forth below:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Natural Gas Distribution:
Physical commodity contracts	$	1,696	$	342
Financial commodity contracts	(14,647)		(4,272)
Total unrealized and realized (loss)	$	(12,951)	$	(3,930)

During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with debt issuances that were finalized in 2020. NJR designates its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges are recorded in OCI and upon settlement of the contracts, realized gains and (losses) are reclassified from OCI to interest expense on the Consolidated Statements of Operations. During both the three months ended December 31, 2021 and 2020, $343,000 of pre-tax loss was reclassified from OCI into income.

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

		Volume (Bcf)
	Transaction Type	December 31, 2021	September 30, 2021
Natural Gas Distribution	Futures	24.0	22.2
	Physical Commodity	1.5	7.6
Energy Services	Futures	(22.0)	(13.4)
	Swaps	(0.2)	(0.3)
	Physical Commodity	(4.9)	0.6

Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $63,000 as of December 31, 2021 and $(123,000) as of September 30, 2021, respectively, and 1.4 million SRECs that were open as of both December 31, 2021 and September 30, 2021.

Broker Margin

Futures exchanges have contract specific 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 the Natural Gas Distribution and Energy Services segments. The balances are as follows:

(Thousands)	Balance Sheet Location	December 31, 2021		September 30, 2021
Natural Gas Distribution	Restricted broker margin accounts-current assets	$	5,358	$	2,790
Energy Services	Restricted broker margin accounts-current assets	$	37,358	$	70,050
	Restricted broker margin accounts-current liabilities	$	(15,475)	$	—

Wholesale Credit Risk

NJNG, Energy Services, Clean Energy Ventures and the Storage and Transportation segment 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, 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 then the Company could sustain a loss.

The Company 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 the Company's election not to extend credit or because exposure exceeds defined thresholds. Most of the Company'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 Fitch or Moody's. In these cases, the counterparty's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by Fitch and/or Moody's are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of December 31, 2021. 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 Clean Energy Ventures residential solar installations.

(Thousands)	Gross Credit Exposure
Investment grade		$	185,828
Noninvestment grade		11,016
Internally rated investment grade		23,742
Internally rated noninvestment grade		30,016
Total		$	250,602

Conversely, certain of NJNG's and Energy Services' 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. 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. There were no derivative instruments with credit-risk-related contingent features that were in a liability position for which collateral is required as of December 31, 2021 and 2020. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.

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FAIR VALUE

3 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

FAIR VALUE

6. 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, in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.

The estimated fair value of long-term debt, including current maturities, excluding finance leases, debt issuance costs and solar asset financing obligations, is as follows:

(Thousands)	December 31, 2021		September 30, 2021
Carrying value (1) (2) (3)	$	2,202,845	$	2,102,845
Fair market value	$	2,373,791	$	2,288,544

(1)Excludes finance leases of $35.1 million and $20.1 million as of December 31, 2021 and September 30, 2021, respectively.

(2)Excludes NJNG's debt issuance costs of $10.3 million and $9.1 million as of December 31, 2021 and September 30, 2021, respectively.

(3)Excludes NJR's debt issuance costs of $3.7 million and $3.3 million as of December 31, 2021 and September 30, 2021, respectively.

Clean Energy Ventures enters into transactions to sell certain commercial solar assets and lease the assets back for a term specified in the lease. These transactions are considered financing obligations for accounting purposes and are recorded within long-term debt on the Unaudited Condensed Consolidated Balance Sheets. The estimated fair value of solar asset financing obligations as of December 31, 2021 and September 30, 2021 was $131.5 million and $132.5 million, respectively.

The Company utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific issue and the Company's credit rating. As of December 31, 2021, the Company discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, investments in equity 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 1Unadjusted quoted prices for identical assets or liabilities in active markets. The Company'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 the Company refers to internally as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM.

Level 2Other 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. The Company'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). 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 3Inputs derived from a significant amount of unobservable market data. These include the Company's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of December 31, 2021:
Assets:
Physical commodity contracts		$	—		$	2,654		$	—	$	2,654
Financial commodity contracts		39,039			—			—		39,039
Financial commodity contracts - foreign exchange		—			68			—		68
Money market funds		41			—			—		41
Other		2,085			—			—		2,085
Total assets at fair value		$	41,165		$	2,722		$	—	$	43,887
Liabilities:
Physical commodity contracts		$	—		$	33,857		$	—	$	33,857
Financial commodity contracts		11,278			171			—		11,449
Financial commodity contracts - foreign exchange		—			4			—		4
Total liabilities at fair value		$	11,278		$	34,032		$	—	$	45,310

	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 September 30, 2021:
Assets:
Physical commodity contracts		$	—		$	3,187		$	—	$	3,187
Financial commodity contracts		35,340			—			—		35,340
Financial commodity contracts - foreign exchange		—			127			—		127
Money market funds		41			—			—		41
Other		1,815			—			—		1,815
Total assets at fair value		$	37,196		$	3,314		$	—	$	40,510
Liabilities:
Physical commodity contracts		$	—		$	37,845		$	—	$	37,845
Financial commodity contracts		62,188			606			—		62,794
Financial commodity contracts - foreign exchange		—			3			—		3
Total liabilities at fair value		$	62,188		$	38,454		$	—	$	100,642

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INVESTMENTS IN EQUITY INVESTEES

3 Months Ended

Dec. 31, 2021

Investments, All Other Investments [Abstract]

INVESTMENTS IN EQUITY INVESTEES

7. INVESTMENTS IN EQUITY INVESTEES

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

(Thousands)	December 31, 2021		September 30, 2021
Steckman Ridge (1)	$	108,770	$	109,050
PennEast	5,479		5,479
Total	$	114,249	$	114,529

(1)Includes loans with a total outstanding principal balance of $70.4 million for both December 31, 2021 and September 30, 2021, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

Steckman Ridge

The Company holds a 50 percent equity method investment in Steckman Ridge, a jointly owned and controlled natural gas storage facility located in Bedford County, Pennsylvania. NJNG and Energy Services have entered into storage and park and loan agreements with Steckman Ridge. See Note 15. Related Party Transactions for more information on these intercompany transactions.

PennEast

The Company, through its subsidiary NJR Midstream Company, is a 20 percent investor in PennEast, a partnership whose purpose was to construct and operate a 120-mile natural gas pipeline that would have extended from northeast Pennsylvania to western New Jersey.

During the third quarter of fiscal 2021, the PennEast partnership determined that this project is no longer supported, and all further development has ceased. The Company recognized an other-than-temporary impairment charge of $92.0 million, or approximately $74.5 million, net of income taxes, which represents the best estimate of the salvage value of the remaining assets of the project. Other-than-temporary impairments are recorded in equity in earnings (losses) of affiliates in the Unaudited Condensed Consolidated Statements of Operations.

On December 16, 2021, the FERC dismissed PennEast’s pending applications. The order vacates the certificate authorization for the PennEast pipeline project in light of PennEast’s response to FERC staff’s November 23, 2021 request for a status update, in which PennEast informed the Commission it is no longer developing the project.

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EARNINGS PER SHARE

3 Months Ended

Dec. 31, 2021

Earnings Per Share [Abstract]

EARNINGS PER SHARE

8. EARNINGS PER SHARE

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

	Three Months Ended
	December 31,
(Thousands, except per share amounts)	2021		2020
Net income, as reported	$	111,312	$	81,045
Basic earnings per share
Weighted average shares of common stock outstanding-basic	95,944		96,114
Basic earnings per common share	$1.16		$0.84
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	95,944		96,114
Incremental shares (1)	412		301
Weighted average shares of common stock outstanding-diluted	96,356		96,415
Diluted earnings per common share (2)(3)	$1.16		$0.84

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

(2)There were anti-dilutive shares of 32,317 excluded from the calculation of diluted earnings per share related to an equity forward sale agreement during the three months ended December 31, 2020.

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DEBT

3 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

DEBT

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 and committed unsecured credit facilities.

Credit Facilities

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

(Thousands)	December 31, 2021			September 30, 2021			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	500,000		$	500,000		September 2026
Notes outstanding at end of period	$	310,550		$	219,100
Weighted average interest rate at end of period	1.13		%	1.05		%
Amount available at end of period (2)	$	169,862		$	270,312
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		September 2026
Commercial paper and notes outstanding at end of period	$	177,400		$	158,200
Weighted average interest rate at end of period	0.55		%	0.17		%
Amount available at end of period (4)	$	71,869		$	91,069

(1)Committed credit facilities, which require commitment fees of 0.10 percent on the unused amounts.

(2)Letters of credit outstanding total $19.6 million at December 31, 2021 and $10.6 million at September 30, 2021, which reduces the amount available by the same amount.

(3)Committed credit facilities, which require commitment fees of 0.075 percent on the unused amounts.

(4)Letters of credit outstanding total $731,000 at both December 31, 2021 and September 30, 2021, 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 October 28, 2021, NJNG entered into a Note Purchase Agreement for $100 million of its senior notes, of which $50 million were issued at an interest rate of 2.97 percent, maturing in 2051, and $50 million were issued at an interest rate of 3.07 percent, maturing in 2061. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

NJNG received $17.3 million during the three months ended December 31, 2021, in connection with the sale leaseback of its natural gas meters. NJNG records a financing 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. During the three months ended December 31, 2021, NJNG exercised an early purchase option with respect to meter leases by making a final principal payment of $1.1 million. NJNG continues to evaluate this sale leaseback program based on current market conditions. Natural gas meters are excepted from the lien on NJNG property under the Mortgage Indenture. There were no natural gas meter sale leasebacks recorded during the three months ended December 31, 2020.

Clean Energy Ventures

Clean Energy Ventures enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over a period of five to 15 years. These transactions are treated as financing obligations for accounting purposes, and are typically secured by the renewable energy facility asset and its future cash flows from RECs and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if applicable; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Clean Energy Ventures

continues to operate the solar assets, including related expenses, and retain the revenue generated from RECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. During the three months ended December 31, 2021 and 2020, Clean Energy Ventures received proceeds of $3.3 million and $12.1 million, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets.

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EMPLOYEE BENEFIT PLANS

3 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]

EMPLOYEE BENEFIT PLANS

10. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

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

	Pension				OPEB
	Three Months Ended				Three Months Ended
	December 31,				December 31,
(Thousands)	2021		2020		2021		2020
Service cost	$	2,073	$	2,182	$	1,076	$	1,211
Interest cost	2,408		2,278		1,589		1,518
Expected return on plan assets	(5,319)		(5,224)		(1,894)		(1,683)
Recognized actuarial loss	2,186		2,862		1,421		1,977
Prior service cost (credit) amortization	25		25		(36)		(45)
Net periodic benefit cost	$	1,373	$	2,123	$	2,156	$	2,978

The Company does not expect to be required to make additional contributions to fund the pension plans during fiscal 2022 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 three months ended December 31, 2021 and 2020.

There are no federal requirements to pre-fund OPEB benefits. However, the Company is required to fund certain amounts due to regulatory agreements with the BPU and estimates that it will contribute between $5 million and $10 million over each of the next five years. Additional contributions may be required based on market conditions and changes to assumptions.

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INCOME TAXES

3 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

INCOME TAXES

11. INCOME TAXES

ASC Topic 740, Income Taxes requires the use of an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating its estimated annual effective tax rate, the Company considers forecasted annual pre-tax income and estimated permanent book versus tax differences. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

Changes in tax laws or tax rates are recognized in the financial reporting period that includes the enactment date, the date in which the act is signed into law.

The Company evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with unrecognized tax benefits. A tax benefit claimed, or expected to be claimed, on a tax return may be recognized if it is more likely than not that the position will be upheld upon examination by the applicable taxing authority. Interest and penalties related to unrecognized tax benefits, if any, are recognized within income tax expense and accrued interest, and penalties are recognized within other noncurrent liabilities on the Unaudited Condensed Consolidated Balance Sheets.

Effective Tax Rate

The forecasted effective tax rates were 21.6 percent and 17.6 percent, for the three months ended December 31, 2021 and 2020, respectively.

To the extent there are discrete tax items that are not included in the forecasted effective tax rate, the actual effective tax rate may differ from the estimated annual effective tax rate. During the three months ended December 31, 2021 and 2020, discrete items totaled approximately $166,000 and $(76,000), respectively, related to excess tax expense (benefits) associated with the vesting of share-based awards. NJR’s actual effective tax rate was 21.7 percent and 17.7 percent during the three months ended December 31, 2021 and 2020, respectively.

Other Tax Items

As of December 31, 2021 and September 30, 2021, the Company has tax credit carryforwards of approximately $226.1 million and $224.2 million, respectively, which each have a life of 20 years. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2035.

As of December 31, 2021 and September 30, 2021, the Company has state income tax net operating losses of approximately $461.9 million and $554.6 million, respectively. These state net operating losses have varying carry-forward periods dictated by the state in which they were incurred; these state carry-forward periods range from seven to 20 years and began to expire in fiscal 2021, with the majority expiring after 2035. The Company expects to utilize this entire carryforward, other than as described below.

The impairment of the equity method investment in PennEast created potential net capital loss attributes totaling approximately $61.8 million, which can only be utilized to offset capital gains income, and can be carried back three years and forward five years prior to expiration.

As of December 31, 2021, the Company has a valuation allowance totaling $23.7 million comprised of approximately $17.3 million related to the recognition of state net operating loss carryforwards, which primarily relate to New Jersey and approximately $6.4 million related to potential capital loss carryforwards resulting from the impairment of the equity method investment in PennEast, which the Company believes may not be fully utilized prior to expiration. As of September 30, 2021, the Company had a valuation allowance totaling $23.6 million related to the state net operating loss carryforwards and the potential capital loss carryforwards resulting from the impairment of the equity method investment, as previously discussed.

