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 March 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 May 3, 2021 was 96,339,849.

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	17
		Note 4. Regulation	21
		Note 5. Derivative Instruments	23
		Note 6. Fair Value	28
		Note 7. Investments in Equity Investees	30
		Note 8. Earnings Per Share	31
		Note 9. Debt	32
		Note 10. Employee Benefit Plans	33
		Note 11. Income Taxes	34
		Note 12. Leases	35
		Note 13. Commitments and Contingent Liabilities	37
		Note 14. Common Stock Equity	39
		Note 15. Reporting Segment and Other Operations Data	39
		Note 16. Related Party Transactions	43
		Note 17. Acquisitions and Dispositions	43
	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	45
	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	72
	ITEM 4.	Controls and Procedures	75
PART II. OTHER INFORMATION
	ITEM 1.	Legal Proceedings	76
	ITEM 1A.	Risk Factors	76
	ITEM 2.	Unregistered Sale of Equity Securities and Use of Proceeds	76
	ITEM 6.	Exhibits	77
		Signatures	78

New Jersey Resources Corporation

GLOSSARY OF KEY TERMS                                                                                                                                                       

Adelphia Gateway	Adelphia Gateway, LLC
AFUDC	Allowance for Funds Used During Construction
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
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
EPS	Earnings Per Share
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
IEC	Interstate Energy Company, LLC
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
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 Act	The Natural Gas Act of 1938, as amended; the federal law regulating interstate natural gas pipeline and storage companies, among other things, codified beginning at 15 U.S.C. Section 717.
NFE	Net Financial Earnings
NJ RISE	New Jersey Reinvestment in System Enhancement
NJCEP	New Jersey's Clean Energy Program
NJDEP	New Jersey Department of Environmental Protection

1

New Jersey Resources Corporation

GLOSSARY OF KEY TERMS (cont.)
NJNG	New Jersey Natural Gas Company
NJNG Credit Facility	NJNG's $250 million unsecured committed credit facility expiring in December 2023
NJR Credit Facility	NJR's $425 million unsecured committed credit facility expiring in December 2023
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
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
S&P	Standard & Poor's Financial Services, LLC
SAFE	Safety Acceleration and Facility Enhancement
SAVEGREEN	The SAVEGREEN Project®
SBC	Societal Benefits Charge
SEC	U.S. Securities and Exchange Commission
SREC	Solar Renewable Energy Certificate
SRL	Southern Reliability Link
Steckman Ridge	Collectively, Steckman Ridge GP, LLC and Steckman Ridge, LP
Storage and Transportation	Storage and Transportation segment
Talen	Talen Energy Marketing, LLC
TETCO	Texas Eastern Transmission
The Exchange Act	The Securities Exchange Act of 1934, as amended
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 Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995. Forward-looking statements can also be identified by the use of forward-looking terminology such as “anticipate,” “estimate,” “may,” “could,” “might,” “intend,” “expect,” “believe,” “will” “plan,” or “should,” or comparable terminology and are made based upon management's current expectations, assumptions and beliefs as of this date concerning future developments and their potential effect on us. There can be no assurance that future developments will be in accordance with management's expectations, assumptions or beliefs, or that the effect of future developments on us will be those anticipated by management.

We caution readers that the expectations, assumptions and beliefs that form the basis for forward-looking statements regarding customer growth, customer usage, qualifications for ITCs, 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 2021 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, 2020, as well as the following:

•risks related to the impact of COVID-19 on business operations, 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 PennEast and 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 SRECs and electricity prices, 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 and Leaf River;

•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;

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

•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;

•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				Six Months Ended
	March 31,				March 31,
(Thousands, except per share data)	2021		2020		2021		2020
OPERATING REVENUES
Utility	$	310,167	$	297,220	$	505,896	$	516,843
Nonutility	492,020		342,394		750,596		737,807
Total operating revenues	802,187		639,614		1,256,492		1,254,650
OPERATING EXPENSES
Natural gas purchases:
Utility	113,235		111,563		169,380		203,377
Nonutility	330,488		318,384		503,735		635,740
Related parties	1,730		1,506		3,464		3,030
Operation and maintenance	110,265		66,832		183,901		130,177
Regulatory rider expenses	18,413		15,330		29,114		27,072
Depreciation and amortization	26,848		27,516		54,210		52,153
Total operating expenses	600,979		541,131		943,804		1,051,549
OPERATING INCOME	201,208		98,483		312,688		203,101
Other income, net	5,007		7,261		9,124		7,547
Interest expense, net of capitalized interest	20,153		19,203		39,939		35,273
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	186,062		86,541		281,873		175,375
Income tax provision	39,057		16,284		56,498		32,755
Equity in earnings of affiliates	2,804		3,589		5,479		6,978
NET INCOME	$	149,809	$	73,846	$	230,854	$	149,598
EARNINGS PER COMMON SHARE
Basic	$1.56		$0.78		$2.40		$1.60
Diluted	$1.55		$0.77		$2.39		$1.59
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic	96,248		95,584		96,181		93,747
Diluted	96,618		95,890		96,598		94,073

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Net income	$	149,809	$	73,846	$	230,854	$	149,598
Other comprehensive income, net of tax
Reclassifications of losses to net income on derivatives designated as hedging instruments, net of tax of $(79), $0, $(191) and $0, respectively	263		—		494		—
Loss on derivatives designated as hedging instruments, net of tax of $0, $2,781, $0 and $2,781, respectively	—		(9,711)		—		(9,711)
Adjustment to postemployment benefit obligation, net of tax of $(244), $(1,753), $(489) and $(1,970), respectively	813		6,100		1,625		6,859
Other comprehensive income (loss)	$	1,076	$	(3,611)	$	2,119	$	(2,852)
Comprehensive income	$	150,885	$	70,235	$	232,973	$	146,746

See Notes to Unaudited Condensed Consolidated Financial Statements

4

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                    

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	Six Months Ended
	March 31,
(Thousands)	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	230,854	$	149,598
Adjustments to reconcile net income to cash flows from operating activities
Unrealized gain on derivative instruments	(8,235)		(45,539)
Depreciation and amortization	54,210		52,153
Amortization of acquired wholesale energy contracts	3,401		3,953
Allowance for equity used during construction	(10,603)		(8,053)
Allowance for doubtful accounts	10,607		951
Non cash lease expense	1,957		1,856
Deferred income taxes	20,909		34,975
Manufactured gas plant remediation costs	(6,284)		(5,291)
Equity in earnings, net of distributions received from equity investees	(3,543)		(2,760)
Cost of removal - asset retirement obligations	(512)		(122)
Contributions to postemployment benefit plans	(2,018)		(5,742)
Taxes related to stock-based compensation	(145)		803
Changes in:
Components of working capital	6,846		3,526
Other noncurrent assets	18,854		(1,258)
Other noncurrent liabilities	39,993		95
Cash flows from operating activities	356,291		179,145
CASH FLOWS USED IN INVESTING ACTIVITIES
Expenditures for:
Utility plant	(152,496)		(132,352)
Solar equipment	(40,884)		(69,786)
Storage and Transportation and other	(28,518)		(7,724)
Cost of removal	(23,989)		(17,487)
Acquisition of assets, net of cash acquired of $5.1 million	—		(523,647)
Distribution from equity investees in excess of equity in earnings	871		1,132
Investments in equity investees	(482)		(1,266)
Cash flows used in investing activities	(245,498)		(751,130)
CASH FLOWS (USED IN) FROM FINANCING ACTIVITIES
Payments of long-term debt	(11,001)		(9,764)
Proceeds from term loan	—		350,000
Payments of term loan	—		(212,900)
(Payments of) proceeds from short-term debt, net	(116,850)		304,023
Proceeds from sale leaseback transaction - solar	12,124		—
Proceeds from sale leaseback transaction	—		4,000
Payments of common stock dividends	(60,894)		(56,821)
Proceeds from issuance of common stock - public equity offering	—		212,900
Cash settlement of equity forward agreement	(388)		—
Proceeds from issuance of common stock - DRP	7,540		8,767
Tax withholding payments related to net settled stock compensation	(1,772)		(3,893)
Cash flows (used in) from financing activities	(171,241)		596,312
Change in cash, cash equivalents and restricted cash	(60,448)		24,327
Cash, cash equivalents and restricted cash at beginning of period	119,423		4,063
Cash, cash equivalents and restricted cash at end of period	$	58,975	$	28,390
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	(136,295)	$	(87,532)
Inventories	94,233		90,484
Recovery of natural gas costs	(20,279)		(21,891)
Natural gas purchases payable	33,191		(10,933)
Natural gas purchases payable - related parties	62		11
Accounts payable and other	(19,621)		(27,345)
Prepaid expenses	(8,170)		(602)
Prepaid and accrued taxes	59,614		22,258
Restricted broker margin accounts	7,644		39,193
Customers' credit balances and deposits	(5,171)		(7,788)
Other current assets	1,638		7,671
Total	$	6,846	$	3,526
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for:
Interest (net of amounts capitalized)	$	40,465	$	32,872
Income taxes	$	3,733	$	1,193
Accrued capital expenditures	$	22,840	$	17,930
See Notes to Unaudited Condensed Consolidated Financial Statements

5

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                    

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

ASSETS

(Thousands)	March 31, 2021		September 30, 2020
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	2,883,656	$	2,800,052
Construction work in progress	456,513		379,846
Nonutility plant and equipment, at cost	1,121,155		1,108,512
Construction work in progress	229,923		176,556
Total property, plant and equipment	4,691,247		4,464,966
Accumulated depreciation and amortization, utility plant	(620,028)		(601,635)
Accumulated depreciation and amortization, nonutility plant and equipment	(156,063)		(140,562)
Property, plant and equipment, net	3,915,156		3,722,769
CURRENT ASSETS
Cash and cash equivalents	57,654		117,012
Customer accounts receivable
Billed	237,229		134,173
Unbilled revenues	41,941		9,226
Allowance for doubtful accounts	(17,325)		(7,242)
Regulatory assets	23,527		36,530
Natural gas in storage, at average cost	74,853		167,504
Materials and supplies, at average cost	18,824		20,406
Prepaid expenses	14,729		6,639
Prepaid and accrued taxes	3,432		24,301
Derivatives, at fair value	17,433		23,310
Restricted broker margin accounts	45,916		69,444
Other	17,015		21,029
Total current assets	535,228		622,332
NONCURRENT ASSETS
Investments in equity method investees	214,521		208,375
Regulatory assets	522,027		527,459
Operating lease assets	144,326		131,769
Derivatives, at fair value	1,977		3,349
Intangible assets, net	6,462		10,060
Software costs	5,485		4,707
Other noncurrent assets	79,952		85,657
Total noncurrent assets	974,750		971,376
Total assets	$	5,425,134	$	5,316,477