The Consolidated Appropriations Act extended the 30 percent ITC for solar property that is under construction on or before December 31, 2019. Projects placed in service after December 31, 2019, may also qualify for a 30 percent federal ITC if five percent or more of the total costs of a solar property are incurred before the end of the applicable year and there are continuous efforts to advance towards completion of the project, based on the IRS guidance around ITC safe harbor determination. The credit declined to 26 percent for property under construction before the end of 2020. The Consolidated Appropriations Act, 2021 extended the 26 percent tax credit for property under construction during 2021 and 2022. The credit will drop to 22 percent for property under construction before the end of 2023. After 2023 the ITC will be reduced to 10 percent.

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LEASES

3 Months Ended

Dec. 31, 2021

Leases [Abstract]

LEASES

12. LEASES

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases.

The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of its natural gas meters.

Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns.

Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five to 20 years. The Company’s office leases vary in duration, ranging from two to 17 years and may or may not include extension or early purchase options. The Company’s meter lease terms are between seven and ten years with purchase options available prior to the end of the term. Equipment leases include general office equipment that also vary in duration, with an average term of six years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The Company has elected an accounting policy that exempts leases with an original term of one year or less from the recognition requirements of ASC 842, Leases.

The Company has lease agreements with lease and non-lease components and has elected the practical expedient to combine lease and non-lease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not considered material to the Company. The Company’s lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

The following table presents the Company's lease costs included in the Unaudited Condensed Consolidated Statements of Operations:

		Three Months Ended
		December 31,
(Thousands)	Income Statement Location	2021		2020
Operating lease cost (1)	Operation and maintenance	$	2,119	$	2,089
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	396		1,246
Interest on lease liabilities	Interest expense, net of capitalized interest	80		221
Total finance lease cost		476		1,467
Short-term lease cost	Operation and maintenance	11		127
Variable lease cost	Operation and maintenance	191		153
Total lease cost		$	2,797	$	3,836

(1)Net of capitalized costs.

The following table presents supplemental cash flow information related to leases:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,037	$	1,737
Operating cash flows for finance leases	$	170	$	2,176
Financing cash flows for finance leases	$	2,275	$	5,997

Assets obtained or modified for operating lease liabilities totaled approximately $808,000 and $9.3 million during the three months ended December 31, 2021 and 2020, respectively. Assets obtained or modified through finance lease liabilities totaled $17.3 million during the three months ended December 31, 2021. There were no assets obtained or modified through finance lease liabilities during the three months ended December 31, 2020.

The following table presents the balance and classifications of the Company's right of use assets and lease liabilities included in the Unaudited Condensed Consolidated Balance Sheets:

(Thousands)	Balance Sheet Location	December 31, 2021		September 30, 2021
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	173,617	$	173,928
Finance lease assets	Utility plant	23,286		13,489
Total lease assets		$	196,903	$	187,417
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,531	$	4,300
Finance lease liabilities	Current maturities of long-term debt	6,397		5,393
Noncurrent
Operating lease liabilities	Operating lease liabilities	141,356		141,363
Finance lease liabilities	Long-term debt	28,673		14,742
Total lease liabilities		$	180,957	$	165,798

For operating lease assets and liabilities, the weighted average remaining lease term was 29.7 years and 29.6 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.2 percent as of both December 31, 2021 and September 30, 2021.

For finance lease assets and liabilities as of December 31, 2021 and September 30, 2021, the weighted average remaining lease term was 4.7 years and 3.4 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.7 percent and 3.5 percent as of December 31, 2021 and September 30, 2021, respectively.

LEASES

12. LEASES

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases.

The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of its natural gas meters.

Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns.

Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five to 20 years. The Company’s office leases vary in duration, ranging from two to 17 years and may or may not include extension or early purchase options. The Company’s meter lease terms are between seven and ten years with purchase options available prior to the end of the term. Equipment leases include general office equipment that also vary in duration, with an average term of six years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The Company has elected an accounting policy that exempts leases with an original term of one year or less from the recognition requirements of ASC 842, Leases.

The Company has lease agreements with lease and non-lease components and has elected the practical expedient to combine lease and non-lease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not considered material to the Company. The Company’s lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

The following table presents the Company's lease costs included in the Unaudited Condensed Consolidated Statements of Operations:

		Three Months Ended
		December 31,
(Thousands)	Income Statement Location	2021		2020
Operating lease cost (1)	Operation and maintenance	$	2,119	$	2,089
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	396		1,246
Interest on lease liabilities	Interest expense, net of capitalized interest	80		221
Total finance lease cost		476		1,467
Short-term lease cost	Operation and maintenance	11		127
Variable lease cost	Operation and maintenance	191		153
Total lease cost		$	2,797	$	3,836

(1)Net of capitalized costs.

The following table presents supplemental cash flow information related to leases:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,037	$	1,737
Operating cash flows for finance leases	$	170	$	2,176
Financing cash flows for finance leases	$	2,275	$	5,997

Assets obtained or modified for operating lease liabilities totaled approximately $808,000 and $9.3 million during the three months ended December 31, 2021 and 2020, respectively. Assets obtained or modified through finance lease liabilities totaled $17.3 million during the three months ended December 31, 2021. There were no assets obtained or modified through finance lease liabilities during the three months ended December 31, 2020.

The following table presents the balance and classifications of the Company's right of use assets and lease liabilities included in the Unaudited Condensed Consolidated Balance Sheets:

(Thousands)	Balance Sheet Location	December 31, 2021		September 30, 2021
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	173,617	$	173,928
Finance lease assets	Utility plant	23,286		13,489
Total lease assets		$	196,903	$	187,417
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,531	$	4,300
Finance lease liabilities	Current maturities of long-term debt	6,397		5,393
Noncurrent
Operating lease liabilities	Operating lease liabilities	141,356		141,363
Finance lease liabilities	Long-term debt	28,673		14,742
Total lease liabilities		$	180,957	$	165,798

For operating lease assets and liabilities, the weighted average remaining lease term was 29.7 years and 29.6 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.2 percent as of both December 31, 2021 and September 30, 2021.

For finance lease assets and liabilities as of December 31, 2021 and September 30, 2021, the weighted average remaining lease term was 4.7 years and 3.4 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.7 percent and 3.5 percent as of December 31, 2021 and September 30, 2021, respectively.

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COMMITMENTS AND CONTINGENT LIABILITIES

3 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENT LIABILITIES

13. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through November 2038, for the supply, transportation and storage of natural gas. These contracts include annual fixed charges of approximately $191.0 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, the Energy Services segment enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by Energy Services 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 December 31, 2021, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2022		2023		2024		2025		2026		Thereafter
Energy Services:
Natural gas purchases	$	101,257	$	1,857	$	—	$	—	$	—	$	—
Storage demand fees	15,217		12,177		6,698		5,018		2,375		906
Pipeline demand fees	49,519		46,628		22,259		19,131		15,211		18,648
Sub-total Energy Services	$	165,993	$	60,662	$	28,957	$	24,149	$	17,586	$	19,554
NJNG:
Natural gas purchases	$	7,668	$	—	$	—	$	—	$	—	$	—
Storage demand fees	34,738		38,107		17,743		7,740		2,171		1,879
Pipeline demand fees	104,124		144,971		133,176		132,456		125,788		1,121,334
Sub-total NJNG	$	146,530	$	183,078	$	150,919	$	140,196	$	127,959	$	1,123,213
Total	$	312,523	$	243,740	$	179,876	$	164,345	$	145,545	$	1,142,767

Certain pipeline demand fees totaling approximately $4.0 million per year, for which Energy Services is the responsible party, are being paid for by the counterparty to a capacity release transaction beginning November 1, 2021 for a period of 10 years.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of certain former 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 NJDEP regulations.

NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester, Toms River, Freehold and Aberdeen, New Jersey, 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 at the former 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 $115.7 million to $178.7 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of December 31, 2021, NJNG recorded a MGP remediation liability and a corresponding regulatory asset of approximately $126.9 million on the Unaudited Condensed Consolidated Balance Sheets based on the most likely amount. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and insurance recoveries, if any.

In June 2019, NJNG initiated a preliminary assessment of a site in Aberdeen, New Jersey to determine prior ownership and if former MGP operations were active at the location. The preliminary assessment and site investigation activities are ongoing at the Aberdeen, NJ site location. The estimated costs to complete the preliminary assessment and site investigation phase are included in the MGP remediation liability and corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets at December 31, 2021 and September 30, 2021. NJNG will continue to gather information to determine whether the obligation exists to undertake remedial action, if any, and refine its estimate of potential costs for this site as more information becomes available.

NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. On April 7, 2021, the BPU approved an increase in the RAC, which increased the annual recovery from $9.7 million to $11.1 million and was effective May 1, 2021. On September 30, 2021, NJNG filed its annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $2.0 million annually, effective April 1, 2022. As of December 31, 2021, $64.7 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination.

General

The Company is involved, and from time to time in the future may be involved, in a number of pending and threatened judicial, regulatory and arbitration proceedings relating to matters that arise in the ordinary course of business. In view of the inherent difficulty of predicting the outcome of litigation matters, particularly when such matters are in their early stages or where the claimants seek indeterminate damages, the Company cannot state with confidence what the eventual outcome of the pending litigation will be, what the timing of the ultimate resolution of these matters will be, or what the eventual loss, fines or penalties related to each pending matter will be, if any. In accordance with applicable accounting guidance, the Company establishes accruals for litigation for those matters that present loss contingencies as to which it is both probable that a loss will be incurred and the amount of such loss can be reasonably estimated. The Company also discloses contingent matters for which there is a reasonable possibility of a loss. Based upon currently available information, the Company believes that the results of litigation that are currently pending, taken together, will not have a materially adverse effect on the Company’s financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts accrued.

The foregoing statements about the Company’s litigation are based upon the Company’s judgments, assumptions and estimates and are necessarily subjective and uncertain. The Company has a number of threatened and pending litigation matters at various stages.

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REPORTING SEGMENT AND OTHER OPERATIONS DATA

3 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

REPORTING SEGMENT AND OTHER OPERATIONS DATA

14. REPORTING SEGMENT AND OTHER OPERATIONS DATA

The Company 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 reporting 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 and retail energy operations; the Storage and Transportation segment consists of the Company’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, other investments and general corporate activities.

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues
Natural Gas Distribution
External customers	$	274,435	$	195,729
Intercompany	337		—
Clean Energy Ventures
External customers	10,183		6,370
Energy Services
External customers (1)	365,788		227,349
Intercompany	3,456		2,128
Storage and Transportation
External customers	11,584		12,447
Intercompany	559		657
Subtotal	666,342		444,680
Home Services and Other
External customers	13,852		12,410
Intercompany	99		167
Eliminations	(4,451)		(2,952)
Total	$	675,842	$	454,305
Depreciation and amortization
Natural Gas Distribution	$	22,893	$	19,169
Clean Energy Ventures	5,233		5,433
Energy Services (2)	28		42
Storage and Transportation	2,133		2,640
Subtotal	30,287		27,284
Home Services and Other	204		260
Eliminations	(98)		(182)
Total	$	30,393	$	27,362
Interest income (3)
Natural Gas Distribution	$	193	$	82
Storage and Transportation	377		694
Subtotal	570		776
Home Services and Other	155		132
Eliminations	(224)		(239)
Total	$	501	$	669

(1)Includes sales to Canada for the Energy Services segment, which are immaterial.

(2)The amortization of acquired wholesale energy contracts is excluded above and is included in natural gas purchases - nonutility on the Unaudited Condensed Consolidated Statements of Operations.

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Interest expense, net of capitalized interest
Natural Gas Distribution	$	10,995	$	8,974
Clean Energy Ventures	5,427		5,034
Energy Services	675		680
Storage and Transportation	2,136		3,982
Subtotal	19,233		18,670
Home Services and Other	244		1,116
Total	$	19,477	$	19,786
Income tax provision (benefit)
Natural Gas Distribution	$	13,204	$	8,367
Clean Energy Ventures	(2,046)		(3,086)
Energy Services	20,505		12,122
Storage and Transportation	343		646
Subtotal	32,006		18,049
Home Services and Other	246		118
Eliminations	(1,445)		(726)
Total	$	30,807	$	17,441
Equity in earnings (loss) of affiliates
Storage and Transportation	$	1,056	$	3,193
Eliminations	(481)		(518)
Total	$	575	$	2,675
Net financial earnings (loss)
Natural Gas Distribution	$	51,080	$	49,467
Clean Energy Ventures	(6,821)		(10,274)
Energy Services	17,567		1,500
Storage and Transportation	2,962		3,508
Subtotal	64,788		44,201
Home Services and Other	447		(62)
Eliminations	535		518
Total	$	65,770	$	44,657
Capital expenditures
Natural Gas Distribution	$	73,464	$	79,246
Clean Energy Ventures	25,380		22,335
Storage and Transportation	65,375		7,613
Subtotal	164,219		109,194
Home Services and Other	79		686
Total	$	164,298	$	109,880
Investments in equity investees
Storage and Transportation	$	—	$	286
Total	$	—	$	286

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

(Thousands)	December 31, 2021		September 30, 2021
Assets at end of period:
Natural Gas Distribution	$	3,861,240	$	3,707,461
Clean Energy Ventures	937,696		914,788
Energy Services	393,744		365,423
Storage and Transportation	928,653		862,407
Subtotal	6,121,333		5,850,079
Home Services and Other	148,368		162,134
Intercompany assets (1)	(288,544)		(289,935)
Total	$	5,981,157	$	5,722,278

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

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Net financial earnings	$	65,770	$	44,657
Less:
Unrealized (gain) on derivative instruments and related transactions	(82,191)		(37,491)
Tax effect	19,536		8,913
Effects of economic hedging related to natural gas inventory	23,577		(7,532)
Tax effect	(5,603)		1,790
NFE tax adjustment	(861)		(2,068)
Net income	$	111,312	$	81,045

The Company uses derivative instruments as economic hedges of purchases and sales of physical natural 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 natural gas related to physical natural gas flow are recognized when the natural gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical natural gas flows. Timing differences occur in two ways:

•unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical natural 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 natural 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 natural 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. 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 natural gas flows. NFE also excludes impairment charges associated with equity method investments, which are non-cash charges considered unusual in nature that occur infrequently and are not indicative of the Company's performance for its ongoing operations. Included in the tax effects are current and deferred income tax expense corresponding with the components of NFE. The Company also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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RELATED PARTY TRANSACTIONS

3 Months Ended

Dec. 31, 2021

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

15. RELATED PARTY TRANSACTIONS

Effective April 1, 2020, NJNG entered into a 5-year agreement for 3 Bcf of firm storage capacity with Steckman Ridge, which expires on March 31, 2025. 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.