See Notes to Unaudited Condensed Consolidated Financial Statements

6

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)                                                                                                                    

CAPITALIZATION AND LIABILITIES

(Thousands, except share data)	March 31, 2021		September 30, 2020
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding March 31, 2021 — 96,262,016; September 30, 2020 — 95,949,183	$	240,497	$	240,243
Premium on common stock	497,167		491,982
Accumulated other comprehensive loss, net of tax	(42,196)		(44,315)
Treasury stock at cost and other; shares March 31, 2021 — 16,313; September 30, 2020 — 148,310	11,983		8,485
Retained earnings	1,114,382		947,501
Common stock equity	1,821,833		1,643,896
Long-term debt	2,265,202		2,259,466
Total capitalization	4,087,035		3,903,362
CURRENT LIABILITIES
Current maturities of long-term debt	22,635		27,236
Short-term debt	8,500		125,350
Natural gas purchases payable	129,136		95,945
Natural gas purchases payable to related parties	853		791
Accounts payable and other	126,154		141,500
Dividends payable	32,007		31,902
Accrued taxes	41,462		2,717
Regulatory liabilities	717		26,188
New Jersey Clean Energy Program	6,148		15,570
Derivatives, at fair value	23,690		33,865
Operating lease liabilities	4,001		6,724
Customers' credit balances and deposits	20,763		25,934
Total current liabilities	416,066		533,722
NONCURRENT LIABILITIES
Deferred income taxes	166,238		138,081
Deferred investment tax credits	3,171		3,332
Deferred gain	894		1,035
Derivatives, at fair value	20,506		13,352
Manufactured gas plant remediation	143,490		150,590
Postemployment employee benefit liability	236,432		237,221
Regulatory liabilities	193,817		196,450
Operating lease liabilities	111,034		95,030
Asset retirement obligation	34,102		33,723
Other	12,349		10,579
Total noncurrent liabilities	922,033		879,393
Commitments and contingent liabilities (Note 13)
Total capitalization and liabilities	$	5,425,134	$	5,316,477

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, 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
Net income	—	—		—			—		—		149,809		149,809
Other comprehensive income	—	—		—			1,076		—		—		1,076
Common stock issued:
Common stock offering	—	—		(388)			—		—		—		(388)
Incentive compensation plan	28	72		1,144			—		—		—		1,216
Dividend reinvestment plan	103	58		3,521			—		—		—		3,579
Cash dividend declared ($.3325 per share)	—	—		—			—		—		(32,007)		(32,007)
Treasury stock and other	(8)	—		—			—		334		—		334
Balance at March 31, 2021	96,262	$	240,497	$	497,167		$	(42,196)	$	11,983	$	1,114,382	$	1,821,833

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

(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, 2019	89,999	$	226,649	$	291,331		$	(31,787)	$	(10,436)	$	869,858	$	1,345,615
Net income	—	—		—			—		—		75,752		75,752
Other comprehensive income	—	—		—			759		—		—		759
Common stock issued:
Common stock offering	5,333	13,333		199,567			—		—		—		212,900
Incentive compensation plan	96	239		3,053			—		—		—		3,292
Dividend reinvestment plan (1)	80	—		314			—		3,185		—		3,499
Cash dividend declared ($.3125 per share)	—	—		—			—		—		(29,846)		(29,846)
Treasury stock and other	—	—		—			—		(3,879)		—		(3,879)
Balance at December 31, 2019	95,508	$	240,221	$	494,265		$	(31,028)	$	(11,130)	$	915,764	$	1,608,092
Net income	—	—		—			—		—		73,846		73,846
Other comprehensive income	—	—		—			(3,611)		—		—		(3,611)
Common stock issued:
Dividend reinvestment plan (1)	143	—		(416)			—		5,621		—		5,205
Cash dividend declared ($.3125 per share)	—	—		—			—		—		(29,888)		(29,888)
Treasury stock and other	(8)	—		107			—		986		—		1,093
Balance at March 31, 2020	95,643	$	240,221	$	493,956		$	(34,639)	$	(4,523)	$	959,722	$	1,654,737

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

8

New Jersey Resources Corporation

Part I

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA                                                                               

1. NATURE OF THE BUSINESS

NJR provides regulated natural gas distribution services, transportation and storage services and operates certain unregulated businesses primarily through the following:

NJNG provides natural gas utility service to approximately 561,500 customers throughout Burlington, Middlesex, Monmouth, Morris and Ocean 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 consists of the Company's capital investments in commercial and residential solar projects.

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, formerly the Midstream segment, invests in energy-related ventures through its subsidiaries. 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. The Company also operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River, which was acquired on October 11, 2019 and Adelphia Gateway, which was acquired on January 13, 2020 and is subject to rate regulation by FERC. See Note 17. Acquisitions and Dispositions for more information regarding these acquisitions.

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 NJR in accordance with the rules and regulations of the SEC and GAAP. The September 30, 2020 Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in NJR's 2020 Annual Report on Form 10-K.

The Unaudited Condensed Consolidated Financial Statements include the accounts of NJR and its subsidiaries. In the opinion of management, the accompanying Unaudited Condensed Consolidated Financial Statements reflect all adjustments necessary for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of NJR's utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ending September 30, 2021. 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. ARO 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.

9

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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 United States. 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 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 March 31, 2021.

Acquisitions

The Company follows the guidance in ASC 805, Business Combinations, for determining the appropriate accounting treatment for acquisitions. ASU No. 2017-01, Clarifying the Definition of a Business, provides an initial fair value screen to determine if substantially all of the fair value of the assets acquired is concentrated in a single asset or group of similar assets. If the initial screening test is not met, the set is considered a business based on whether there are inputs and substantive processes in place. Based on the results of this analysis and conclusion on an acquisition’s classification of a business combination or an asset acquisition, the accounting treatment is derived.

If the acquisition is deemed to be a business, the acquisition method of accounting is applied. Identifiable assets acquired and liabilities assumed at the acquisition date are recorded at fair value. If the transaction is deemed to be an asset purchase, the cost accumulation and allocation model is used whereby the assets and liabilities are recorded based on the purchase price and allocated to the individual assets and liabilities based on relative fair values.

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various assumptions and valuation methodologies requiring considerable management judgment. The most significant variables in these valuations are discount rates and the number of years on which to base the cash flow projections, as well as other assumptions and estimates used to determine the cash inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets, specific risks, industry beta and capital structure of guideline companies. The valuation of an acquired business is based on available information at the acquisition date and assumptions that are believed to be reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date.

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.

10

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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.

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 escrow balances for utility plant projects at NJNG and irrevocable letters of credit at Leaf River, which is recorded in other current and 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)	March 31, 2021		September 30, 2020		March 31, 2020		September 30, 2019
Balance Sheet
Cash and cash equivalents	$	57,654	$	117,012	$	25,968	$	2,676
Restricted cash in other noncurrent assets	$	1,321	$	2,411	$	2,422	$	1,387
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	58,975	$	119,423	$	28,390	$	4,063

Allowance for Doubtful Accounts

As of October 1, 2021, the Company adopted ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The Company segregates financial assets that fall within the scope of ASC 326, 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.

In February 2021, severe winter weather affected the U.S. mid-continent and southern regions that resulted in increased demand for natural gas supply and increases in wholesale energy prices. As a result, at March 31, 2021, Energy Services evaluated its counterparties for credit deterioration, as well as the related receivables for the purchase and receipt of natural gas for amounts past due.

The Company examined the credit characteristics of its counterparties, including the history of past due amounts for contractual settlements, counterparty credit ratings, and the likelihood of recovering amounts owed. As of March 31, 2021, the Company recorded a reserve for expected credit losses for Energy Services totaling $5.2 million within operations and maintenance expense on the Unaudited Condensed Consolidated Statement of Operations, representing management’s best estimate of expected credit losses at this time.

11

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

It is possible that future developments could occur that could result in impairment of a portion or all of the remaining amounts owed to Energy Services, which would result in an additional charge to earnings.

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 recorded $14.3 million and $13.7 million in other current assets and $33.9 million and $35.3 million in other noncurrent assets as of March 31, 2021 and September 30, 2020, 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 March 31, 2021 and September 30, 2020, 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:

	March 31, 2021				September 30, 2020
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	40,083	9.4		$	110,037	27.2
Energy Services		34,439		13.3		57,352		34.3
Storage and Transportation		331		0.1		115		0.02
Total		$	74,853	22.8		$	167,504	61.52

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 table presents the software costs included in the Unaudited Condensed Consolidated Financial Statements:

(Thousands)	March 31, 2021		September 30, 2020
Balance Sheets
Utility plant, at cost	$	14,011	$	13,452
Nonutility plant and equipment, at cost	$	334	$	316
Accumulated depreciation and amortization, utility plant	$	(790)	$	(279)
Accumulated depreciation and amortization, nonutility plant and equipment	$	(17)	$	(5)
Software costs	$	5,485	$	4,707

	Three Months Ended				Six Months Ended
	March 31,				March 31,
Statements of Operations	2021		2020		2021		2020
Operation and maintenance (1)	$	2,847	$	1,109	$	4,770	$	2,596
Depreciation and amortization	$	270	$	—	$	523	$	—

(1)During the three and six months ended March 31, 2021, $111,000 and $188,000 was amortized from software costs into O&M. There were no amounts amortized for the three and six months ended March 31, 2020.