Energy Services may periodically enter into storage or park and loan agreements with its affiliated FERC-jurisdictional natural gas storage facility, Steckman Ridge. As of December 31, 2021, Energy Services has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2022.

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Natural Gas Distribution	$	1,558	$	1,568
Energy Services	288		166
Total	$	1,846	$	1,734

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

(Thousands)	December 31, 2021		September 30, 2021
Natural Gas Distribution	$	775	$	778
Energy Services	76		83
Total	$	851	$	861

NJNG and Energy Services have entered into various AMAs, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. As of December 31, 2021, NJNG and Energy Services had one AMA with an expiration date of March 31, 2022.

NJNG has entered into a 5-year transportation precedent agreement with Adelphia Gateway for committed capacity of 130,000 Dths per day, which is expected to begin during the 3rd quarter of fiscal 2022, dependent upon the completion of a compressor.

Energy Services has a 5-year agreement for 3 Bcf of firm storage capacity with Leaf River, which is eliminated in consolidation and expires in March 2024.

In March 2021, NJNG and Clean Energy Ventures entered into a 15-year sublease and PPA agreement related to an onsite solar array and the related energy output at the Company’s headquarters in Wall, New Jersey, the effects of which are immaterial to the consolidated financial statements.

In July 2021, NJNG entered into 16-year lease agreements with various NJR subsidiaries for office space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

3 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Consolidation

The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by the Company in accordance with the rules and regulations of the SEC and GAAP. The September 30, 2021 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 the Company's 2021 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 the Company'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, 2022. Intercompany transactions and accounts have been eliminated.

Use of Estimates

Use of Estimates

The preparation of financial statements in conformity with GAAP requires the Company to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosure of contingencies during the reporting period. On a quarterly basis or more frequently whenever events or changes in circumstances indicate a need, the Company evaluates its estimates, including those related to the calculation of the fair value of derivative instruments, debt, equity method investments, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, long-lived assets, regulatory assets and liabilities, income taxes, pensions and other postemployment benefits, contingencies related to environmental matters and litigation. Asset retirement obligations are evaluated as often as needed. The Company’s estimates are based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources.

The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.

Revenues

Revenues

Revenues from the sale of natural gas to NJNG customers are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for unbilled revenue. NJNG records unbilled revenue for natural gas services. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the month. At the end of each month, the amount of natural gas delivered to each customer after the last meter reading through the end of the respective accounting period is estimated, and recognizes unbilled revenues related to these amounts. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects, unaccounted-for natural gas and the most current tariff rates.

Clean Energy Ventures recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the transfer of certificates as per contractual settlement schedules. The Clean Energy Act of 2018 established guidelines for the closure of the SREC registration program to new applicants in New Jersey. The SREC program officially closed to new qualified solar projects on April 30, 2020.

In December 2019, the BPU established the TREC as the successor to the SREC program. TRECs provide a fixed compensation base multiplied by an assigned project factor in order to determine their value. The project factor is determined by the type and location of the project, as defined. All TRECs generated are required to be purchased monthly by a TREC program administrator as appointed by the BPU.

In June 2020, Clean Energy Ventures began generating TRECs for qualified new residential and commercial solar projects placed into service following the close of the SREC program. TREC revenue is recognized when TRECs are generated and are transferred monthly based upon metered solar electricity activity.

Revenues for Energy Services are recognized when the natural gas is physically delivered to the customer. In addition, changes in the fair value of derivatives that economically hedge the forecasted sales of the natural gas are recognized in operating revenues as they occur, as noted above. Energy Services also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues.

During December 2020, Energy Services entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts, which commenced on November 1, 2021. The AMAs include a series of temporary and permanent releases and revenue under these agreements is recognized as the performance obligations are satisfied. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis

over the agreed upon term. For permanent releases of pipeline capacity, which represent a transfer of contractual rights for such capacity, revenue is recognized upon the transfer of the underlying contractual rights. During the three months ended December 31, 2021, Energy Services recognized $22.1 million of operating revenue on the Unaudited Condensed Consolidated Statements of Operations. Amounts received in excess of revenue totaling $64.7 million are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets.

The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, related usage fees and hub services for the use of storage space, injections and withdrawals from their natural gas storage facility and the delivery of natural gas to customers. Demand fees are recognized as revenue over the term of the related agreement while usage fees and hub services revenues are recognized as services are performed.

Revenues from all other activities are recorded in the period during which products or services are delivered and accepted by customers, or over the related contractual term. See Note 3. Revenue for further information.

Cash and Cash Equivalents

Cash and Cash Equivalents

Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to irrevocable letters of credit at Leaf River and escrow balances for utility plant projects at NJNG, which are recorded in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets, respectively.

Allowance for Doubtful Accounts

Allowance for Doubtful Accounts

The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations, and macroeconomic factors, such as unemployment rates among others, including the estimated impact of the ongoing pandemic on the outstanding balances.

In December 2021, the Company deferred a portion of costs incurred related to bad debt for NJNG associated with customer accounts receivable as a regulatory asset resulting from the impacts of the ongoing COVID-19 pandemic. See Note 4. Regulation for additional information.

Loans Receivable

Loans ReceivableNJNG currently 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 fair value on the Unaudited Condensed Consolidated Balance Sheets.

Software Costs

Software CostsThe Company capitalizes certain costs, such as software design and configuration, coding, testing and installation, that are incurred to purchase or create and implement computer software for internal use. Capitalized costs include external costs of materials and services utilized in developing or obtaining internal-use software and payroll and payroll-related costs for employees who are directly associated with and devote time to the internal-use software project. Maintenance costs are expensed as incurred. Upgrades and enhancements are capitalized if it is probable that such expenditures will result in additional functionality. Amortization is recorded on the straight-line basis over the estimated useful lives.

Sale Leasebacks

Sale Leasebacks

NJNG utilizes sale leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease or repurchase the asset at the end of the term. Proceeds from sale leaseback transactions are accounted for as financing arrangements and are included in long-term debt on the Unaudited Condensed Consolidated Balance Sheets. NJNG received $17.3 million during the three months ended December 31, 2021, in connection with the sale leaseback of its natural gas meters. There were no natural gas meter sale leasebacks recorded during the three months ended December 31, 2020.

In addition, for certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third parties and the concurrent leaseback of the assets. For sale leaseback transactions where the Company has concluded that the arrangement does not qualify as a sale as the Company retains control of the underlying assets and, as such, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the buyer-lessor that constitute a payment to acquire the

solar energy asset as a financing arrangement, which is recorded as a component of debt on the Unaudited Condensed Consolidated Balance Sheets.

The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from RECs and energy sales. The ITCs and other tax benefits associated with these solar projects transfer to the buyer; however, the payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax attributes. Accordingly, Clean Energy Ventures recognizes the equivalent value of the tax attributes in other income on the Unaudited Condensed Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease.

During the three months ended December 31, 2021 and 2020, Clean Energy Ventures received proceeds of $3.3 million and $12.1 million, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets.

Recently Adopted Updates to the Accounting Standards Codification

Recently Adopted Updates to the Accounting Standards Codification

Income Taxes

In December 2019, the FASB issued ASU No. 2019-12, an amendment to ASC 740, Income Taxes, which simplifies the accounting for income taxes and changes the accounting for certain income tax transactions, among other minor improvements. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. The amendments in this update were either not applicable, currently applied, or did not have a material impact on the Company's financial position, results of operations, cash flows or disclosures.

Investments - Equity Securities, Investments - Equity Method and Joint Ventures and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, an amendment to ASC 321, Investments - Equity Securities, ASC 323, Investments - Equity Method and Joint Ventures, and ASC 815, Derivatives and Hedging, which clarifies the interactions between the three ASU topics. The update requires an entity to evaluate observable transactions that necessitate applying or discontinuing the equity method of accounting when applying the measurement alternative in Topic 321. This evaluation occurs prior to applying or upon ceasing the equity method. The update also states that when applying paragraph 815-10-15-141(a) for

forward contracts and purchased options, an entity is not required to assess whether the underlying securities will be accounted for under the equity method in accordance with Topic 323 or fair value method under Topic 825 upon settlement or exercise. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures.

Other

In October 2020, the FASB issued ASU No. 2020-10, Codification Improvements, which clarifies application of various provisions in the ASC by amending and adding new headings, cross referencing to other guidance, and refining or correcting terminology. It also improves the consistency by amending the ASC to include all disclosure guidance in the appropriate section. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures.

Other Recent Updates to the Accounting Standards Codification

Debt and Other

In August 2020, the FASB issued ASU No. 2020-06, an amendment to ASC 470, Debt, and ASC 815, Derivatives and Hedging, which changes the accounting for convertible instruments by reducing the number of acceptable accounting models to three models including, the embedded derivative, substantial premium, and traditional no proceeds allocated models. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it on either a modified or a full retrospective basis. The Company does not currently have convertible debt instruments and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption.

In May 2021, the FASB issued ASU No. 2021-04, an amendment to ASC 470, Debt, ASC 260, Earnings per Share, ASC 718, Stock Compensation, and ASC 815, Derivatives and Hedging. The update impacts equity-classified written call options that remain equity-classified after a modification or exchange. The guidance is effective for the Company beginning October 1, 2022, and will be applied on a prospective basis. The Company does not currently have equity-classified written call options and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Leases

In July 2021, the FASB issued ASU No. 2021-05, an amendment to ASC 842, Leases, which requires a lessor to classify a lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another classification, including sales-type or direct financing would trigger a loss at the lease commencement date. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it either on a retrospective basis to leases that have commenced or have been modified under ASC 842 or on a prospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Business Combinations

In October 2021, the FASB issued ASU No. 2021-08, an amendment to ASC 805, Business Combinations, which requires that an acquirer recognize, and measure contract assets and contract liabilities acquired in a business combination in accordance with Topic 606, Revenue from Contracts with Customers. The guidance is effective for the Company beginning October 1, 2023, and will be applied on a prospective basis to new acquisitions following the date of adoption. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Derivative Instruments

The Company is subject primarily 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 is exposed to foreign currency and interest rate risk and may utilize foreign currency derivatives to hedge Canadian dollar denominated natural gas purchases and/or sales and interest rate derivatives to reduce exposure to fluctuations in interest rates. All of these types of contracts are accounted for as derivatives, unless the Company elects NPNS, which is done on a contract-by-contract election. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company’s fair value measurement policies and level disclosures associated with the Company’s derivative instruments, see Note 6. Fair Value.

Energy Services

Energy Services 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 natural gas purchases or operating revenues, as appropriate for Energy Services, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of natural 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 natural gas purchases or operating revenues.

Energy Services 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. Energy Services may utilize foreign currency derivatives to lock in the exchange rates 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 natural gas purchase agreements.

As a result of Energy Services 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 natural 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. Energy Services 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.

Natural Gas Distribution

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 a portfolio basis. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as 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 natural 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.

Clean Energy Ventures

The Company elects NPNS accounting treatment on PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to do so, the Company can and may elect to treat certain contracts as normal.

Fair Value Hierarchy

Fair Value Hierarchy

The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, investments in equity 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 1Unadjusted quoted prices for identical assets or liabilities in active markets. The Company'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 the Company refers to internally as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM.

Level 2Other 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. The Company'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). 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 3Inputs derived from a significant amount of unobservable market data. These include the Company's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

Lessee Accounting

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases.

The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of its natural gas meters.

Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns.

Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five to 20 years. The Company’s office leases vary in duration, ranging from two to 17 years and may or may not include extension or early purchase options. The Company’s meter lease terms are between seven and ten years with purchase options available prior to the end of the term. Equipment leases include general office equipment that also vary in duration, with an average term of six years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The Company has elected an accounting policy that exempts leases with an original term of one year or less from the recognition requirements of ASC 842, Leases.

The Company has lease agreements with lease and non-lease components and has elected the practical expedient to combine lease and non-lease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not considered material to the Company. The Company’s lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

3 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Schedule of Restricted Cash

The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Unaudited Condensed Consolidated Balance Sheets to the total amounts in the Unaudited Condensed Consolidated Statements of Cash Flows as follows:

(Thousands)	December 31, 2021		September 30, 2021		December 31, 2020
Balance Sheet
Cash and cash equivalents	$	1,259	$	4,749	$	22,358
Restricted cash in other noncurrent assets	$	1,294	$	1,294	$	2,431
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	2,553	$	6,043	$	24,789

Summary of Natural Gas in Storage

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

	December 31, 2021				September 30, 2021
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	110,673	22.7		$	115,824	27.6
Energy Services		132,019		28.9		77,782		18.8
Total		$	242,692	51.6		$	193,606	46.4

Schedule of Software Costs Included in the Consolidated Financial Statements

The following tables present the software costs included in the Unaudited Condensed Consolidated Financial Statements:

(Thousands)	December 31, 2021		September 30, 2021
Balance Sheets
Utility plant, at cost	$	16,777	$	16,543
Construction work in progress	$	11,725	$	7,801
Nonutility plant and equipment, at cost	$	341	$	338
Construction work in progress	$	1	$	8
Accumulated depreciation and amortization, utility plant	$	(1,644)	$	(1,333)
Accumulated depreciation and amortization, nonutility plant and equipment	$	(16)	$	(29)
Software costs	$	5,464	$	5,582

	Three Months Ended
	December 31,
Statements of Operations	2021		2020
Operation and maintenance (1)	$	2,523	$	1,924
Depreciation and amortization	$	299	$	253

(1)During the three months ended December 31, 2021 and 2020, approximately $113,000 and $77,000, respectively, was amortized from software costs into O&M.

Schedule of Accumulated Other Comprehensive Income (Loss)

The following table presents the changes in the components of accumulated other comprehensive (loss) income, net of related tax effects during the three months ended December 31, 2021 and 2020:

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2021	$	(9,376)	$	(25,152)		$	(34,528)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive loss, net of tax of $(79), $(233), $(312), respectively	264		766		(1)	1,030
Balance at December 31, 2021	$	(9,112)	$	(24,386)		$	(33,498)
Balance at September 30, 2020	$	(10,397)	$	(33,918)		$	(44,315)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive loss, net of tax of $(112), $(245) and $(357)	231		812		(1)	1,043
Balance at December 31, 2020	$	(10,166)	$	(33,106)		$	(43,272)

(1)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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REVENUE (Tables)

3 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

Performance obligation, recognition period

Below is a listing of performance obligations that arise from contracts with customers, along with details on the satisfaction of each performance obligation, the significant payment terms and the nature of the goods and services being transferred, by reporting segment and other business operations:

Revenue Recognized Over Time:
Segment	Performance Obligation	Description
Natural Gas Distribution	Natural gas utility sales	NJNG's performance obligation is to provide natural gas to residential, commercial and industrial customers as demanded, based on regulated tariff rates, which are established by the BPU. Revenues from the sale of natural gas are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for quantities consumed but not billed during the period. Payment is due each month for the previous month's deliveries. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the billing period. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects and the most current tariff rates. NJNG is entitled to be compensated for performance completed until service is terminated. Customers may elect to purchase the natural gas commodity from NJNG or may contract separately to purchase natural gas directly from third-party suppliers. As NJNG is acting as an agent on behalf of the third-party supplier, revenue is recorded for the delivery of natural gas to the customer.
Clean Energy Ventures	Commercial solar electricity	Clean Energy Ventures operates wholly-owned solar projects that recognize revenue as electricity is generated and transferred to the customer. The performance obligation is to provide electricity to the customer in accordance with contract terms or the interconnection agreement and is satisfied upon transfer of electricity generated. Revenue is recognized as invoiced and the payment is due each month for the previous month's services.
Clean Energy Ventures	Residential solar electricity	Clean Energy Ventures provides access to residential rooftop and ground-mount solar equipment to customers who then pay the Company a monthly fee. The performance obligation is to provide electricity to the customer based on generation from the underlying residential solar asset and is satisfied upon transfer of electricity generated. Revenue is derived from the contract terms and is recognized as invoiced, with the payment due each month for the previous month's services.
Clean Energy Ventures	Transition renewable energy certificates	Clean Energy Ventures generates TRECs, which are created for every MWh of electricity produced by a solar generator. The performance obligation of Clean Energy Ventures is to generate electricity and TRECs, which are purchased monthly by a REC Administrator. Revenue is recognized upon generation.
Energy Services	Natural gas services	The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers in line with the terms of the contract and based on the services provided. Payment is due upon receipt of the invoice. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed upon term.
Storage and Transportation	Natural gas services	The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as customers receive the benefits of its service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement.
Home Services and Other	Service contracts	Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice.

Revenue Recognized at a Point in Time:
Energy Services	Natural gas services	For a permanent release of pipeline capacity, the performance obligation of NJRES is the release of the pipeline capacity associated with certain natural gas transportation contracts and the transfer of the underlying contractual rights to the counterparty. Revenue is recognized upon the transfer of the underlying contractual rights.
Storage and Transportation	Natural gas services	The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from usage fees and hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Usage fees and hub services revenues are recognized as services are performed.
Home Services and Other	Installations	Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators to customers. The distinct performance obligation is the installation of the contracted appliance, which is satisfied at the point in time the item is installed. The transaction price for each installation differs accordingly. Revenue is recognized at a point in time upon completion of the installation, which is when the customer is billed.

Disaggregation of Revenue

Disaggregated revenues from contracts with customers by product line and by reporting segment and other business operations during the three months ended December 31, 2021 and 2020, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales (1)	$	223,796	—		—	—	—	$	223,796
Natural gas services	—		—		27,879	12,143	—	40,022
Service contracts	—		—		—	—	8,467	8,467
Installations and maintenance	—		—		—	—	5,484	5,484
Renewable energy certificates	—		846		—	—	—	846
Electricity sales	—		6,470		—	—	—	6,470
Eliminations (2	(337)		—		—	(559)	(99)	(995)
Revenues from contracts with customers	223,459		7,316		27,879	11,584	13,852	284,090
Alternative revenue programs (3)	10,654		—		—	—	—	10,654
Derivative instruments	40,322		2,867	(4)	341,365	—	—	384,554
Eliminations (2)	—		—		(3,456)	—	—	(3,456)
Revenues out of scope	50,976		2,867		337,909	—	—	391,752
Total operating revenues	$	274,435	10,183		365,788	11,584	13,852	$	675,842
2020
Natural gas utility sales	$	189,364	—		—	—	—	$	189,364
Natural gas services	—		—		6,428	13,104	—	19,532
Service contracts	—		—		—	—	8,259	8,259
Installations and maintenance	—		—		—	—	4,318	4,318
Renewable energy certificates	—		690		—	—	—	690
Electricity sales	—		4,388		—	—	—	4,388
Eliminations (1)	—		—		—	(657)	(167)	(824)
Revenues from contracts with customers	189,364		5,078		6,428	12,447	12,410	225,727
Alternative revenue programs (3)	1,568		—		—	—	—	1,568
Derivative instruments	4,797		1,292	(4)	223,049	—	—	229,138
Eliminations (2)	—		—		(2,128)	—	—	(2,128)
Revenues out of scope	6,365		1,292		220,921	—	—	228,578
Total operating revenues	$	195,729	6,370		227,349	12,447	12,410	$	454,305

(1)Includes building rent related to the Wall headquarters, which is eliminated in consolidation.

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

(3)Includes CIP revenue.

(4)Includes SREC revenue.

Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the three months ended December 31, 2021 and 2020, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	151,308	2,972	—	—	13,775	$	168,055
Commercial and industrial	47,184		4,344	27,879	11,584	77	91,068
Firm transportation	22,675		—	—	—	—	22,675
Interruptible and off-tariff	2,292		—	—	—	—	2,292
Revenues out of scope	50,976		2,867	337,909	—	—	391,752
Total operating revenues	$	274,435	10,183	365,788	11,584	13,852	$	675,842
2020
Residential	$	137,224	2,722	—	—	12,204	$	152,150
Commercial and industrial	29,229		2,356	6,428	12,447	206	50,666
Firm transportation	21,104		—	—	—	—	21,104
Interruptible and off-tariff	1,807		—	—	—	—	1,807
Revenues out of scope	6,365		1,292	220,921	—	—	228,578
Total operating revenues	$	195,729	6,370	227,349	12,447	12,410	$	454,305

Expected Timing of Performance

The timing of revenue recognition, customer billings and cash collections resulting in accounts receivables, billed and unbilled, and customers’ credit balances and deposits on the Unaudited Condensed Consolidated Balance Sheets during the three months ended December 31, 2021 and 2020, are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of September 30, 2021	$	212,838	$	10,351	$	32,586
Increase	53,977		62,598		6,080
Balance as of December 31, 2021	$	266,815	$	72,949	$	38,666
Balance as of September 30, 2020	$	134,173	$	9,226	$	25,934
Increase	63,468		44,568		7,014
Balance as of December 31, 2020	$	197,641	$	53,794	$	32,948

Performance obligation, in excess of billings

The following table provides information about receivables, which are included within accounts receivable, billed and unbilled, and customers’ credit balances and deposits, respectively, on the Unaudited Condensed Consolidated Balance Sheets as of December 31, 2021 and September 30, 2021:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
December 31, 2021
Customer accounts receivable
Billed	$	102,890	4,608	153,014	4,339	1,964	$	266,815
Unbilled	71,542		1,407	—	—	—	72,949
Customers' credit balances and deposits	(38,666)		—	—	—	—	(38,666)
Total	$	135,766	6,015	153,014	4,339	1,964	$	301,098
September 30, 2021
Customer accounts receivable
Billed	$	54,514	5,534	147,087	3,956	1,747	$	212,838
Unbilled	8,427		1,924	—	—	—	10,351
Customers' credit balances and deposits	(32,586)		—	—	—	—	(32,586)
Total	$	30,355	7,458	147,087	3,956	1,747	$	190,603

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REGULATION (Tables)

3 Months Ended

Dec. 31, 2021

Regulated Operations [Abstract]

Schedule of Regulator Liabilities

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

(Thousands)	December 31, 2021		September 30, 2021
Regulatory assets-current
New Jersey Clean Energy Program	$	14,416	$	16,308
Conservation Incentive Program	22,493		11,839
Other current regulatory assets	1,371		1,554
Total current regulatory assets	$	38,280	$	29,701
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	64,662	$	58,483
Liability for future expenditures	126,881		135,012
Deferred income taxes	39,613		39,694
SAVEGREEN	37,342		32,941
Postemployment and other benefit costs	114,515		117,194
Deferred storm damage costs	3,800		4,343
Cost of removal	99,160		99,238
Other noncurrent regulatory assets	38,685		32,695
Total noncurrent regulatory assets	$	524,658	$	519,600
Regulatory liability-current
Overrecovered natural gas costs	$	11,659	$	5,510
Derivatives at fair value, net	7,340		22,497
Total current regulatory liabilities	$	18,999	$	28,007
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	189,131	$	190,386
Derivatives at fair value, net	—		1,166
Other noncurrent regulatory liabilities	688		336
Total noncurrent regulatory liabilities	$	189,819	$	191,888

(1)Reflects the re-measurement and subsequent amortization of NJNG's net deferred tax liabilities as a result of the change in federal tax rates enacted in the Tax Act.

At December 31, 2021, other noncurrent regulatory assets include deferred pandemic costs of $10.7 million primarily related to a portion of bad debt associated with customer accounts receivable resulting from the impacts of the ongoing COVID-19 pandemic. These costs are eligible for future regulatory recovery.

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

(Thousands)	December 31, 2021		September 30, 2021
Total current regulatory assets	$	373	$	417
Total noncurrent regulatory assets	$	3,416	$	2,499
Total noncurrent regulatory liabilities	$	895	$	1,163

Schedule of Regulatory Assets

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

(Thousands)	December 31, 2021		September 30, 2021
Regulatory assets-current
New Jersey Clean Energy Program	$	14,416	$	16,308
Conservation Incentive Program	22,493		11,839
Other current regulatory assets	1,371		1,554
Total current regulatory assets	$	38,280	$	29,701
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	64,662	$	58,483
Liability for future expenditures	126,881		135,012
Deferred income taxes	39,613		39,694
SAVEGREEN	37,342		32,941
Postemployment and other benefit costs	114,515		117,194
Deferred storm damage costs	3,800		4,343
Cost of removal	99,160		99,238
Other noncurrent regulatory assets	38,685		32,695
Total noncurrent regulatory assets	$	524,658	$	519,600
Regulatory liability-current
Overrecovered natural gas costs	$	11,659	$	5,510
Derivatives at fair value, net	7,340		22,497
Total current regulatory liabilities	$	18,999	$	28,007
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	189,131	$	190,386
Derivatives at fair value, net	—		1,166
Other noncurrent regulatory liabilities	688		336
Total noncurrent regulatory liabilities	$	189,819	$	191,888

(1)Reflects the re-measurement and subsequent amortization of NJNG's net deferred tax liabilities as a result of the change in federal tax rates enacted in the Tax Act.

At December 31, 2021, other noncurrent regulatory assets include deferred pandemic costs of $10.7 million primarily related to a portion of bad debt associated with customer accounts receivable resulting from the impacts of the ongoing COVID-19 pandemic. These costs are eligible for future regulatory recovery.