12

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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 $4.0 million in December 2019, in connection with the sale leaseback of its natural gas meters. There were no natural gas meter sale leasebacks recorded during the six months ended March 31, 2021.

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 terms of 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 SRECs, TRECs 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.

In December 2020, Clean Energy Ventures received proceeds of $12.1 million in connection with the sale leaseback of two commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during the three and six months ended March 31, 2020.

Accumulated Other Comprehensive 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 March 31, 2021 and 2020:

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at December 31, 2020	$	(10,166)	$	(33,106)		$	(43,272)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive income, net of tax of $(79), $(244), $(323), respectively	263		813		(1)	1,076
Balance at March 31, 2021	$	(9,903)	$	(32,293)		$	(42,196)
Balance at December 31, 2019	$	—	$	(31,028)		$	(31,028)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $2,781, $(1,681), $1,100	(9,711)		5,378			(4,333)
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(72), $(72)	—		722		(1)	722
Net current-period other comprehensive income, net of tax of $2,781, $(1,753), $1,028	(9,711)		6,100			(3,611)
Balance at March 31, 2020	$	(9,711)	$	(24,928)		$	(34,639)

(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.

13

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2020	$	(10,397)	$	(33,918)		$	(44,315)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive income, net of tax of $(191), $(489), $(680), respectively	494		1,625		(1)	2,119
Balance at March 31, 2021	$	(9,903)	$	(32,293)		$	(42,196)
Balance at September 30, 2019	$	—	$	(31,787)		$	(31,787)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $2,781, $(1,681), $1,100	(9,711)		5,378			(4,333)
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(289) and $(289)	—		1,481		(1)	1,481
Net current-period other comprehensive income, net of tax of $2,781, $(1,970), $811	(9,711)		6,859			(2,852)
Balance at March 31, 2020	$	(9,711)	$	(24,928)		$	(34,639)

(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.

Change in Accounting Policy

Effective October 1, 2020, the Company changed its method of accounting for ITCs at Clean Energy Ventures from the flow through method to the deferral method. Prior to the change, the Company recognized ITCs as a reduction of income tax expense in the period that the qualified solar energy property, to which it relates, was placed in service. Effective with the accounting change, the Company records ITCs as a reduction to the carrying value of the related asset when placed in service and recognizes ITCs in earnings as a reduction to depreciation expense over the productive life of the related property. The deferral method is considered the preferred method per the authoritative guidance as described in ASC 740 - Income Taxes. The change to the deferral method is also consistent with the application of authoritative accounting guidance throughout other reporting segments and promotes proper matching of the benefits of the recognition of the ITC with the expected use of the asset.

The Company applied the change in accounting method retrospectively to all prior periods presented.

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the three months ended March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	30,784	(3,268)	$	27,516
Total operating expenses	$	544,399	(3,268)	$	541,131
Operating income	$	95,215	3,268	$	98,483
Income before income taxes and equity in earnings of affiliates	$	83,273	3,268	$	86,541
Income tax (benefit) expense	$	(1,643)	17,927	$	16,284
Net income	$	88,505	(14,659)	$	73,846
Earnings per common share
Basic	$	0.93	(0.15)	$	0.78
Diluted	$	0.92	(0.15)	$	0.77

14

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the six months ended March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	58,542	(6,389)	$	52,153
Total operating expenses	$	1,057,938	(6,389)	$	1,051,549
Operating income	$	196,712	6,389	$	203,101
Income before income taxes and equity in earnings of affiliates	$	168,986	6,389	$	175,375
Income tax (benefit) expense	$	(1,902)	34,657	$	32,755
Net income	$	177,866	(28,268)	$	149,598
Earnings per common share
Basic	$	1.90	(0.30)	$	1.60
Diluted	$	1.89	(0.30)	$	1.59

The cumulative effect of the change in accounting policy on the Unaudited Condensed Consolidated Balance Sheets as of September 30, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Assets
Nonutility plant and equipment, at cost	$	1,430,723	(322,211)	$	1,108,512
Accumulated depreciation and amortization, nonutility plant and equipment	$	(202,507)	61,945	$	(140,562)
Property, plant and equipment, net	$	3,983,035	(260,266)	$	3,722,769
Other noncurrent assets	$	78,716	6,941	$	85,657
Total noncurrent assets	$	964,435	6,941	$	971,376
Total assets	$	5,569,802	(253,325)	$	5,316,477
Capitalization
Retained earnings	$	1,148,297	(200,796)	$	947,501
Common stock equity	$	1,844,692	(200,796)	$	1,643,896
Total capitalization	$	4,104,158	(200,796)	$	3,903,362
Liabilities
Deferred income taxes	$	190,610	(52,529)	$	138,081
Total noncurrent liabilities	$	931,922	(52,529)	$	879,393
Total capitalization and liabilities	$	5,569,802	(253,325)	$	5,316,477

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Cash Flows as of March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	58,542	(6,389)	$	52,153
Deferred income taxes	$	318	34,657	$	34,975

15

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Common Stock Equity as of March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Retained Earnings
Balance at September 30, 2019	$	1,075,960	(206,102)	$	869,858
Net income	$	89,361	(13,609)	$	75,752
Balance at December 31, 2019	$	1,135,475	(219,711)	$	915,764
Net income	$	88,505	(14,659)	$	73,846
Balance at March 31, 2020	$	1,194,092	(234,370)	$	959,722
Total
Balance at September 30, 2019	$	1,551,717	(206,102)	$	1,345,615
Net income	$	89,361	(13,609)	$	75,752
Balance at December 31, 2019	$	1,827,803	(219,711)	$	1,608,092
Net income	$	88,505	(14,659)	$	73,846
Balance at March 31, 2020	$	1,889,107	(234,370)	$	1,654,737

Recently Adopted Updates to the Accounting Standards Codification

Financial Instruments

In June 2016, the FASB issued ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. An entity will apply the amendment through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The Company assessed the impact of the guidance on NJR's reserve methodologies and credit policies and procedures for any assets that could be impacted, noting the majority of NJR's financial assets are short-term in nature, such as trade receivables and unbilled revenues.

The Company completed its evaluation of this amendment and all subsequent amendments related to this topic and adopted this guidance on October 1, 2020 using the modified retrospective method. The adoption did not result in a cumulative effect adjustment to retained earnings as the current expected lifetime loss estimates were not materially different from the reserves already in place.

The Company segregates financial assets that fall within the scope of ASC 326, 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.

Fair Value

In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The Company adopted this guidance on October 1, 2020 on a prospective basis. The Company does not have either Level 3 fair value measurements or transfers between Level 1 or Level 2 in its current portfolios, and therefore, this ASU did not have an impact to the Company's financial position, results of operations or cash flows.

16

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Compensation - Retirement Benefits

In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures and adds new disclosure requirements identified as relevant. The Company adopted this guidance on October 1, 2020. There was no impact to the Company's financial position, results of operations or cash flows.

Reference Rate Reform

In January 2021, the FASB issued ASU 2021-01, which refines the scope of ASC 848, Reference Rate Reform, and clarifies some of its guidance of global reference rate reform activities. The amendments in this update permits entities to elect certain optional expedients and exceptions when accounting for derivative contracts and certain hedging relationships affected by changes in the interest rates used for discounting cash flows, for computing variation margin settlements, and for calculating price alignment interest in connection with reference rate reform activities under way in global financial markets (the “discounting transition”). The amendments in this update are effective upon the ASU issuance through December 31, 2022. There was no impact to the Company's financial position, results of operations or cash flows as a result of its adoption.

Other Recent 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 guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. Upon adoption, the amendments will be applied 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.

Investments - Equity Method and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, Investments - Equity Securities (Topic 321), Investments - Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815): Clarifying the Interactions between Topic 321, Topic 323, and Topic 815. 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 guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of these amendments but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

Other

In October 2020, the FASB issued ASU 2020-10, 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 guidance is effective for the Company on October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of these amendments but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

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.

17

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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 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 on a monthly basis in line with the terms of the contract and based on the services provided. Payment is due each month for the previous month's invoiced services.
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, related usage fees for the use of storage space, 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 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.

18

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Revenue Recognized at a Point in Time:
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 hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. 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 March 31, 2021 and 2020, is as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales	$	296,888	—		—	—	—	$	296,888
Natural gas services	—		—		11,011	13,926	—	24,937
Service contracts	—		—		—	—	8,314	8,314
Installations and maintenance	—		—		—	—	4,459	4,459
Renewable energy certificates	—		817		—	—	—	817
Electricity sales	—		4,882		—	—	—	4,882
Eliminations (1)	—		—		—	(669)	(252)	(921)
Revenues from contracts with customers	296,888		5,699		11,011	13,257	12,521	339,376
Alternative revenue programs (2)	(6,664)		—		—	—	—	(6,664)
Derivative instruments	19,943		777	(3)	451,558	—	—	472,278
Eliminations (1)	—		—		(2,803)	—	—	(2,803)
Revenues out of scope	13,279		777		448,755	—	—	462,811
Total operating revenues	$	310,167	6,476		459,766	13,257	12,521	$	802,187
2020
Natural gas utility sales	$	266,868	—		—	—	—	$	266,868
Natural gas services	—		—		9,634	11,076	—	20,710
Service contracts	—		—		—	—	8,073	8,073
Installations and maintenance	—		—		—	—	4,292	4,292
Electricity sales	—		4,458		—	—	—	4,458
Eliminations (1)	—		—		—	(675)	(326)	(1,001)
Revenues from contracts with customers	266,868		4,458		9,634	10,401	12,039	303,400
Alternative revenue programs (2)	22,073		—		—	—	—	22,073
Derivative instruments	8,279		1,537		304,067	—	—	313,883
Eliminations (1)	—		—		258	—	—	258
Revenues out of scope	30,352		1,537		304,325	—	—	336,214
Total operating revenues	$	297,220	5,995		313,959	10,401	12,039	$	639,614

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

(2)Includes CIP revenue.

(3)Includes SREC revenue.