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

(Thousands)	December 31, 2021		September 30, 2021
Total current regulatory assets	$	373	$	417
Total noncurrent regulatory assets	$	3,416	$	2,499
Total noncurrent regulatory liabilities	$	895	$	1,163

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DERIVATIVE INSTRUMENTS (Tables)

3 Months Ended

Dec. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Assets and Liabilities

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

			Derivatives at Fair Value
			December 31, 2021						September 30, 2021
(Thousands)	Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	234		$	4		$	36		$	16
Financial commodity contracts	Derivatives - current		5,032			240			2,046			13
Energy Services:
Physical commodity contracts	Derivatives - current		2,285			18,592			2,818			24,592
	Derivatives - noncurrent		135			15,261			333			13,237
Financial commodity contracts	Derivatives - current		32,164			11,209			30,226			62,521
	Derivatives - noncurrent		1,843			—			3,068			260
Foreign currency contracts	Derivatives - current		68			4			125			3
	Derivatives - noncurrent		—			—			2			—
Total fair value of derivatives			$	41,761		$	45,310		$	38,654		$	100,642

Offsetting Assets

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

(Thousands)	Amounts Presented on Balance Sheets (1)			Offsetting Derivative Instruments (2)			Financial Collateral Received/Pledged (3)			Net Amounts (4)
As of December 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	2,420		$	(908)		$	(200)		$	1,312
Financial commodity contracts		34,007			(9,247)			—			24,760
Foreign currency contracts		68			(4)			—			64
Total Energy Services		$	36,495		$	(10,159)		$	(200)		$	26,136
Natural Gas Distribution
Physical commodity contracts		$	234		$	—		$	—		$	234
Financial commodity contracts		5,032			(240)			—			4,792
Total Natural Gas Distribution		$	5,266		$	(240)		$	—		$	5,026
Derivative liabilities:
Energy Services
Physical commodity contracts		$	33,853		$	(908)		$	—		$	32,945
Financial commodity contracts		11,209			(9,247)			—			1,962
Foreign currency contracts		4			(4)			—			—
Total Energy Services		$	45,066		$	(10,159)		$	—		$	34,907
Natural Gas Distribution
Physical commodity contracts		$	4		$	—		$	—		$	4
Financial commodity contracts		240			(240)			—			—
Total Natural Gas Distribution		$	244		$	(240)		$	—		$	4
As of September 30, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	3,151		$	(894)		$	(700)		$	1,557
Financial commodity contracts		33,294			(33,294)			20,532			20,532
Foreign currency contracts		127			(3)						124
Total Energy Services		$	36,572		$	(34,191)		$	19,832		$	22,213
Natural Gas Distribution
Physical commodity contracts		$	36		$	(8)		$	—		$	28
Financial commodity contracts		2,046			(13)			—			2,033
Total Natural Gas Distribution		$	2,082		$	(21)		$	—		$	2,061
Derivative liabilities:
Energy Services
Physical commodity contracts		$	37,829		$	(894)		$	—		$	36,935
Financial commodity contracts		62,781			(33,294)			—			29,487
Foreign currency contracts		3			(3)			—			—
Total Energy Services		$	100,613		$	(34,191)		$	—		$	66,422
Natural Gas Distribution
Physical commodity contracts		$	16		$	(8)		$	—		$	8
Financial commodity contracts		13			(13)			—			—
Total Natural Gas Distribution		$	29		$	(21)		$	—		$	8

(1)Derivative assets and liabilities are presented on a gross basis on 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 the Company has the right to offset but elects not to, financial collateral, as well as the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(Thousands)	Amounts Presented on Balance Sheets (1)			Offsetting Derivative Instruments (2)			Financial Collateral Received/Pledged (3)			Net Amounts (4)
As of December 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	2,420		$	(908)		$	(200)		$	1,312
Financial commodity contracts		34,007			(9,247)			—			24,760
Foreign currency contracts		68			(4)			—			64
Total Energy Services		$	36,495		$	(10,159)		$	(200)		$	26,136
Natural Gas Distribution
Physical commodity contracts		$	234		$	—		$	—		$	234
Financial commodity contracts		5,032			(240)			—			4,792
Total Natural Gas Distribution		$	5,266		$	(240)		$	—		$	5,026
Derivative liabilities:
Energy Services
Physical commodity contracts		$	33,853		$	(908)		$	—		$	32,945
Financial commodity contracts		11,209			(9,247)			—			1,962
Foreign currency contracts		4			(4)			—			—
Total Energy Services		$	45,066		$	(10,159)		$	—		$	34,907
Natural Gas Distribution
Physical commodity contracts		$	4		$	—		$	—		$	4
Financial commodity contracts		240			(240)			—			—
Total Natural Gas Distribution		$	244		$	(240)		$	—		$	4
As of September 30, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	3,151		$	(894)		$	(700)		$	1,557
Financial commodity contracts		33,294			(33,294)			20,532			20,532
Foreign currency contracts		127			(3)						124
Total Energy Services		$	36,572		$	(34,191)		$	19,832		$	22,213
Natural Gas Distribution
Physical commodity contracts		$	36		$	(8)		$	—		$	28
Financial commodity contracts		2,046			(13)			—			2,033
Total Natural Gas Distribution		$	2,082		$	(21)		$	—		$	2,061
Derivative liabilities:
Energy Services
Physical commodity contracts		$	37,829		$	(894)		$	—		$	36,935
Financial commodity contracts		62,781			(33,294)			—			29,487
Foreign currency contracts		3			(3)			—			—
Total Energy Services		$	100,613		$	(34,191)		$	—		$	66,422
Natural Gas Distribution
Physical commodity contracts		$	16		$	(8)		$	—		$	8
Financial commodity contracts		13			(13)			—			—
Total Natural Gas Distribution		$	29		$	(21)		$	—		$	8

(1)Derivative assets and liabilities are presented on a gross basis on 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 presents the effect of derivative instruments recognized on the Unaudited Condensed Consolidated Statements of Operations for the periods set forth below:

(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended
		December 31,
Derivatives not designated as hedging instruments:		2021		2020
Energy Services:
Physical commodity contracts	Operating revenues	$	150	$	5,252
Physical commodity contracts	Natural gas purchases	1,505		(5,054)
Financial commodity contracts	Natural gas purchases	61,189		47,755
Foreign currency contracts	Natural gas purchases	—		200
Total unrealized and realized loss		$	62,844	$	48,153

Effect of Derivative Instruments Designated as Cash Flow Hedges on OCI

The following table reflects the gains (losses) associated with NJNG's derivative instruments for the periods set forth below:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Natural Gas Distribution:
Physical commodity contracts	$	1,696	$	342
Financial commodity contracts	(14,647)		(4,272)
Total unrealized and realized (loss)	$	(12,951)	$	(3,930)

Schedule of Outstanding Long (Short) Derivatives

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

		Volume (Bcf)
	Transaction Type	December 31, 2021	September 30, 2021
Natural Gas Distribution	Futures	24.0	22.2
	Physical Commodity	1.5	7.6
Energy Services	Futures	(22.0)	(13.4)
	Swaps	(0.2)	(0.3)
	Physical Commodity	(4.9)	0.6

Schedule of Broker Margin Accounts by Company

The balances are as follows:

(Thousands)	Balance Sheet Location	December 31, 2021		September 30, 2021
Natural Gas Distribution	Restricted broker margin accounts-current assets	$	5,358	$	2,790
Energy Services	Restricted broker margin accounts-current assets	$	37,358	$	70,050
	Restricted broker margin accounts-current liabilities	$	(15,475)	$	—

Summary of Gross Credit Exposures

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of December 31, 2021. 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 Clean Energy Ventures residential solar installations.

(Thousands)	Gross Credit Exposure
Investment grade		$	185,828
Noninvestment grade		11,016
Internally rated investment grade		23,742
Internally rated noninvestment grade		30,016
Total		$	250,602

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FAIR VALUE (Tables)

3 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

Fair Value, by Balance Sheet Grouping

The estimated fair value of long-term debt, including current maturities, excluding finance leases, debt issuance costs and solar asset financing obligations, is as follows:

(Thousands)	December 31, 2021		September 30, 2021
Carrying value (1) (2) (3)	$	2,202,845	$	2,102,845
Fair market value	$	2,373,791	$	2,288,544

(1)Excludes finance leases of $35.1 million and $20.1 million as of December 31, 2021 and September 30, 2021, respectively.

(2)Excludes NJNG's debt issuance costs of $10.3 million and $9.1 million as of December 31, 2021 and September 30, 2021, respectively.

(3)Excludes NJR's debt issuance costs of $3.7 million and $3.3 million as of December 31, 2021 and September 30, 2021, respectively.

Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of December 31, 2021:
Assets:
Physical commodity contracts		$	—		$	2,654		$	—	$	2,654
Financial commodity contracts		39,039			—			—		39,039
Financial commodity contracts - foreign exchange		—			68			—		68
Money market funds		41			—			—		41
Other		2,085			—			—		2,085
Total assets at fair value		$	41,165		$	2,722		$	—	$	43,887
Liabilities:
Physical commodity contracts		$	—		$	33,857		$	—	$	33,857
Financial commodity contracts		11,278			171			—		11,449
Financial commodity contracts - foreign exchange		—			4			—		4
Total liabilities at fair value		$	11,278		$	34,032		$	—	$	45,310

	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 September 30, 2021:
Assets:
Physical commodity contracts		$	—		$	3,187		$	—	$	3,187
Financial commodity contracts		35,340			—			—		35,340
Financial commodity contracts - foreign exchange		—			127			—		127
Money market funds		41			—			—		41
Other		1,815			—			—		1,815
Total assets at fair value		$	37,196		$	3,314		$	—	$	40,510
Liabilities:
Physical commodity contracts		$	—		$	37,845		$	—	$	37,845
Financial commodity contracts		62,188			606			—		62,794
Financial commodity contracts - foreign exchange		—			3			—		3
Total liabilities at fair value		$	62,188		$	38,454		$	—	$	100,642

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INVESTMENTS IN EQUITY INVESTEES (Tables)

3 Months Ended

Dec. 31, 2021

Investments, All Other Investments [Abstract]

Schedule of Equity Method Investments

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

(Thousands)	December 31, 2021		September 30, 2021
Steckman Ridge (1)	$	108,770	$	109,050
PennEast	5,479		5,479
Total	$	114,249	$	114,529

(1)Includes loans with a total outstanding principal balance of $70.4 million for both December 31, 2021 and September 30, 2021, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

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EARNINGS PER SHARE (Tables)

3 Months Ended

Dec. 31, 2021

Earnings Per Share [Abstract]

Schedule of Earnings Per Share Basic and Diluted

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

	Three Months Ended
	December 31,
(Thousands, except per share amounts)	2021		2020
Net income, as reported	$	111,312	$	81,045
Basic earnings per share
Weighted average shares of common stock outstanding-basic	95,944		96,114
Basic earnings per common share	$1.16		$0.84
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	95,944		96,114
Incremental shares (1)	412		301
Weighted average shares of common stock outstanding-diluted	96,356		96,415
Diluted earnings per common share (2)(3)	$1.16		$0.84

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

(2)There were anti-dilutive shares of 32,317 excluded from the calculation of diluted earnings per share related to an equity forward sale agreement during the three months ended December 31, 2020.

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DEBT (Tables)

3 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

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

(Thousands)	December 31, 2021			September 30, 2021			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	500,000		$	500,000		September 2026
Notes outstanding at end of period	$	310,550		$	219,100
Weighted average interest rate at end of period	1.13		%	1.05		%
Amount available at end of period (2)	$	169,862		$	270,312
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		September 2026
Commercial paper and notes outstanding at end of period	$	177,400		$	158,200
Weighted average interest rate at end of period	0.55		%	0.17		%
Amount available at end of period (4)	$	71,869		$	91,069

(1)Committed credit facilities, which require commitment fees of 0.10 percent on the unused amounts.

(2)Letters of credit outstanding total $19.6 million at December 31, 2021 and $10.6 million at September 30, 2021, which reduces the amount available by the same amount.

(3)Committed credit facilities, which require commitment fees of 0.075 percent on the unused amounts.

(4)Letters of credit outstanding total $731,000 at both December 31, 2021 and September 30, 2021, which reduces the amount available by the same amount.

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EMPLOYEE BENEFIT PLANS (Tables)

3 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]

Components of Net Periodic Cost

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

	Pension				OPEB
	Three Months Ended				Three Months Ended
	December 31,				December 31,
(Thousands)	2021		2020		2021		2020
Service cost	$	2,073	$	2,182	$	1,076	$	1,211
Interest cost	2,408		2,278		1,589		1,518
Expected return on plan assets	(5,319)		(5,224)		(1,894)		(1,683)
Recognized actuarial loss	2,186		2,862		1,421		1,977
Prior service cost (credit) amortization	25		25		(36)		(45)
Net periodic benefit cost	$	1,373	$	2,123	$	2,156	$	2,978

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LEASES (Tables)

3 Months Ended

Dec. 31, 2021

Leases [Abstract]

Lease, Cost

The following table presents the Company's lease costs included in the Unaudited Condensed Consolidated Statements of Operations:

		Three Months Ended
		December 31,
(Thousands)	Income Statement Location	2021		2020
Operating lease cost (1)	Operation and maintenance	$	2,119	$	2,089
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	396		1,246
Interest on lease liabilities	Interest expense, net of capitalized interest	80		221
Total finance lease cost		476		1,467
Short-term lease cost	Operation and maintenance	11		127
Variable lease cost	Operation and maintenance	191		153
Total lease cost		$	2,797	$	3,836

(1)Net of capitalized costs.

The following table presents supplemental cash flow information related to leases:

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,037	$	1,737
Operating cash flows for finance leases	$	170	$	2,176
Financing cash flows for finance leases	$	2,275	$	5,997

Assets And Liabilities, Lessee

The following table presents the balance and classifications of the Company's right of use assets and lease liabilities included in the Unaudited Condensed Consolidated Balance Sheets:

(Thousands)	Balance Sheet Location	December 31, 2021		September 30, 2021
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	173,617	$	173,928
Finance lease assets	Utility plant	23,286		13,489
Total lease assets		$	196,903	$	187,417
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,531	$	4,300
Finance lease liabilities	Current maturities of long-term debt	6,397		5,393
Noncurrent
Operating lease liabilities	Operating lease liabilities	141,356		141,363
Finance lease liabilities	Long-term debt	28,673		14,742
Total lease liabilities		$	180,957	$	165,798

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COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

3 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment

Commitments as of December 31, 2021, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2022		2023		2024		2025		2026		Thereafter
Energy Services:
Natural gas purchases	$	101,257	$	1,857	$	—	$	—	$	—	$	—
Storage demand fees	15,217		12,177		6,698		5,018		2,375		906
Pipeline demand fees	49,519		46,628		22,259		19,131		15,211		18,648
Sub-total Energy Services	$	165,993	$	60,662	$	28,957	$	24,149	$	17,586	$	19,554
NJNG:
Natural gas purchases	$	7,668	$	—	$	—	$	—	$	—	$	—
Storage demand fees	34,738		38,107		17,743		7,740		2,171		1,879
Pipeline demand fees	104,124		144,971		133,176		132,456		125,788		1,121,334
Sub-total NJNG	$	146,530	$	183,078	$	150,919	$	140,196	$	127,959	$	1,123,213
Total	$	312,523	$	243,740	$	179,876	$	164,345	$	145,545	$	1,142,767

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REPORTING SEGMENT AND OTHER OPERATIONS DATA (Tables)

3 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Operating revenues
Natural Gas Distribution
External customers	$	274,435	$	195,729
Intercompany	337		—
Clean Energy Ventures
External customers	10,183		6,370
Energy Services
External customers (1)	365,788		227,349
Intercompany	3,456		2,128
Storage and Transportation
External customers	11,584		12,447
Intercompany	559		657
Subtotal	666,342		444,680
Home Services and Other
External customers	13,852		12,410
Intercompany	99		167
Eliminations	(4,451)		(2,952)
Total	$	675,842	$	454,305
Depreciation and amortization
Natural Gas Distribution	$	22,893	$	19,169
Clean Energy Ventures	5,233		5,433
Energy Services (2)	28		42
Storage and Transportation	2,133		2,640
Subtotal	30,287		27,284
Home Services and Other	204		260
Eliminations	(98)		(182)
Total	$	30,393	$	27,362
Interest income (3)
Natural Gas Distribution	$	193	$	82
Storage and Transportation	377		694
Subtotal	570		776
Home Services and Other	155		132
Eliminations	(224)		(239)
Total	$	501	$	669

(1)Includes sales to Canada for the Energy Services segment, which are immaterial.