19

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales	$	486,252	—		—	—	—	$	486,252
Natural gas services	—		—		17,439	27,030	—	44,469
Service contracts	—		—		—	—	16,573	16,573
Installations and maintenance	—		—		—	—	8,777	8,777
Renewable energy certificates	—		1,507		—	—	—	1,507
Electricity sales	—		9,270		—	—	—	9,270
Eliminations (1)	—		—		—	(1,326)	(419)	(1,745)
Revenues from contracts with customers	486,252		10,777		17,439	25,704	24,931	565,103
Alternative revenue programs (2)	(5,096)		—		—	—	—	(5,096)
Derivative instruments	24,740		2,069	(3)	674,607	—	—	24,740
Eliminations (1)	—		—		(4,931)	—	—	(4,931)
Revenues out of scope	19,644		2,069		669,676	—	—	691,389
Total operating revenues	$	505,896	12,846		687,115	25,704	24,931	$	1,256,492
2020
Natural gas utility sales	$	486,762	—		—	—	—	$	486,762
Natural gas services	—		—		16,955	20,148	—	37,103
Service contracts	—		—		—	—	16,111	16,111
Installations and maintenance	—		—		—	—	9,161	9,161
Electricity sales	—		8,476		—	—	—	8,476
Eliminations (1)	—		—		—	(1,342)	(741)	(2,083)
Revenues from contracts with customers	486,762		8,476		16,955	18,806	24,531	555,530
Alternative revenue programs (2)	20,130		—		—	—	—	20,130
Derivative instruments	9,951		3,731	(3)	667,161	—	—	680,843
Eliminations (1)	—		—		(1,853)	—	—	(1,853)
Revenues out of scope	30,081		3,731		665,308	—	—	699,120
Total operating revenues	$	516,843	12,207		682,263	18,806	24,531	$	1,254,650

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

(2)Includes CIP revenue.

(3)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 March 31, 2021 and 2020, is as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	225,174	2,692	—	—	12,234	$	240,100
Commercial and industrial	42,824		3,007	11,011	13,257	287	70,386
Firm transportation	28,190		—	—	—	—	28,190
Interruptible and off-tariff	700		—	—	—	—	700
Revenues out of scope	13,279		777	448,755	—	—	462,811
Total operating revenues	$	310,167	6,476	459,766	13,257	12,521	$	802,187
2020
Residential	$	199,776	2,469	—	—	11,831	$	214,076
Commercial and industrial	41,635		1,989	9,634	10,401	208	63,867
Firm transportation	24,123		—	—	—	—	24,123
Interruptible and off-tariff	1,334		—	—	—	—	1,334
Revenues out of scope	30,352		1,537	304,325	—	—	336,214
Total operating revenues	$	297,220	5,995	313,959	10,401	12,039	$	639,614

20

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	362,398	5,414	—	—	24,438	$	392,250
Commercial and industrial	72,053		5,363	17,439	25,704	493	121,052
Firm transportation	49,294		—	—	—	—	49,294
Interruptible and off-tariff	2,507		—	—	—	—	2,507
Revenues out of scope	19,644		2,069	669,676	—	—	691,389
Total operating revenues	$	505,896	12,846	687,115	25,704	24,931	$	1,256,492
2020
Residential	$	352,998	4,929	—	—	24,110	$	382,037
Commercial and industrial	87,057		3,547	16,955	18,806	421	126,786
Firm transportation	43,712		—	—	—	—	43,712
Interruptible and off-tariff	2,995		—	—	—	—	2,995
Revenues out of scope	30,081		3,731	665,308	—	—	699,120
Total operating revenues	$	516,843	12,207	682,263	18,806	24,531	$	1,254,650

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 six months ended March 31, 2021 are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of October 1, 2020	$	134,173	$	9,226	$	25,934
Increase (Decrease)	103,056		32,715		(5,171)
Balance as of March 31, 2021	$	237,229	$	41,941	$	20,763

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 March 31, 2021:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
Customer accounts receivable
Billed	$	119,845	4,794	107,353	3,437	1,800	$	237,229
Unbilled	39,652		2,289	—	—	—	41,941
Customers' credit balances and deposits	(20,763)		—	—	—	—	(20,763)
Total	$	138,734	7,083	107,353	3,437	1,800	$	258,407

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 annual filings to the BPU for review of its BGSS, CIP and various other programs and related rates. Annual rate changes are typically requested to be effective at the beginning of the following fiscal year. 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.

21

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 NJNG are comprised of the following:

(Thousands)	March 31, 2021		September 30, 2020
Regulatory assets-current
New Jersey Clean Energy Program	$	6,147	$	15,570
Conservation Incentive Program	14,025		19,120
Derivatives at fair value, net	1,509		—
Other current regulatory assets	1,730		1,682
Total current regulatory assets	$	23,411	$	36,372
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	37,476	$	36,516
Liability for future expenditures	143,495		150,590
Deferred income taxes	31,603		28,241
Derivatives at fair value, net	4		1
SAVEGREEN	21,842		21,281
Postemployment and other benefit costs	180,360		188,170
Deferred storm damage costs	5,429		6,515
Cost of removal	82,353		75,080
Other noncurrent regulatory assets	17,952		20,068
Total noncurrent regulatory assets	$	520,514	$	526,462
Regulatory liability-current
Overrecovered natural gas costs	$	541	$	25,914
Derivatives at fair value, net	176		274
Total current regulatory liabilities	$	717	$	26,188
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	192,895	$	195,425
Derivatives at fair value, net	—		352
Other noncurrent regulatory liabilities	759		509
Total noncurrent regulatory liabilities	$	193,654	$	196,286

(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.

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

(Thousands)	March 31, 2021		September 30, 2020
Total current regulatory assets	$	116	$	158
Total noncurrent regulatory assets	$	1,514	$	997
Total-noncurrent regulatory liabilities	$	164	$	—

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 October 28, 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. The recovery of information technology replacement and enhancements, that was included in the original IIP filing, will be included as part of base rate filings as projects are placed in service.

•On November 20, 2020, NJNG notified the BPU of its intent to provide BGSS bill credits to residential and small commercial sales customers effective December 1, 2020 to December 31, 2020. On December 22, 2020, NJNG notified the BPU of the extension of the BGSS bill credits through January 31, 2021. The actual bill credits given to customers totaled $20.6 million, $19.3 million net of tax.

22

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

•On March 3, 2021, the BPU approved the three-year SAVEGREEN program consisting of approximately $126.1 million of direct investment, $109.4 million in financing options, and $23.4 million in operation and maintenance expenses, to be effective July 1, 2021.

•On March 3, 2021, the BPU approved, on a final basis, NJNG’s annual petition to modify its BGSS, balancing charge and CIP rates for residential and small commercial customers. The rate changes resulted in a $20.4 million decrease to the annual revenues credited to BGSS, a $3.8 million annual decrease related to its balancing charge, as well as changes to CIP rates, which resulted in a $16.5 million annual recovery increase, effective October 1, 2020.

•On March 30, 2021, NJNG filed a base rate case with the BPU requesting a natural gas revenue increase of $165.7 million including a rate recovery for SRL and other infrastructure investments. SRL is expected to be placed in service during fiscal 2021.

•On March 31, 2021, NJNG filed a petition with the BPU requesting the final base rate increase of approximately $311,000 for the recovery associated with NJ RISE and SAFE II capital investments cost of approximately $3.4 million made through June 30, 2021. This filing will be updated for actual information through June 30, 2021. Changes to base rates are anticipated to be effective October 1, 2021.

•On April 7, 2021, the BPU approved a stipulation resolving NJNG’s annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $1.3 million annually and an increase to the NJCEP factor, resulting in an annual increase of approximately $6 million, effective April 1, 2021.

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

23

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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.

In February 2020 and March 2020, NJNG entered into treasury lock transactions to fix the benchmark treasury rate associated with a $75 million debt tranche that was issued in September 2020. Settlement of the treasury locks resulted in a $6.6 million loss, which was recorded as a component of regulatory assets on the Unaudited Condensed Consolidated Balance Sheets. The loss is being amortized into earnings over the term of the debt as a component of interest expense on the Unaudited Condensed Consolidated Statements of Operations, which totaled $54,000 and $114,000 during the three and six months ended March 31, 2021.

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.

Home Services and Other

During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with a $260 million debt issuance that was finalized in July 2020 and a $200 million debt issuance that was finalized in September 2020. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks in fiscal 2020 resulted in a loss of $13.7 million, which was recorded within OCI. The loss is being amortized into earnings over the term of the debt as a component of interest expense on the Unaudited Condensed Consolidated Statements of Operations, which totaled $263,000 and $494,000, net of tax, during the three and six months ended March 31, 2021.

Fair Value of Derivatives

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

			Derivatives at Fair Value
			March 31, 2021						September 30, 2020
(Thousands)	Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	177		$	1		$	78		$	76
Financial commodity contracts	Derivatives - current		589			88			71			282
Energy Services:
Physical commodity contracts	Derivatives - current		3,668			16,415			6,454			20,438
	Derivatives - noncurrent		1,364			20,090			1,264			12,003
Financial commodity contracts	Derivatives - current		12,770			7,166			16,671			12,965
	Derivatives - noncurrent		585			407			2,037			1,346
Foreign currency contracts	Derivatives - current		229			20			36			104
	Derivatives - noncurrent		28			9			48			3
Total fair value of derivatives			$	19,410		$	44,196		$	26,659		$	47,217

24

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 March 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	5,032		$	(1,757)		$	(200)		$	3,075
Financial commodity contracts		13,355			(7,573)						5,782
Foreign currency contracts		257			(29)						228
Total Energy Services		$	18,644		$	(9,359)		$	(200)		$	9,085
Natural Gas Distribution
Physical commodity contracts		$	177		$	(1)		$	—		$	176
Financial commodity contracts		589			(88)			—			501
Total Natural Gas Distribution		$	766		$	(89)		$	—		$	677
Derivative liabilities:
Energy Services
Physical commodity contracts		$	36,505		$	(1,757)		$	—		$	34,748
Financial commodity contracts		7,573			(7,573)			—			—
Foreign currency contracts		29			(29)			—			—
Total Energy Services		$	44,107		$	(9,359)		$	—		$	34,748
Natural Gas Distribution
Physical commodity contracts		$	1		$	(1)					$	—
Financial commodity contracts		88			(88)						—
Total Natural Gas Distribution		$	89		$	(89)		$	—		$	—
As of September 30, 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222

(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.

25

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				Six Months Ended
		March 31,				March 31,
Derivatives not designated as hedging instruments:		2021		2020		2021		2020
Energy Services:
Physical commodity contracts	Operating revenues	$	36,419	$	12,096	$	41,671	$	21,932
Physical commodity contracts	Natural gas purchases	2,650		(1,892)		(2,404)		(3,302)
Financial commodity contracts	Natural gas purchases	(27,315)		23,319		20,440		69,412
Foreign currency contracts	Natural gas purchases	27		(475)		227		(360)
Total unrealized and realized gains		$	11,781	$	33,048	$	59,934	$	87,682

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Natural Gas Distribution:
Physical commodity contracts	$	1,091	$	209	$	1,433	$	1,049
Financial commodity contracts	645		(11,434)		(3,627)		(12,522)
Interest rate contracts	—		(6,692)		—		(6,692)
Total unrealized and realized losses	$	1,736	$	(17,917)	$	(2,194)	$	(18,165)

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.

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

(Thousands)	Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives				Location of Gain (Loss) Reclassified from OCI into Income	Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income
	Three Months Ended					Three Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(342)	$	—
	Six Months Ended					Six Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(685)	$	—

26

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

		Volume (Bcf)
	Transaction Type	March 31, 2021	September 30, 2020
Natural Gas Distribution	Futures	22.1	23.7
	Physical Commodity	16.6	6.0
Energy Services	Futures	(11.6)	(27.5)
	Swaps	(0.8)	(1.8)
	Physical Commodity	1.5	5.0

Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $42,000 as of March 31, 2021 and $5.1 million as of September 30, 2020 and 1,588,000 and 960,000 SRECs that were open as of March 31, 2021 and September 30, 2020, respectively.

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	March 31, 2021		September 30, 2020
Natural Gas Distribution	Restricted broker margin accounts	$	4,190	$	13,525
Energy Services	Restricted broker margin accounts	$	41,726	$	55,919

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.

27

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of March 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		$	128,585
Noninvestment grade		9,471
Internally rated investment grade		23,661
Internally rated noninvestment grade		20,118
Total		$	181,835

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 March 31, 2021. 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)	March 31, 2021		September 30, 2020
Carrying value (1) (2) (3)	$	2,102,845	$	2,102,845
Fair market value	$	2,259,855	$	2,417,748

(1)Excludes finance leases of $68.2 million and $74.2 million as of March 31, 2021 and September 30, 2020, respectively.

(2)Excludes NJNG's debt issuance costs of $9.4 million and $9.2 million as of March 31, 2021 and September 30, 2020, respectively.

(3)Excludes NJR's debt issuance costs of $3.3 million and $3.4 million as of March 31, 2021 and September 30, 2020, 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 March 31, 2021 and September 30, 2020 was $155.6 million and $149.2 million, respectively.

28

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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 March 31, 2021, NJR discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, 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. NJR's Level 1 assets and liabilities include exchange traded natural gas futures and options contracts, listed equities and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX, CME and ICE that NJR refers 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. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG's treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:

•widely accepted and public;

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

•observable and published.

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

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

29

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of March 31, 2021:
Assets:
Physical commodity contracts		$	—		$	5,209		$	—	$	5,209
Financial commodity contracts		13,751			193			—		13,944
Financial commodity contracts - foreign exchange		—			257			—		257
Money market funds		50,368			—			—		50,368
Other		1,818			—			—		1,818
Total assets at fair value		$	65,937		$	5,659		$	—	$	71,596
Liabilities:
Physical commodity contracts		$	—		$	36,506		$	—	$	36,506
Financial commodity contracts		7,661			—			—		7,661
Financial commodity contracts - foreign exchange		—			29			—		29
Total liabilities at fair value		$	7,661		$	36,535		$	—	$	44,196
As of September 30, 2020:
Assets:
Physical commodity contracts		$	—		$	7,796		$	—	$	7,796
Financial commodity contracts		18,279			500			—		18,779
Financial commodity contracts - foreign exchange		—			84			—		84
Money market funds		112,291			—			—		112,291
Other		1,840			—			—		1,840
Total assets at fair value		$	132,410		$	8,380		$	—	$	140,790
Liabilities:
Physical commodity contracts		$	—		$	32,517		$	—	$	32,517
Financial commodity contracts		14,593			—			—		14,593
Financial commodity contracts - foreign exchange		—			107			—		107
Total liabilities at fair value		$	14,593		$	32,624		$	—	$	47,217

7. INVESTMENTS IN EQUITY INVESTEES

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

(Thousands)	March 31, 2021		September 30, 2020
Steckman Ridge (1)	$	111,435	$	112,378
PennEast (2)	103,086		95,997
Total	$	214,521	$	208,375

(1)Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2021 and September 30, 2020, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

(2)Includes a deferred tax component related to AFUDC equity of $7.6 million and $4.6 million for March 31, 2021 and September 30, 2020, respectively.

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. Due to the expiration of a customer contract in October 2020, the Company evaluated its investment in Steckman Ridge for other-than-temporary impairment and determined an impairment charge was not necessary.

30

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The fair value of the Company’s investment in Steckman Ridge was determined using a discounted cash flow method and utilized management’s best estimates and assumptions related to expected future results, including the price and capacity of firm natural gas storage contracting, operations and maintenance costs, the nature and timing of major maintenance and capital investment, and discount rates. Fair value determinations require considerable judgment and are sensitive to changes in underlying assumptions and other factors. As a result, it is reasonably possible that unfavorable developments, such as the failure to execute storage contracts and other services for available capacity at anticipated price levels could result in an other-than temporary impairment charge in the Unaudited Condensed Consolidated Financial Statements.

PennEast

The Company, through its subsidiary NJR Pipeline Company, is a 20 percent investor in PennEast, a partnership whose purpose is to construct and operate a 120-mile natural gas pipeline that will extend from northeast Pennsylvania to western New Jersey. PennEast received a Certificate of Public Convenience and Necessity for the project from FERC on January 19, 2018.

On September 10, 2019, the Third Circuit issued an order overturning the United States District Court for the District of New Jersey’s order granting PennEast condemnation and immediate access in accordance with the Natural Gas Act to certain properties in which the State of New Jersey holds an interest. A Petition for Rehearing was denied by the Third Circuit on November 5, 2019.

On October 8, 2019, the NJDEP issued a letter indicating that it deemed PennEast’s freshwater wetlands permit application to be administratively incomplete and closed the matter without prejudice. On October 11, 2019, PennEast submitted a letter to the NJDEP objecting to its position that the application is administratively incomplete. PennEast's objections were rejected by the NJDEP on November 18, 2019.

On October 4, 2019, PennEast filed a petition for Declaratory Order with FERC requesting an interpretation of the eminent domain authority of a FERC certificate holder under the Natural Gas Act. The Declaratory Order was granted on January 30, 2020.

On January 30, 2020, PennEast filed an amendment with FERC to construct the PennEast pipeline in two phases. Phase one consists of construction of a 68-mile pipeline in Pennsylvania from the eastern Marcellus Shale region in Luzerne County that would terminate in Northampton County. Phase two includes construction of the remaining original certificated route in Pennsylvania and New Jersey. Construction is expected to begin following approval by FERC of the phased approach and receipt of any remaining governmental and regulatory permits.

On February 18, 2020, PennEast filed a writ of certiorari with the Supreme Court of the United States to review the September 10, 2019 Third Circuit decision.

On June 29, 2020, the Supreme Court requested that the Solicitor General of the United States file a brief that expresses the views on the question of the use of eminent domain to acquire state owned lands for pipeline construction. The Solicitor General filed its brief with the Supreme Court on December 9, 2020.

The State of New Jersey filed a brief with the Supreme Court on December 23, 2020 in response to the brief of the Solicitor General.

On February 3, 2021, the Supreme Court granted the petition for a writ of certiorari. The matter was argued before the Supreme Court on April 28, 2021.

The Company evaluated its investment in PennEast for an other-than-temporary impairment and determined an impairment charge was not necessary. It is reasonably possible that future unfavorable developments, such as a reduced likelihood of success from development options and legal outcomes, estimated increases in construction costs, increases in the discount rate, or further significant delays, could result in an impairment of the Company's equity method investment. Also, the use of alternate judgments and assumptions could result in a different calculation of fair value, which could ultimately result in the recognition of an impairment charge.

31

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

8. EARNINGS PER SHARE

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands, except per share amounts)	2021		2020		2021		2020
Net income, as reported	$	149,809	$	73,846	$	230,854	$	149,598
Basic earnings per share
Weighted average shares of common stock outstanding-basic	96,248		95,584		96,181		93,747
Basic earnings per common share	$1.56		$0.78		$2.40		$1.60
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	96,248		95,584		96,181		93,747
Equity forward sale agreement (1)	—		—		—		4
Other (2)	370		306		417		322
Weighted average shares of common stock outstanding-diluted	96,618		95,890		96,598		94,073
Diluted earnings per common share (3)	$1.55		$0.77		$2.39		$1.59

(1)See Note 14. Common Stock Equity for details regarding the forward sale agreement.

(2)Consist primarily of unvested stock awards and performance shares.

(3)There were anti-dilutive shares of 24,101 and 30,708 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement during the three months ended March 31, 2021 and 2020. There were anti-dilutive shares of 65,334 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement during the six months ended March 31, 2021. There were no anti-dilutive shares excluded during the six months ended March 31, 2020.