(2)The amortization of acquired wholesale energy contracts is excluded above and is included in natural gas purchases - nonutility on the Unaudited Condensed Consolidated Statements of Operations.

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Interest expense, net of capitalized interest
Natural Gas Distribution	$	10,995	$	8,974
Clean Energy Ventures	5,427		5,034
Energy Services	675		680
Storage and Transportation	2,136		3,982
Subtotal	19,233		18,670
Home Services and Other	244		1,116
Total	$	19,477	$	19,786
Income tax provision (benefit)
Natural Gas Distribution	$	13,204	$	8,367
Clean Energy Ventures	(2,046)		(3,086)
Energy Services	20,505		12,122
Storage and Transportation	343		646
Subtotal	32,006		18,049
Home Services and Other	246		118
Eliminations	(1,445)		(726)
Total	$	30,807	$	17,441
Equity in earnings (loss) of affiliates
Storage and Transportation	$	1,056	$	3,193
Eliminations	(481)		(518)
Total	$	575	$	2,675
Net financial earnings (loss)
Natural Gas Distribution	$	51,080	$	49,467
Clean Energy Ventures	(6,821)		(10,274)
Energy Services	17,567		1,500
Storage and Transportation	2,962		3,508
Subtotal	64,788		44,201
Home Services and Other	447		(62)
Eliminations	535		518
Total	$	65,770	$	44,657
Capital expenditures
Natural Gas Distribution	$	73,464	$	79,246
Clean Energy Ventures	25,380		22,335
Storage and Transportation	65,375		7,613
Subtotal	164,219		109,194
Home Services and Other	79		686
Total	$	164,298	$	109,880
Investments in equity investees
Storage and Transportation	$	—	$	286
Total	$	—	$	286

Schedule of Assets for Business Segments and Business Operations

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

(Thousands)	December 31, 2021		September 30, 2021
Assets at end of period:
Natural Gas Distribution	$	3,861,240	$	3,707,461
Clean Energy Ventures	937,696		914,788
Energy Services	393,744		365,423
Storage and Transportation	928,653		862,407
Subtotal	6,121,333		5,850,079
Home Services and Other	148,368		162,134
Intercompany assets (1)	(288,544)		(289,935)
Total	$	5,981,157	$	5,722,278

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

Reconciliation of Consolidated NFE to Consolidated Net Income

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

	Three Months Ended
	December 31,
(Thousands)	2021		2020
Net financial earnings	$	65,770	$	44,657
Less:
Unrealized (gain) on derivative instruments and related transactions	(82,191)		(37,491)
Tax effect	19,536		8,913
Effects of economic hedging related to natural gas inventory	23,577		(7,532)
Tax effect	(5,603)		1,790
NFE tax adjustment	(861)		(2,068)
Net income	$	111,312	$	81,045

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RELATED PARTY TRANSACTIONS (Tables)

3 Months Ended

Dec. 31, 2021

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
	December 31,
(Thousands)	2021		2020
Natural Gas Distribution	$	1,558	$	1,568
Energy Services	288		166
Total	$	1,846	$	1,734

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

(Thousands)	December 31, 2021		September 30, 2021
Natural Gas Distribution	$	775	$	778
Energy Services	76		83
Total	$	851	$	861

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NATURE OF THE BUSINESS (Details)	3 Months Ended
	Dec. 31, 2021 customer subsidiary
Steckman Ridge
Nature of Business [Line Items]
Ownership percentage	50.00%
PennEast
Nature of Business [Line Items]
Ownership percentage	20.00%
Natural Gas Distribution
Nature of Business [Line Items]
Total retail customers | customer	566,600
NJR Retail Holdings Corporation
Nature of Business [Line Items]
Number of principal subsidiaries | subsidiary	2

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020	Sep. 30, 2020
Accounting Policies [Abstract]
Cash and cash equivalents	$ 1,259	$ 4,749	$ 22,358
Restricted cash in other noncurrent assets	1,294	1,294	2,431
Cash, cash equivalents and restricted cash	$ 2,553	$ 6,043	$ 24,789	$ 119,423

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2021
Finite-Lived Intangible Assets [Line Items]
Operating revenues	$ 675,842	$ 454,305
Loans receivable in other noncurrent assets	32,600		$ 32,300
Proceeds from sale leaseback transaction	17,300	0
Proceeds from sale leaseback transaction - solar	3,300	12,124
Financial Asset, Not Past Due
Finite-Lived Intangible Assets [Line Items]
Loans receivable in other current assets	14,100		$ 14,200
Energy Services
Finite-Lived Intangible Assets [Line Items]
Operating revenues	22,100
Deferred revenue	64,700
Natural Gas Distribution
Finite-Lived Intangible Assets [Line Items]
Proceeds from sale leaseback transaction	$ 17,300	$ 0
Minimum
Finite-Lived Intangible Assets [Line Items]
Loans receivable, term	2 years
Maximum
Finite-Lived Intangible Assets [Line Items]
Loans receivable, term	10 years

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - NATURAL GAS IN STORAGE (Details) $ in Thousands	Dec. 31, 2021 USD ($) Bcf	Sep. 30, 2021 USD ($) Bcf
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 242,692	$ 193,606
Natural Gas in Storage, Bcf | Bcf	51.6	46.4
Natural Gas Distribution
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 110,673	$ 115,824
Natural Gas in Storage, Bcf | Bcf	22.7	27.6
Energy Services
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 132,019	$ 77,782
Natural Gas in Storage, Bcf | Bcf	28.9	18.8

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SOFTWARE COSTS (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2021
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Capitalized software costs	$ 5,464		$ 5,582
Software amortization	113	$ 77
Operation and maintenance
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	2,523	1,924
Depreciation and amortization
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	299	$ 253
Utility plant, at cost
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	16,777		16,543
Construction work in progress | Regulated
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	11,725		7,801
Construction work in progress | Unregulated
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	1		8
Nonutility plant and equipment, at cost
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	341		338
Accumulated depreciation and amortization, utility plant
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Accumulated depreciation and amortization	(1,644)		(1,333)
Accumulated depreciation and amortization, nonutility plant and equipment
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Accumulated depreciation and amortization	$ (16)		$ (29)

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	$ 1,630,862	$ 1,643,896
Balance as of end of period	1,716,978	1,698,214
Cash Flow Hedges
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(9,376)	(10,397)
Amounts reclassified from accumulated other comprehensive income, net of tax	264	231
Balance as of end of period	(9,112)	(10,166)
Tax on amounts reclassified from accumulated other comprehensive income	(79)	(112)
Postemployment Benefit Obligation
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(25,152)	(33,918)
Amounts reclassified from accumulated other comprehensive income, net of tax	766	812
Balance as of end of period	(24,386)	(33,106)
Tax on amounts reclassified from accumulated other comprehensive income	(233)	(245)
Total
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(34,528)	(44,315)
Amounts reclassified from accumulated other comprehensive income, net of tax	1,030	1,043
Balance as of end of period	(33,498)	(43,272)
Tax on amounts reclassified from accumulated other comprehensive income	$ (312)	$ (357)

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REVENUE - DISAGGREGATED REVENUE - PRODUCT (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 284,090	$ 225,727
Alternative revenue programs	10,654	1,568
Derivative instruments	384,554	229,138
Revenues out of scope	391,752	228,578
Total operating revenues	675,842	454,305
Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	223,796	189,364
Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	40,022	19,532
Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,467	8,259
Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,484	4,318
Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	846	690
Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,470	4,388
Energy Services
Disaggregation of Revenue [Line Items]
Total operating revenues	22,100
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues	666,342	444,680
Operating Segments | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	223,459	189,364
Alternative revenue programs	10,654	1,568
Derivative instruments	40,322	4,797
Revenues out of scope	50,976	6,365
Total operating revenues	274,435	195,729
Operating Segments | Natural Gas Distribution | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	223,796	189,364
Operating Segments | Natural Gas Distribution | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Natural Gas Distribution | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Natural Gas Distribution | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Natural Gas Distribution | Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Natural Gas Distribution | Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	7,316	5,078
Alternative revenue programs	0	0
Derivative instruments	2,867	1,292
Revenues out of scope	2,867	1,292
Total operating revenues	10,183	6,370
Operating Segments | Clean Energy Ventures | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Clean Energy Ventures | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Clean Energy Ventures | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Clean Energy Ventures | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Clean Energy Ventures | Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	846	690
Operating Segments | Clean Energy Ventures | Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,470	4,388
Operating Segments | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	27,879	6,428
Alternative revenue programs	0	0
Derivative instruments	341,365	223,049
Revenues out of scope	337,909	220,921
Total operating revenues	365,788	227,349
Operating Segments | Energy Services | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Energy Services | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	27,879	6,428
Operating Segments | Energy Services | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Energy Services | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Energy Services | Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Energy Services | Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,584	12,447
Alternative revenue programs	0	0
Derivative instruments	0	0
Revenues out of scope	0	0
Total operating revenues	11,584	12,447
Operating Segments | Storage and Transportation | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Storage and Transportation | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,143	13,104
Operating Segments | Storage and Transportation | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Storage and Transportation | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Storage and Transportation | Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments | Storage and Transportation | Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues out of scope	0	0
Total operating revenues	13,852	12,410
Home Services and Other | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,852	12,410
Alternative revenue programs	0	0
Derivative instruments	0	0
Revenues out of scope	0	0
Total operating revenues	13,852	12,410
Home Services and Other | Home Services and Other | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Home Services and Other | Home Services and Other | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Home Services and Other | Home Services and Other | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,467	8,259
Home Services and Other | Home Services and Other | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,484	4,318
Home Services and Other | Home Services and Other | Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Home Services and Other | Home Services and Other | Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(995)	(824)
Revenues out of scope	(3,456)	(2,128)
Eliminations | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(337)	0
Revenues out of scope	0	0
Eliminations | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Revenues out of scope	0	0
Eliminations | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Revenues out of scope	(3,456)	(2,128)
Eliminations | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(559)	(657)
Revenues out of scope	0	0
Eliminations | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(99)	(167)
Revenues out of scope	$ 0	$ 0

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REVENUE - DISAGGREGATED REVENUE - TYPE (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 284,090	$ 225,727
Revenues out of scope	391,752	228,578
Total operating revenues	675,842	454,305
Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	168,055	152,150
Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	91,068	50,666
Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	22,675	21,104
Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,292	1,807
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues	666,342	444,680
Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues out of scope	0	0
Total operating revenues	13,852	12,410
Home Services and Other | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,775	12,204
Home Services and Other | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	77	206
Home Services and Other | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Home Services and Other | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Natural Gas Distribution | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	223,459	189,364
Revenues out of scope	50,976	6,365
Total operating revenues	274,435	195,729
Natural Gas Distribution | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	151,308	137,224
Natural Gas Distribution | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	47,184	29,229
Natural Gas Distribution | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	22,675	21,104
Natural Gas Distribution | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,292	1,807
Clean Energy Ventures | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	7,316	5,078
Revenues out of scope	2,867	1,292
Total operating revenues	10,183	6,370
Clean Energy Ventures | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,972	2,722
Clean Energy Ventures | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,344	2,356
Clean Energy Ventures | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Clean Energy Ventures | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Energy Services
Disaggregation of Revenue [Line Items]
Total operating revenues	22,100
Energy Services | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	27,879	6,428
Revenues out of scope	337,909	220,921
Total operating revenues	365,788	227,349
Energy Services | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Energy Services | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	27,879	6,428
Energy Services | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Energy Services | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Storage and Transportation | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,584	12,447
Revenues out of scope	0	0
Total operating revenues	11,584	12,447
Storage and Transportation | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Storage and Transportation | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,584	12,447
Storage and Transportation | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Storage and Transportation | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 0	$ 0

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REVENUE - TIMING OF REVENUE RECOGNITION (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Timing of Revenue Recognition [Roll Forward]
Billed, beginning	$ 212,838	$ 134,173
Unbilled, beginning	10,351	9,226
Customers' credit, beginning	32,586	25,934
Increase (decrease) for accounts receivable, billed	53,977	63,468
Increase (decrease) for unbilled revenue	62,598	44,568
Increase (decrease) for customers' credits	6,080	7,014
Billed, end	266,815	197,641
Unbilled, end	72,949	53,794
Customers' credit, end	$ 38,666	$ 32,948

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REVENUE - TIMING OF REVENUE RECOGNITION - BALANCE SHEET (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020	Sep. 30, 2020
Customer accounts receivable
Billed	$ 266,815	$ 212,838	$ 197,641	$ 134,173
Unbilled revenues	72,949	10,351	53,794	9,226
Customers' credit balances and deposits	(38,666)	(32,586)	$ (32,948)	$ (25,934)
Customers accounts receivables & Customers' credit balances and deposits	301,098	190,603
Operating Segments | Natural Gas Distribution
Customer accounts receivable
Billed	102,890	54,514
Unbilled revenues	71,542	8,427
Customers' credit balances and deposits	(38,666)	(32,586)
Customers accounts receivables & Customers' credit balances and deposits	135,766	30,355
Operating Segments | Clean Energy Ventures
Customer accounts receivable
Billed	4,608	5,534
Unbilled revenues	1,407	1,924
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	6,015	7,458
Operating Segments | Energy Services
Customer accounts receivable
Billed	153,014	147,087
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	153,014	147,087
Operating Segments | Storage and Transportation
Customer accounts receivable
Billed	4,339	3,956
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	4,339	3,956
Home Services and Other
Customer accounts receivable
Billed	1,964	1,747
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	$ 1,964	$ 1,747