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)	March 31, 2021			September 30, 2020			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	425,000		$	425,000		December 2023
Notes outstanding at end of period	$	8,500		$	125,350
Weighted average interest rate at end of period	1.75		%	1.49		%
Amount available at end of period (2)	$	406,206		$	289,356
Bank revolving credit facilities (1)	$	—		$	250,000
Notes outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (2)	$	—		$	250,000
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		December 2023
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2)Letters of credit outstanding total $10.3 million for both March 31, 2021 and September 30, 2020, which reduces 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 for both March 31, 2021 and September 30, 2020, which reduces the amount available by the same amount.

32

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

On April 24, 2020, NJR entered into a 364-day $250 million revolving credit facility with an interest rate based on LIBOR plus 1.625 percent. After six months, all outstanding amounts under the credit facility would convert to a term loan and would be due on April 23, 2021. In connection with entry into this credit facility, all outstanding borrowings under NJR's December 13, 2019, $150 million revolving line of credit facility were repaid. On October 24, 2020, there was no balance outstanding on the $250 million credit facility. As a result, the credit facility was considered terminated.

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

NJNG received $4.0 million in December 2019, in connection with the sale leaseback of its natural gas meters. NJNG records a capital lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease. NJNG exercised early purchase options with respect to certain outstanding meter leases by making final principal payments of $1.2 million for both the six months ended March 31, 2021 and 2020. There were no natural gas meter sale leasebacks recorded during the six months ended March 31, 2021.

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 SREC, TRECs and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if applicable. Clean Energy Ventures continues to operate the solar assets, including related expenses, and retain the revenue generated from SRECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. In December 2020, Clean Energy Ventures received proceeds of $12.1 million in connection with the sale leaseback of two commercial solar projects. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during the six months ended March 31, 2020.

10. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

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

	Pension								OPEB
	Three Months Ended				Six Months Ended				Three Months Ended				Six Months Ended
	March 31,				March 31,				March 31,				March 31,
(Thousands)	2021		2020		2021		2020		2021		2020		2021		2020
Service cost	$	2,183	$	2,055	$	4,365	$	4,111	$	1,211	$	1,072	$	2,422	$	2,427
Interest cost	2,278		2,646		4,556		5,293		1,517		1,509		3,035		3,513
Expected return on plan assets	(4,851)		(5,232)		(10,075)		(10,289)		(1,565)		(1,695)		(3,248)		(3,255)
Recognized actuarial loss	2,861		2,466		5,723		5,212		1,978		930		3,955		3,721
Prior service cost (credit) amortization	26		26		51		51		(45)		(50)		(90)		(99)
Net periodic benefit cost	$	2,497	$	1,961	$	4,620	$	4,378	$	3,096	$	1,766	$	6,074	$	6,307

The Company does not expect to be required to make additional contributions to fund the pension plans during fiscal 2020 or 2021 based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents. In addition, as in the past, the Company may elect to make contributions in excess of the minimum required amount to the plans. There were no discretionary contributions made during the six months ended March 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.

33

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The Company's OPEB liability was revalued for changes related to the Affordable Care Act-mandated excise tax applicable to high-cost health plans, commonly known as the Cadillac Tax. The Company applied a practical expedient to remeasure the plan assets and obligations as of December 31, 2019, which was the nearest calendar month-end date. The impact of the revaluation of the OPEB liability was recorded as of January 1, 2020.

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, NJR 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.

NJR 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.

The Company evaluates certain tax benefits that have been recorded in the financial statements for uncertainties. During fiscal 2019 the Company concluded that a portion of tax benefits were uncertain at this time. As a result, the Company recorded a reserve that was included in accrued taxes on the Unaudited Condensed Consolidated Balance Sheets. During fiscal 2021, a tax audit was completed and the positions that the prior tax reserves related to are now considered effectively settled and the tax reserve has been released. As a result of the change in the Company's method of accounting for ITCs from the flow through method to the deferral method, which was effective October 1, 2020, the settlement of the reserve was recorded as an adjustment to nonutility plant and equipment, at cost on the Unaudited Condensed Consolidated Balance Sheets.

The reserve for uncertain tax benefits is as follows:

(Thousands)	March 31, 2021		September 30, 2020
Balance at October 1,	$	4,930	$	4,930
Settlements	(4,930)		—
Balance at period end	$	—	$	4,930

The tax benefits related to fiscal tax years open to examination by the IRS may be subject to subsequent adjustments.

On March 27, 2020, the President of the U.S. signed the CARES Act, which is aimed at providing emergency assistance and health care for individuals, families, and businesses affected by the COVID-19 pandemic and generally supporting the U.S. economy. The CARES Act, among other things, includes several business tax provisions which include, but are not limited to modifications of federal net operating loss carrybacks and deductibility, changes to prior year refundable alternative minimum tax liabilities, increase of limitations on business interest deductions from 30 percent to 50 percent of earnings before interest, taxes, depreciation, and amortization, technical corrections of the classification of qualified improvement property making them eligible for bonus depreciation, increase of the limits on charitable contribution deductions from 10 percent to 25 percent of adjusted taxable income, modifications of the treatment of federal loans, loan guarantees, and other investments, suspension of industry specific excise taxes, deferral of the company portion of OASDI, and implementation of a refundable employee retention tax credit.

The CARES Act provides for the delay in the required deposit of the employer portion of the OASDI payroll tax from the date of enactment through the end of 2020. Of the taxes that the Company can defer, 50 percent of the deferred taxes are required to be deposited by the end of 2021 and the remaining 50 percent are required to be deposited by the end of 2022. Additionally, The CARES Act provides a refundable tax credit, the employee retention tax credit, to certain employers who are ordered by a competent governmental authority to suspend or reduce business operations due to concern about the spread of COVID-19 or suffered a significant decline in the business during a calendar quarter during 2020 compared to the same calendar quarter during the previous year. As of March 31, 2021 and September 30, 2020, the Company deferred $5.1 million and $3.1 million, respectively, related to the employer portion of the OASDI tax.

34

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

On March 11, 2021, the President of the U.S. signed the American Rescue Plan Act of 2021, which is primarily an economic stimulus package. It also expanded the scope of Section 162(m) of the Internal Revenue Code, which imposes a $1 million deduction limit on compensation paid to covered employees from the top five officers to include the additional top five highest paid employees for tax years beginning after December 31, 2026.

Effective Tax Rate

The forecasted effective tax rates were 19.9 percent and 19.4 percent, for the six months ended March 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 six months ended March 31, 2021, discrete items totaled $(145,000) related to excess tax expense associated with the vesting of share-based awards. During the six months ended March 31, 2020, discrete items totaled $2.7 million related to a revaluation of certain state deferred tax assets and liabilities as a result of a change in the New Jersey state apportionment factor and excess tax benefits associated with the vesting of share-based awards. NJR’s actual effective tax rate was 19.7 percent and 18.0 percent during the six months ended March 31, 2021 and 2020, respectively.

Other Tax Items

As of March 31, 2021 and September 30, 2020, the Company has federal income tax net operating losses of approximately $134.0 million. Federal net operating losses can generally be carried back two years and forward 20 years and will begin to expire in fiscal 2036, with the remainder expiring by 2038. The Company expects to exercise its ability to carryback federal net operating losses to offset taxable income in prior periods.

For the net operating losses it expects to carryback, the Company estimated the portion considered refundable and recorded receivables of approximately $22.8 million as of March 31, 2021 and September 30, 2020, as a component of other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets. Upon filing amended federal income tax returns to carryback its remaining federal net operating losses totaling $24.1 million, the Company will reduce its taxable income in those periods and recapture ITCs of the same amount that were previously utilized to offset taxable income.

In addition, as of March 31, 2021 and September 30, 2020, the Company has tax credit carryforwards of approximately $193.2 million and $195.2 million, respectively, which each have a life of 20 years. When the Company carries back the federal net operating losses noted above, it expects to recapture investment tax credits totaling $24.1 million. These recaptured tax credits are in addition to the $193.2 million and will be carried forward to offset future taxable income. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2034.

As of March 31, 2021 and September 30, 2020, the Company has state income tax net operating losses of approximately $442.4 million and $487.7 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 would begin to expire in fiscal 2021, with the majority expiring after 2035. The Company expects to utilize this entire carryforward, other than as described below.

As of March 31, 2021 and September 30, 2020, the Company has a valuation allowance of $17.6 million, which is primarily related to the recognition of state net operating loss carryforwards in New Jersey.

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.

35

New Jersey Resources Corporation

Part I

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 leases terms are between 15 and 35 years and may include multiple options to extend the terms for an additional five to 10 years. The Company’s office leases vary in duration, ranging from one to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of seven years with purchase options available prior to the end of the seven year term. Equipment leases include general office equipment that also vary in duration, most of which are for a term of five 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				Six Months Ended
		March 31,				March 31,
(Thousands)	Income Statement Location	2021		2020		2021		2020
Operating lease cost (1)	Operation and maintenance	$	1,356	1,719		3,445		3,111
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	1,191	$	1,299	$	2,437	$	2,460
Interest on lease liabilities	Interest expense, net of capitalized interest	113		301		334		548
Total finance lease cost		1,304		1,600		2,771		3,008
Short-term lease cost	Operation and maintenance	127		172		254		626
Variable lease cost	Operation and maintenance	549		403		702		1,110
Total lease cost		$	3,336	$	3,894	$	7,172	$	7,855

(1)Net of capitalized costs.

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

	Six Months Ended
	March 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,932	$	2,856
Operating cash flows for finance leases	$	791	$	704
Financing cash flows for finance leases	$	5,690	$	4,038

Assets obtained or modified through amendments in exchange for operating lease liabilities totaled $5.7 million and $12.4 million during the three months ended March 31, 2021 and 2020, respectively, and totaled $13.3 million and $34.0 million during the six months ended March 31, 2021 and 2020, respectively. Assets obtained or modified through finance lease liabilities totaled $45.7 million and $49.7 million during the three and six months ended March 31, 2020, respectively. There were no assets obtained or modified through finance lease liabilities during the three and six months ended March 31, 2021.

36

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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	March 31, 2021		September 30, 2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	144,326	$	131,769
Finance lease assets	Utility plant	61,432		71,085
Total lease assets		$	205,758	$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,001	$	6,724
Finance lease liabilities	Current maturities of long-term debt	5,855		10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	111,034		95,030
Finance lease liabilities	Long-term debt	62,334		63,743
Total lease liabilities		$	183,224	$	175,913

For operating lease assets and liabilities, the weighted average remaining lease term was 27.6 years and 25.5 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.3 percent and 3.2 percent as of March 31, 2021 and September 30, 2020, respectively. For finance lease assets and liabilities as of March 31, 2021 and September 30, 2020, the weighted average remaining lease term was 11.9 years and 11.5 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.5 percent as of both March 31, 2021 and September 30, 2020.

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 $156.0 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 March 31, 2021, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2021		2022		2023		2024		2025		Thereafter
Energy Services:
Natural gas purchases	$	98,845	$	—	$	—	$	—	$	—	$	—
Storage demand fees	18,712		14,248		6,712		3,318		2,742		277
Pipeline demand fees	60,585		49,224		21,689		18,673		16,245		34,074
Sub-total Energy Services	$	178,142	$	63,472	$	28,401	$	21,991	$	18,987	$	34,351
NJNG:
Natural gas purchases	$	32,320	$	—	$	—	$	—	$	—	$	—
Storage demand fees	37,285		28,593		17,090		11,506		2,207		2,495
Pipeline demand fees	118,672		150,719		136,124		158,600		154,297		1,437,814
Sub-total NJNG	$	188,277	$	179,312	$	153,214	$	170,106	$	156,504	$	1,440,309
Total	$	366,419	$	242,784	$	181,615	$	192,097	$	175,491	$	1,474,660

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

37

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of 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, and Freehold, New Jersey, collectively, the "former MGP sites", including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future expenditures at the former MGP sites for which it is responsible, including potential liabilities for further and continued natural resource damages, may be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites. At the MGP site in Freehold, New Jersey, as the Company has not yet completed the remedial investigation of the site, the total amount of potential costs of all remedial actions cannot be reasonably estimated at this time.

The estimated total future expenditures for all former MGP sites will range from approximately $143.1 million to $181.7 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, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets of $143.5 million as of March 31, 2021, and $150.6 million as of September 30, 2020, based on the most likely amount. The remediation liability at March 31, 2021, includes adjustments for actual expenditures during fiscal 2021. 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. NJNG will continue to gather information to determine whether the obligation exists to undertake remedial action.

NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. On September 9, 2020, the BPU approved NJNG's increase in the RAC, which increased the annual recovery from $8.5 million to $9.7 million and is effective October 1, 2020. As of March 31, 2021, $37.5 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, NJR 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. NJR also discloses contingent matters for which there is a reasonable possibility of a loss. Based upon currently available information, NJR believes that the results of litigation that is 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.

38

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The foregoing statements about NJR’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.

14. COMMON STOCK EQUITY

In December 2019, the Company completed an equity offering of 6,545,454 common shares, consisting of 5,333,334 common shares issued directly by the Company and 1,212,120 common shares issuable pursuant to forward sales agreements with investment banks. The issuance of 5,333,334 resulted in proceeds of approximately $212.9 million, net of issuance costs, and was reflected in shareholders' equity and as a financing activity on the statement of cash flows.

Under the forward sale agreements, a total of 1,212,120 common shares were borrowed from third parties and sold to the underwriters. Each forward sale agreement allows the Company, at its election and prior to September 30, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement, which was initially $40.0125 per share, or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as anticipated dividends.

On September 18, 2020, the Company amended its forward sale agreements to extend the maturity date of such forward sales agreements from September 30, 2020 to September 10, 2021. On March 3, 2021, the Company cash settled a portion of the forward sale agreement for a payout of $387,744 for 727,272 common shares. As of March 31, 2021, if the Company elected to net settle the remaining forward sale agreement, the Company would have paid approximately $1.4 million under a cash settlement or would have issued 31,607 common shares under a net share settlement.

Issuances of shares under the forward sale agreements are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreements have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method until settlement of the forward sale agreements. Under this method, the number of the Company common shares used in calculating diluted EPS is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreements less the number of shares that would be purchased by the Company in the market (based on the average market price during the same reporting period) using the proceeds receivable upon settlement (based on the adjusted forward sale price at the end of that reporting period). Share dilution occurs when the average market price of the Company's common shares is higher than the adjusted forward sale price. See Note 8. Earnings Per Share for the impact of the forward sale agreements on the calculation of diluted earnings per share.

15. 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.

39

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues
Natural Gas Distribution
External customers	$	310,167	$	297,220	$	505,896	$	516,843
Clean Energy Ventures
External customers	6,476		5,995		12,846		12,207
Energy Services
External customers (1)	459,766		313,959		687,115		682,263
Intercompany	2,803		(258)		4,931		1,853
Storage and Transportation
External customers	13,257		10,401		25,704		18,806
Intercompany	669		675		1,326		1,342
Subtotal	793,138		627,992		1,237,818		1,233,314
Home Services and Other
External customers	12,521		12,039		24,931		24,531
Intercompany	252		326		419		741
Eliminations	(3,724)		(743)		(6,676)		(3,936)
Total	$	802,187	$	639,614	$	1,256,492	$	1,254,650
Depreciation and amortization
Natural Gas Distribution	$	19,475	$	18,100	$	38,644	$	34,917
Clean Energy Ventures	4,685		6,603		10,118		12,919
Energy Services (2)	13		27		55		56
Storage and Transportation	2,364		2,397		5,004		4,078
Subtotal	26,537		27,127		53,821		51,970
Home Services and Other	227		250		487		496
Eliminations	84		139		(98)		(313)
Total	$	26,848	$	27,516	$	54,210	$	52,153
Interest income (3)
Natural Gas Distribution	$	76	$	136	$	158	$	243
Clean Energy Ventures	240		—		240		—
Energy Services	—		52		—		89
Storage and Transportation	851		2,085		1,545		2,782
Subtotal	1,167		2,273		1,943		3,114
Home Services and Other	127		208		259		699
Eliminations	(237)		(760)		(476)		(1,906)
Total	$	1,057	$	1,721	$	1,726	$	1,907

(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.

40

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Interest expense, net of capitalized interest
Natural Gas Distribution	$	9,006	$	7,473	$	17,980	$	15,305
Clean Energy Ventures	5,266		4,835		10,300		9,327
Energy Services	575		937		1,255		2,163
Storage and Transportation	3,578		5,621		7,560		8,443
Subtotal	18,425		18,866		37,095		35,238
Home Services and Other	1,728		565		2,844		837
Eliminations	—		(228)		—		(802)
Total	$	20,153	$	19,203	$	39,939	$	35,273
Income tax provision (benefit)
Natural Gas Distribution	$	15,622	$	19,702	$	23,989	$	28,337
Clean Energy Ventures	(2,714)		(4,134)		(5,800)		(7,968)
Energy Services	23,128		(2,449)		35,250		8,303
Storage and Transportation	873		1,105		1,519		1,807
Subtotal	36,909		14,224		54,958		30,479
Home Services and Other	(59)		1,956		59		2,175
Eliminations	2,207		104		1,481		101
Total	$	39,057	$	16,284	$	56,498	$	32,755
Equity in earnings of affiliates
Storage and Transportation	$	3,386	$	3,921	$	6,579	$	7,585
Eliminations	(582)		(332)		(1,100)		(607)
Total	$	2,804	$	3,589	$	5,479	$	6,978
Net financial earnings (loss)
Natural Gas Distribution	$	80,541	$	86,336	$	130,008	$	130,192
Clean Energy Ventures	(8,872)		(8,829)		(19,146)		(17,008)
Energy Services	96,528		2,487		98,028		(2,635)
Storage and Transportation	4,711		4,258		8,219		7,262
Subtotal	172,908		84,252		217,109		117,811
Home Services and Other	747		148		685		1,257
Eliminations	(3,051)		(109)		(2,533)		154
Total	$	170,604	$	84,291	$	215,261	$	119,222
Capital expenditures
Natural Gas Distribution	$	97,239	$	72,042	$	176,485	$	149,839
Clean Energy Ventures	18,549		24,087		40,884		69,786
Storage and Transportation	20,094		5,148		27,707		7,709
Subtotal	135,882		101,277		245,076		227,334
Home Services and Other	125		(111)		811		15
Total	$	136,007	$	101,166	$	245,887	$	227,349
Investments in equity investees
Storage and Transportation	$	196	$	757	$	482	$	1,266
Total	$	196	$	757	$	482	$	1,266

41

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Net financial earnings	$	170,604	$	84,291	$	215,261	$	119,222
Less:
Unrealized gain on derivative instruments and related transactions	29,255		(3,773)		(8,235)		(45,539)
Tax effect	(6,954)		897		1,958		10,828
Effects of economic hedging related to natural gas inventory	(7,209)		14,622		(14,741)		5,735
Tax effect	1,713		(3,475)		3,503		(1,363)
NFE tax adjustment	3,990		2,174		1,922		(37)
Net income	$	149,809	$	73,846	$	230,854	$	149,598

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 is 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. Additionally, realized derivative gains and losses are also included in current period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical natural gas flows. Included in the tax effects are current and deferred income tax expense corresponding with the NFE. NJR also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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

(Thousands)	March 31, 2021		September 30, 2020
Assets at end of period:
Natural Gas Distribution	$	3,593,630	$	3,531,477
Clean Energy Ventures	848,290		814,277
Energy Services	224,069		244,836
Storage and Transportation	874,976		844,799
Subtotal	5,540,965		5,435,389
Home Services and Other	136,531		138,375
Intercompany assets (1)	(252,362)		(257,287)
Total	$	5,425,134	$	5,316,477

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

42

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

16. 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 March 31, 2021, Energy Services has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2021.

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Natural Gas Distribution	$	1,505	$	1,477	$	3,073	$	2,971
Energy Services	226		29		391		59
Total	$	1,731	$	1,506	$	3,464	$	3,030

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

(Thousands)	March 31, 2021		September 30, 2020
Natural Gas Distribution	$	775	$	775
Energy Services	78		16
Total	$	853	$	791

NJNG and Energy Services have entered into various asset management agreements, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. As of March 31, 2021, NJNG and Energy Services had three asset management agreements with expiration dates ranging from October 31, 2021 through March 31, 2022.