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REGULATION - REGULATORY FILINGS (Details) - USD ($) $ in Thousands				3 Months Ended
	Jan. 26, 2022	Nov. 19, 2021	Nov. 17, 2021	Dec. 31, 2021	Sep. 30, 2021
Schedule of Regulatory Filings [Line Items]
Other noncurrent regulatory assets				$ 528,074	$ 522,099
Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Other noncurrent regulatory assets				$ 10,700
Base Rate Stipulation
Schedule of Regulatory Filings [Line Items]
Weighted average cost of capital				6.84%
Approved return on equity				9.60%
Approved equity capital structure, percentage				54.00%
Public utilities, approved depreciation rate, percentage				2.78%
BPU | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount			$ 79,000
SAFE II and NJ RISE
Schedule of Regulatory Filings [Line Items]
Approved rate increase (decrease), amount				$ 269
BGSS | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount			2,900
BGSS | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount		$ 24,200
BGSS Balancing | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount			13,000
Conservation Incentive Program | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount			$ (6,300)
SAVEGREEN | Subsequent Event
Schedule of Regulatory Filings [Line Items]
Annual recovery increase	$ 2,200

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REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	$ 38,653	$ 30,118
Overrecovered natural gas costs	18,999	28,007
Regulatory liabilities-noncurrent	190,714	193,051
NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	38,280	29,701
Regulatory assets-noncurrent	524,658	519,600
Overrecovered natural gas costs	18,999	28,007
Regulatory liabilities-noncurrent	189,819	191,888
Adelphia
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	373	417
Regulatory assets-noncurrent	3,416	2,499
Regulatory liabilities-noncurrent	895	1,163
Total current regulatory liabilities | NJNG
Regulatory Assets And Liabilities [Line Items]
Overrecovered natural gas costs	11,659	5,510
Derivatives at fair value, net | NJNG
Regulatory Assets And Liabilities [Line Items]
Overrecovered natural gas costs	7,340	22,497
Regulatory liabilities-noncurrent	0	1,166
Tax Act impact | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	189,131	190,386
Other noncurrent regulatory liabilities | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	688	336
New Jersey Clean Energy Program | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	14,416	16,308
Conservation Incentive Program | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	22,493	11,839
Other current regulatory assets | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	1,371	1,554
Regulatory assets-noncurrent	38,685	32,695
Expended, net of recoveries | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	64,662	58,483
Liability for future expenditures | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	126,881	135,012
Deferred income taxes | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	39,613	39,694
SAVEGREEN | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	37,342	32,941
Postemployment and other benefit costs | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	114,515	117,194
Deferred storm damage costs | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	3,800	4,343
Cost of removal | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	$ 99,160	$ 99,238

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DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
Fair Value
Derivative assets, current	$ 39,783	$ 35,251
Derivative liabilities, current	30,049	87,145
Derivative assets, noncurrent	1,978	3,403
Derivative liabilities, noncurrent	15,261	13,497
Not Designated as Hedging Instrument
Fair Value
Derivative assets	41,761	38,654
Derivative liabilities	45,310	100,642
Natural Gas Distribution | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	234	36
Derivative liabilities, current	4	16
Natural Gas Distribution | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	5,032	2,046
Derivative liabilities, current	240	13
Energy Services | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	2,285	2,818
Derivative liabilities, current	18,592	24,592
Derivative assets, noncurrent	135	333
Derivative liabilities, noncurrent	15,261	13,237
Energy Services | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	32,164	30,226
Derivative liabilities, current	11,209	62,521
Derivative assets, noncurrent	1,843	3,068
Derivative liabilities, noncurrent	0	260
Energy Services | Not Designated as Hedging Instrument | Foreign currency contracts
Fair Value
Derivative assets, current	68	125
Derivative liabilities, current	4	3
Derivative assets, noncurrent	0	2
Derivative liabilities, noncurrent	$ 0	$ 0

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DERIVATIVE INSTRUMENTS - OFFSETTING OF ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
Energy Services
Derivative assets:
Amounts Presented in Balance Sheets	$ 36,495	$ 36,572
Offsetting Derivative Instruments	(10,159)	(34,191)
Financial Collateral Received/Pledged	(200)	19,832
Net Amounts	26,136	22,213
Derivative liabilities:
Amounts Presented in Balance Sheets	45,066	100,613
Offsetting Derivative Instruments	(10,159)	(34,191)
Financial Collateral Received/Pledged	0	0
Net Amounts	34,907	66,422
Energy Services | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	2,420	3,151
Offsetting Derivative Instruments	(908)	(894)
Financial Collateral Received/Pledged	(200)	(700)
Net Amounts	1,312	1,557
Derivative liabilities:
Amounts Presented in Balance Sheets	33,853	37,829
Offsetting Derivative Instruments	(908)	(894)
Financial Collateral Received/Pledged	0	0
Net Amounts	32,945	36,935
Energy Services | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	34,007	33,294
Offsetting Derivative Instruments	(9,247)	(33,294)
Financial Collateral Received/Pledged	0	20,532
Net Amounts	24,760	20,532
Derivative liabilities:
Amounts Presented in Balance Sheets	11,209	62,781
Offsetting Derivative Instruments	(9,247)	(33,294)
Financial Collateral Received/Pledged	0	0
Net Amounts	1,962	29,487
Energy Services | Foreign currency contracts
Derivative assets:
Amounts Presented in Balance Sheets	68	127
Offsetting Derivative Instruments	(4)	(3)
Financial Collateral Received/Pledged	0
Net Amounts	64	124
Derivative liabilities:
Amounts Presented in Balance Sheets	4	3
Offsetting Derivative Instruments	(4)	(3)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	0
Natural Gas Distribution
Derivative assets:
Amounts Presented in Balance Sheets	5,266	2,082
Offsetting Derivative Instruments	(240)	(21)
Financial Collateral Received/Pledged	0	0
Net Amounts	5,026	2,061
Derivative liabilities:
Amounts Presented in Balance Sheets	244	29
Offsetting Derivative Instruments	(240)	(21)
Financial Collateral Received/Pledged	0	0
Net Amounts	4	8
Natural Gas Distribution | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	234	36
Offsetting Derivative Instruments	0	(8)
Financial Collateral Received/Pledged	0	0
Net Amounts	234	28
Derivative liabilities:
Amounts Presented in Balance Sheets	4	16
Offsetting Derivative Instruments	0	(8)
Financial Collateral Received/Pledged	0	0
Net Amounts	4	8
Natural Gas Distribution | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	5,032	2,046
Offsetting Derivative Instruments	(240)	(13)
Financial Collateral Received/Pledged	0	0
Net Amounts	4,792	2,033
Derivative liabilities:
Amounts Presented in Balance Sheets	240	13
Offsetting Derivative Instruments	(240)	(13)
Financial Collateral Received/Pledged	0	0
Net Amounts	$ 0	$ 0

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DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) - Not Designated as Hedging Instrument - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	$ 62,844	$ 48,153
Energy Services | Physical commodity contracts | Operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	150	5,252
Energy Services | Physical commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	1,505	(5,054)
Energy Services | Financial commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	61,189	47,755
Energy Services | Foreign currency contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	0	200
Natural Gas Distribution
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	(12,951)	(3,930)
Natural Gas Distribution | Physical commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	1,696	342
Natural Gas Distribution | Financial commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	$ (14,647)	$ (4,272)

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DERIVATIVE INSTRUMENTS - ADDITIONAL INFORMATION (Details) certificate in Thousands, $ in Thousands	3 Months Ended
	Dec. 31, 2021 USD ($) certificate	Dec. 31, 2020 USD ($)	Sep. 30, 2021 USD ($) certificate
Treasury Lock | Interest expense
Derivative [Line Items]
Amount of pre-tax gain (loss) reclassified from OCI into income	$ (343)	$ (343)
Foreign currency contracts
Derivative [Line Items]
Notional amount	$ (63)		$ (123)
Physical commodity contracts | Energy Services
Derivative [Line Items]
Number of SRECs (in certificates) | certificate	1,400		1,400

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DERIVATIVE INSTRUMENTS - VOLUME (Details) - Bcf	3 Months Ended	12 Months Ended
	Dec. 31, 2021	Sep. 30, 2021
Natural Gas Distribution | Long | Futures
Derivative [Line Items]
Notional amount	24.0	22.2
Natural Gas Distribution | Long | Physical Commodity
Derivative [Line Items]
Notional amount	1.5	7.6
Energy Services | Long | Physical Commodity
Derivative [Line Items]
Notional amount	(4.9)	0.6
Energy Services | Short | Futures
Derivative [Line Items]
Notional amount	(22.0)	(13.4)
Energy Services | Short | Swaps
Derivative [Line Items]
Notional amount	(0.2)	(0.3)

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DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
Natural Gas Distribution | Assets, Current
Derivative [Line Items]
Broker margin - Current assets	$ 5,358	$ 2,790
Energy Services | Assets, Current
Derivative [Line Items]
Broker margin - Current assets	37,358	70,050
Energy Services | Liabilities, Current
Derivative [Line Items]
Broker margin - Current assets	$ (15,475)	$ 0

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DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) $ in Thousands	3 Months Ended
	Dec. 31, 2021 USD ($)
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 250,602
Investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	185,828
Noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	11,016
Internally rated investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	23,742
Internally rated noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 30,016

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FAIR VALUE - DEBT (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Finance leases	$ 35,100	$ 20,100
NJR
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	3,700	3,300
Natural Gas Distribution
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	10,300	9,100
Level 2 | Carrying Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	2,202,845	2,102,845
Level 2 | Fair market value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 2,373,791	$ 2,288,544

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FAIR VALUE - ADDITIONAL INFORMATION (Details) - USD ($) $ in Millions	Dec. 31, 2021	Sep. 30, 2021
Solar Asset Financing | Fair market value | Clean Energy Ventures
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 131.5	$ 132.5

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FAIR VALUE - HIERARCHY (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	$ 2,085	$ 1,815
Total assets at fair value	43,887	40,510
Total liabilities at fair value	45,310	100,642
Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	2,654	3,187
Liabilities	33,857	37,845
Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	39,039	35,340
Liabilities	11,449	62,794
Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	68	127
Liabilities	4	3
Quoted Prices in Active Markets for Identical Assets, (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	2,085	1,815
Total assets at fair value	41,165	37,196
Total liabilities at fair value	11,278	62,188
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
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	39,039	35,340
Liabilities	11,278	62,188
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
Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	0	0
Total assets at fair value	2,722	3,314
Total liabilities at fair value	34,032	38,454
Significant Other Observable Inputs (Level 2) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	2,654	3,187
Liabilities	33,857	37,845
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	171	606
Significant Other Observable Inputs (Level 2) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	68	127
Liabilities	4	3
Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	0	0
Total assets at fair value	0	0
Total liabilities at fair value	0	0
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
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
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
Money market funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	41	41
Money market funds | Quoted Prices in Active Markets for Identical Assets, (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	41	41
Money market funds | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Money market funds | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 0	$ 0

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INVESTMENTS IN EQUITY INVESTEES (Details) $ in Thousands	3 Months Ended
	Dec. 31, 2021 USD ($) mi	Jun. 30, 2021 USD ($)	Sep. 30, 2021 USD ($)
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 114,249		$ 114,529
Other than temporary impairment		$ 92,000
Other than temporary impairment, net of tax		$ 74,500
PennEast | NJR Pipeline
Schedule of Equity Method Investments [Line Items]
Ownership percentage	20.00%
Steckman Ridge
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 108,770		109,050
Total outstanding principal balance of loans	$ 70,400		70,400
Ownership percentage	50.00%
PennEast
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 5,479		$ 5,479
Ownership percentage	20.00%
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
	Dec. 31, 2021	Dec. 31, 2020
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income, as reported	$ 111,312	$ 81,045
Basic earnings per share
Weighted average shares of common stock outstanding-basic (in shares)	95,944,000	96,114,000
Basic earnings per common share (usd per share)	$ 1.16	$ 0.84
Diluted earnings per share
Weighted average shares of common stock outstanding-basic (in shares)	95,944,000	96,114,000
Incremental shares (in shares)	412,000	301,000
Weighted average shares of common stock outstanding-diluted (in shares)	96,356,000	96,415,000
Diluted earnings per common share (usd per share)	$ 1.16	$ 0.84
Share-based Payment Arrangement
Diluted earnings per share
Anti-dilutive shares excluded from the calculation of diluted earnings per share (in shares)		32,317

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DEBT - CREDIT FACILITIES (Details) - USD ($)	3 Months Ended
	Dec. 31, 2021	Sep. 30, 2021
NJR | Letter of Credit on Behalf of NJRES
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount	$ 19,600,000	$ 10,600,000
NJNG | Letter of Credit
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount	$ 731,000	731,000
Revolving Credit Facility | NJR
Line of Credit Facility [Line Items]
Commitment fee percentage	0.10%
Revolving Credit Facility | NJNG
Line of Credit Facility [Line Items]
Commitment fee percentage	0.075%
Revolving Credit Facility | Committed Credit Facilities Due December 2023 | NJR
Line of Credit Facility [Line Items]
Bank revolving credit facilities	$ 500,000,000	500,000,000
Amount outstanding at end of period	$ 310,550,000	$ 219,100,000
Weighted average interest rate at end of period	1.13%	1.05%
Amount available at end of period	$ 169,862,000	$ 270,312,000
Revolving Credit Facility | Committed Credit Facilities Due December 2023 | NJNG
Line of Credit Facility [Line Items]
Bank revolving credit facilities	250,000,000	250,000,000
Amount outstanding at end of period	$ 177,400,000	$ 158,200,000
Weighted average interest rate at end of period	0.55%	0.17%
Amount available at end of period	$ 71,869,000	$ 91,069,000

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DEBT - LONG TERM DEBT (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Oct. 28, 2021
Debt Instrument [Line Items]
Proceeds from sale leaseback transaction	$ 17,300	$ 0
Proceeds from sale leaseback transaction - solar	3,300	12,124
Senior Notes | Natural Gas Distribution
Debt Instrument [Line Items]
Face amount			$ 100,000
Senior Notes | Natural Gas Distribution | Fixed Interest Rate Maturing 2051
Debt Instrument [Line Items]
Face amount			$ 50,000
Stated interest rate			2.97%
Senior Notes | Natural Gas Distribution | Fixed Interest Rate Maturing 2061
Debt Instrument [Line Items]
Face amount			$ 50,000
Stated interest rate			3.07%
Clean Energy Ventures
Debt Instrument [Line Items]
Proceeds from sale leaseback transaction - solar	$ 3,300	12,100
Clean Energy Ventures | Minimum
Debt Instrument [Line Items]
Sale leaseback transaction lease term	5 years
Clean Energy Ventures | Maximum
Debt Instrument [Line Items]
Sale leaseback transaction lease term	15 years
Natural Gas Distribution
Debt Instrument [Line Items]
Proceeds from sale leaseback transaction	$ 17,300	$ 0
Payments for sale leaseback transaction	$ 1,100

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EMPLOYEE BENEFIT PLANS - COMPONENTS OF NET PERIODIC COST (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	$ 2,073	$ 2,182
Interest cost	2,408	2,278
Expected return on plan assets	(5,319)	(5,224)
Recognized actuarial loss	2,186	2,862
Prior service cost (credit) amortization	25	25
Net periodic benefit cost	1,373	2,123
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	1,076	1,211
Interest cost	1,589	1,518
Expected return on plan assets	(1,894)	(1,683)
Recognized actuarial loss	1,421	1,977
Prior service cost (credit) amortization	(36)	(45)
Net periodic benefit cost	$ 2,156	$ 2,978

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EMPLOYEE BENEFIT PLANS - ADDITIONAL INFORMATION (Details) - USD ($)	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Pension
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	$ 0	$ 0
OPEB | Minimum
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	5,000,000
OPEB | Maximum
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	$ 10,000,000

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INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2021	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Forecasted effective tax rate	21.60%	17.60%
Revaluation of deferred tax assets and liabilities	$ 166	$ (76)
Actual effective tax rate	21.70%	17.70%
ITC carryforward	$ 226,100		$ 224,200
Effective term	20 years
Potential net capital loss	$ 61,800
Valuation allowance	23,700		23,600
Operating loss carryforward, valuation allowance	$ 17,300
Investment tax credit, solar property, percentage	26.00%	26.00%				30.00%
Scenario, Forecast
Operating Loss Carryforwards [Line Items]
Investment tax credit, solar property, percentage				10.00%	22.00%
Capital Loss Carryforward
Operating Loss Carryforwards [Line Items]
Tax credit carryforward, valuation allowance	$ 6,400
State
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	$ 461,900		$ 554,600
State | Minimum
Operating Loss Carryforwards [Line Items]
Effective term			7 years
State | Maximum
Operating Loss Carryforwards [Line Items]
Effective term			20 years

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LEASES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2021
Lessee, Lease, Description [Line Items]
ROU asset obtained in exchange for operating lease liability	$ 808	$ 9,300
ROU asset obtained in exchange for finance lease liability	$ 17,300	$ 0
Weighted average remaining lease term, operating lease	29 years 8 months 12 days		29 years 7 months 6 days
Operating lease, discount rate	3.20%		3.20%
Weighted average remaining lease term, finance lease	4 years 8 months 12 days		3 years 4 months 24 days
Finance lease, discount rate	2.70%		3.50%
Solar Property | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	20 years
Renewal term	5 years
Solar Property | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	50 years
Renewal term	20 years
Office Building | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	2 years
Office Building | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	17 years
Meter License | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	7 years
Meter License | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	10 years
Equipment
Lessee, Lease, Description [Line Items]
Term of contract	6 years
Storage and Capacity
Lessee, Lease, Description [Line Items]
Term of contract	50 years

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LEASES - LEASE COST (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease cost	$ 2,119	$ 2,089
Amortization of right-of-use assets	396	1,246
Interest on lease liabilities	80	221
Total finance lease cost	476	1,467
Short-term lease cost	11	127
Variable lease cost	191	153
Total lease cost	$ 2,797	$ 3,836

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LEASES - SUPPLEMENTAL CASH FLOW INFORMATION (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating cash flows for operating leases	$ 2,037	$ 1,737
Operating cash flows for finance leases	170	2,176
Financing cash flows for finance leases	$ 2,275	$ 5,997

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LEASES - RIGHT-OF-USE ASSETS AND LEASE LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
NONCURRENT ASSETS
Operating lease assets	$ 173,617	$ 173,928
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Utility plant, at cost	Utility plant, at cost
Finance lease assets	$ 23,286	$ 13,489
Total lease assets	196,903	187,417
Current
Operating lease liabilities	$ 4,531	$ 4,300
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Current maturities of long-term debt	Current maturities of long-term debt
Finance lease liabilities	$ 6,397	$ 5,393
Noncurrent
Operating lease liabilities	$ 141,356	$ 141,363
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Long-term debt	Long-term debt
Finance lease liabilities	$ 28,673	$ 14,742
Total lease liabilities	$ 180,957	$ 165,798

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COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) $ in Thousands	3 Months Ended
	Dec. 31, 2021 USD ($)
Long-term Purchase Commitment [Line Items]
Current charges recoverable through BGSS	$ 191,000
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	312,523
2023	243,740
2024	179,876
2025	164,345
2026	145,545
Thereafter	1,142,767
Energy Services
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	165,993
2023	60,662
2024	28,957
2025	24,149
2026	17,586
Thereafter	19,554
Energy Services | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	101,257
2023	1,857
2024	0
2025	0
2026	0
Thereafter	0
Energy Services | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	15,217
2023	12,177
2024	6,698
2025	5,018
2026	2,375
Thereafter	906
Energy Services | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	49,519
2023	46,628
2024	22,259
2025	19,131
2026	15,211
Thereafter	18,648
Annual pipeline obligation to be paid over 10 year period	4,000
Natural Gas Distribution
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	146,530
2023	183,078
2024	150,919
2025	140,196
2026	127,959
Thereafter	1,123,213
Natural Gas Distribution | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	7,668
2023	0
2024	0
2025	0
2026	0
Thereafter	0
Natural Gas Distribution | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	34,738
2023	38,107
2024	17,743
2025	7,740
2026	2,171
Thereafter	1,879
Natural Gas Distribution | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	104,124
2023	144,971
2024	133,176
2025	132,456
2026	125,788
Thereafter	$ 1,121,334
Minimum | Energy Services
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, contract term	1 year
Maximum | Energy Services
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, contract term	10 years

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COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details) - USD ($) $ in Thousands				3 Months Ended
	Sep. 30, 2021	Apr. 07, 2021	Sep. 09, 2020	Dec. 31, 2021
Site Contingency [Line Items]
Manufactured gas plant remediation	$ 135,012			$ 126,872
Recovery from third party of environmental remediation cost, period				7 years
Regulatory assets	522,099			$ 528,074
Expended, net of recoveries
Site Contingency [Line Items]
Regulatory assets				64,700
RAC
Site Contingency [Line Items]
Approved rate, amount		$ 11,100	$ 9,700
Approved rate increase (decrease), amount	$ 2,000
Minimum
Site Contingency [Line Items]
Product liability contingency, loss exposure in excess of accrual, best estimate				115,700
Maximum
Site Contingency [Line Items]
Product liability contingency, loss exposure in excess of accrual, best estimate				$ 178,700

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REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Utility	$ 274,435	$ 195,729
Nonutility	401,407	258,576
Operating revenues	675,842	454,305
Depreciation and amortization	30,393	27,362
Interest income	501	669
Interest expense, net of capitalized interest	19,477	19,786
Income tax provision (benefit)	30,807	17,441
Impairment of equity method investment	575	2,675
Net financial earnings (loss)	65,770	44,657
Capital expenditures	164,298	109,880
Investments in equity investees	0	286
Energy Services
Segment Reporting Information [Line Items]
Operating revenues	22,100
Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	666,342	444,680
Depreciation and amortization	30,287	27,284
Interest income	570	776
Interest expense, net of capitalized interest	19,233	18,670
Income tax provision (benefit)	32,006	18,049
Net financial earnings (loss)	64,788	44,201
Capital expenditures	164,219	109,194
Operating Segments | Natural Gas Distribution, External Customers
Segment Reporting Information [Line Items]
Utility	274,435	195,729
Operating Segments | Clean Energy Ventures
Segment Reporting Information [Line Items]
Nonutility	10,183	6,370
Operating revenues	10,183	6,370
Depreciation and amortization	5,233	5,433
Interest expense, net of capitalized interest	5,427	5,034
Income tax provision (benefit)	(2,046)	(3,086)
Net financial earnings (loss)	(6,821)	(10,274)
Capital expenditures	25,380	22,335
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Nonutility	365,788	227,349
Operating revenues	365,788	227,349
Depreciation and amortization	28	42
Interest expense, net of capitalized interest	675	680
Income tax provision (benefit)	20,505	12,122
Net financial earnings (loss)	17,567	1,500
Operating Segments | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility	11,584	12,447
Operating revenues	11,584	12,447
Depreciation and amortization	2,133	2,640
Interest income	377	694
Interest expense, net of capitalized interest	2,136	3,982
Income tax provision (benefit)	343	646
Impairment of equity method investment	1,056	3,193
Net financial earnings (loss)	2,962	3,508
Capital expenditures	65,375	7,613
Investments in equity investees	0	286
Operating Segments | Natural Gas Distribution
Segment Reporting Information [Line Items]
Operating revenues	274,435	195,729
Depreciation and amortization	22,893	19,169
Interest income	193	82
Interest expense, net of capitalized interest	10,995	8,974
Income tax provision (benefit)	13,204	8,367
Net financial earnings (loss)	51,080	49,467
Capital expenditures	73,464	79,246
Intercompany
Segment Reporting Information [Line Items]
Nonutility	99	167
Intercompany | Natural Gas Distribution, External Customers
Segment Reporting Information [Line Items]
Utility	337	0
Intercompany | Energy Services
Segment Reporting Information [Line Items]
Nonutility	3,456	2,128
Intercompany | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility	559	657
Home Services and Other
Segment Reporting Information [Line Items]
Nonutility	13,852	12,410
Operating revenues	13,852	12,410
Depreciation and amortization	204	260
Interest income	155	132
Interest expense, net of capitalized interest	244	1,116
Income tax provision (benefit)	246	118
Net financial earnings (loss)	447	(62)
Capital expenditures	79	686
Eliminations
Segment Reporting Information [Line Items]
Nonutility	(4,451)	(2,952)
Depreciation and amortization	(98)	(182)
Interest income	(224)	(239)
Income tax provision (benefit)	(1,445)	(726)
Impairment of equity method investment	(481)	(518)
Net financial earnings (loss)	$ 535	$ 518

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REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Sep. 30, 2021
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ 5,981,157	$ 5,722,278
Operating Segments
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	6,121,333	5,850,079
Operating Segments | Natural Gas Distribution
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	3,861,240	3,707,461
Operating Segments | Clean Energy Ventures
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	937,696	914,788
Operating Segments | Energy Services
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	393,744	365,423
Operating Segments | Storage and Transportation
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	928,653	862,407
Home Services and Other
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	148,368	162,134
Intercompany Assets
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ (288,544)	$ (289,935)

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REPORTING SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS (LOSS) RECONCILIATION (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting [Abstract]
Net financial earnings (loss)	$ 65,770	$ 44,657
Less:
Unrealized (gain) on derivative instruments and related transactions	(82,191)	(37,491)
Tax effect	19,536	8,913
Effects of economic hedging related to natural gas inventory	23,577	(7,532)
Tax effect	(5,603)	1,790
NFE tax adjustment	(861)	(2,068)
NET INCOME	$ 111,312	$ 81,045

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RELATED PARTY TRANSACTIONS (Details) $ in Thousands		1 Months Ended	3 Months Ended
	Apr. 01, 2020 USD ($) Bcf	Mar. 31, 2021	Dec. 31, 2021 USD ($) dth / d lease Bcf	Dec. 31, 2020 USD ($)	Sep. 30, 2021 USD ($)	Jul. 31, 2021
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement			$ 1,846	$ 1,734
Demand fees payable			$ 851		$ 861
Number of asset management agreements | lease			1
NJNG to NJRES Affiliate
Related Party Transaction [Line Items]
Asset management agreement, period	5 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			$ 1,558	1,568
Demand fees payable			775		778
NJRES to Steckman Ridge Affiliate
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement			288	$ 166
Demand fees payable			$ 76		$ 83
NJN G to Adelphia Affiliate
Related Party Transaction [Line Items]
Transportation precedent agreement term			5 years
Transportation capacity under precedent agreement with PennEast (in bcf per day) | dth / d			130,000
Leaf River Energy Center LLC
Related Party Transaction [Line Items]
Natural gas sold at cost under asset management agreement (in Bcf) | Bcf			3
Storage capacity agreement term			5 years
NJNG and Clean Energy Ventures to PPA
Related Party Transaction [Line Items]
Sublease agreement term		15 years
NJNG To NJR Subsidiaries
Related Party Transaction [Line Items]
Term of contract						16 years