NJNG has entered into a 15-year transportation precedent agreement for committed capacity of 180,000 Dths per day and NJRES has entered into a 5-year, 50,000 Dths per day transportation precedent agreement with PennEast, both to commence when PennEast is placed in service.

NJNG has entered into a transportation precedent agreement with Adelphia Gateway for committed capacity of 130,000 Dths per day, which expires in October 2026.

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. On February 19, 2021, Energy Services entered into a park and loan agreement with Leaf River for 330,000 Dths, which expired on April 30, 2021 and is eliminated in consolidation.

NJNG and Clean Energy Ventures entered into a sublease agreement and PPA agreement related to an onsite solar array and the related energy output at the Company’s headquarters in Wall, New Jersey.

17. ACQUISITIONS AND DISPOSITIONS

Acquisitions

Adelphia Gateway

On January 13, 2020, Adelphia Gateway, an indirect wholly-owned subsidiary of NJR, acquired all of Talen’s membership interests in IEC, an existing 84-mile pipeline in southeastern Pennsylvania, including related assets and rights of

43

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

way, for a base purchase price of $166 million. In November 2017, the Company made an initial payment of $10 million towards the base purchase price, which was included in other noncurrent assets on the Consolidated Balance Sheets. The remaining purchase price of $156 million was paid upon the close of the acquisition of the related assets. As additional consideration, Adelphia Gateway will pay Talen specified amounts of up to $23 million contingent upon the achievement of certain regulatory approvals and binding natural gas capacity commitments. On December 20, 2019, FERC issued Adelphia Gateway’s Certificate of Public Convenience and Necessity. Adelphia Gateway has agreed to provide firm natural gas transportation service for 10 years following the closing to two power generators owned by affiliates of Talen that are currently served by the pipeline.

The Company evaluated the acquisition under the guidance of ASU 2017-01, Clarifying the Definition of a Business and concluded that the acquisition did not meet the definition of a business, as almost all of the fair value relates to the pipeline assets acquired. As a result, the purchase was accounted for as an asset acquisition.

The following table summarizes the consideration transferred and purchase price allocation based upon the relative fair value of the assets acquired and liabilities to be assumed:

(Thousands)	Estimated Fair Value
Purchase price	$	166,000
Net working capital adjustment	(449)
Transaction costs	9,456
Total costs capitalized	$	175,007
Identifiable assets acquired
Property, plant and equipment	$	174,438
Other	1,018
Net working capital	(449)
Net assets acquired	$	175,007

The Company utilized a discounted cash flow valuation technique to measure the fair value of the property, plant, and equipment based upon the present value of their future economic benefits reflecting current market expectations. The assumptions used in the discounted cash flow valuation are not observable in active markets and thus represent non-recurring Level 3 fair value measurements.

Property, plant and equipment consist primarily of pipeline related assets, land, buildings and other structures and software. Depreciation is computed on a straight-line basis over the estimated useful life of the assets, ranging from five to 30 years, based on various classes of depreciable property. Other assets consist primarily of an assembled workforce and base natural gas.

Asset retirement obligations are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The Company records any asset retirement obligations in the period in which information permitting a reasonable estimate of such obligation becomes available. The Company is unable to predict when, or if, the pipelines would become completely obsolete and require decommissioning. As such, upon acquisition, there were no liabilities recorded for asset retirement obligations, as both the timing and future estimates of decommissioning the pipeline was indeterminable.

Leaf River

On October 11, 2019, NJR Pipeline Company, an indirect wholly-owned subsidiary of NJR, acquired 100 percent of the issued and outstanding limited liability company interests of Leaf River Energy Center LLC for $367.5 million. The purchase price was subject to certain contractual conditions, including customary purchase price adjustments related to the amount of net working capital and transaction expenses. Leaf River owns and operates a 32.2 million Dth salt dome natural gas storage facility, located in southeastern Mississippi.

44

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)                     

The Company evaluated the acquisition under the guidance of ASU 2017-01, Clarifying the Definition of a Business and concluded that the acquisition did not meet the definition of a business, as almost all of the fair value relates to the natural gas storage assets acquired. As a result, the purchase was accounted for as an asset acquisition.

The following table summarizes the consideration transferred and purchase price allocation based upon the relative fair value of the assets acquired and liabilities to be assumed:

(Thousands)	Estimated Fair Value
Purchase price	$	367,500
Net working capital adjustment	4,111
Transaction costs	1,664
Total costs capitalized	$	373,275
Identifiable assets acquired
Property, plant and equipment	$	365,715
Base gas	3,445
Other assets, net	4
Net working capital	4,111
Net assets acquired	$	373,275

The total consideration transferred is comprised of the purchase price to the seller and the transaction costs incurred during the acquisition. The Company utilized a discounted cash flow valuation technique to measure the fair value of the property, plant, and equipment based upon the present value of their future economic benefits reflecting current market expectations. Base gas is valued based upon the estimated replacement costs associated with the respective assets.

Base gas is needed to maintain the necessary pressure to allow efficient operation of the storage facility. The base gas is determined to be recoverable and is considered a component of the facility and presented as a component in property, plant and equipment. This natural gas is not depreciated, as it is expected to be recovered and sold.

Property, plant and equipment consist primarily of surface equipment and pipelines necessary to operate the facility. Depreciation is computed on a straight-line basis over the estimated useful life of the assets, ranging from five to 50 years, based on various classes of depreciable property.

Asset retirement obligations are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The Company records any asset retirement obligations in the period in which information permitting a reasonable estimate of such obligation becomes available. The Company is unable to predict when, or if, the storage facilities and related pipelines would become completely obsolete and require decommissioning. As such, upon acquisition, there were no liabilities recorded for asset retirement obligations, as both the timing and future estimates of decommissioning the storage facilities and related pipelines were indeterminable.

The assumptions used in the discounted cash flow valuation are not observable in active markets and thus represent non-recurring Level 3 fair value measurements.

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

OPERATIONS                                                                                                                                                                                  

Critical Accounting Policies

A summary of our critical accounting policies is included in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10-K for the period ended September 30, 2020. Our critical accounting policies have not changed from those reported in the 2020 Annual Report on Form 10-K.

Recently Issued Accounting Standards

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

45

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Management's Overview

Consolidated

NJR is an energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in the U.S. and Canada. In addition, we invest in clean energy projects, storage and transportation assets and provide various repair, sales and installations services. A more detailed description of our organizational structure can be found in Item 1. Business of our 2020 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 closely monitor developments related to the COVID-19 pandemic and have taken steps intended to limit potential exposure for our employees and those we serve. We have also taken proactive steps to ensure business continuity in the safe operation of our business. Both NJR and NJNG continue to have sufficient liquidity to meet their current obligations and business operations remain fundamentally unchanged at this time. This remains an evolving situation, and we cannot predict the extent or duration of the outbreak, the effects of the pandemic on the global, national or local economy, or its effects on our financial condition, results of operations and cash flows. We cannot predict the nature and extent of impacts to future operations. 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.

46

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Operating Results

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

	Three Months Ended								Six Months Ended
	March 31,								March 31,
(Thousands)	2021				2020				2021				2020
Net income (loss)
Natural Gas Distribution	$	80,541	54	%	$	86,336	117	%	$	130,008	56	%	$	130,192	87	%
Clean Energy Ventures	(8,872)		(6)		(8,829)		(12)		(19,146)		(8)		(17,008)		(11)
Energy Services	75,662		51		(8,435)		(11)		114,534		49		27,590		18
Storage and Transportation	4,711		3		4,258		6		8,219		4		7,262		5
Home Services and Other	747		—		148		—		685		—		1,257		1
Eliminations (1)	(2,980)		(2)		368		—		(3,446)		(1)		305		—
Total	$	149,809	100	%	$	73,846	100	%	$	230,854	100	%	$	149,598	100	%

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

The increase in net income during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, was driven primarily by increased earnings at Energy Services due to strong market demand related to the extreme cold weather during February 2021. The primary drivers of the changes noted above are described in more detail in the individual segment discussions.

Assets by reporting segment and operations are as follows:

(Thousands)	March 31, 2021				September 30, 2020
Assets
Natural Gas Distribution	$	3,593,630	66	%	$	3,531,477	66	%
Clean Energy Ventures	848,290		16		814,277		15
Energy Services	224,069		4		244,836		5
Storage and Transportation	874,976		16		844,799		16
Home Services and Other	136,531		3		138,375		3
Intercompany assets (1)	(252,362)		(5)		(257,287)		(5)
Total	$	5,425,134	100	%	$	5,316,477	100	%

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

The increase in assets was due primarily to additional utility plant and an increase in solar asset investments at Clean Energy Ventures, along with an increase in accounts receivable and at our Natural Gas Distribution and Energy Services segments.

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. There is a related tax effect on current and deferred income tax expense corresponding with this non-GAAP measure. To the extent we utilize forwards, futures, or other derivatives to hedge forecasted SREC production, unrealized gains and losses are also eliminated for NFE purposes.

GAAP requires us, during the interim periods, to estimate our annual effective tax rate and use this rate to calculate the year-to-date tax provision. We also determine an annual estimated effective tax rate for NFE purposes and calculate a quarterly tax adjustment based on the differences between our forecasted net income and our forecasted NFE for the fiscal year. Since the annual estimated effective tax rate is based on certain forecasted assumptions, 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.

47

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Non-GAAP financial measures 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				Six Months Ended
	March 31,				March 31,
(Thousands, except per share data)	2021		2020		2021		2020
Net income	$	149,809	$	73,846	$	230,854	$	149,598
Add:
Unrealized gain on derivative instruments and related transactions	29,255		(3,773)		(8,235)		(45,539)
Tax effect	(6,954)		897		1,958		10,828
Effects of economic hedging related to natural gas inventory (1)	(7,209)		14,622		(14,741)		5,735
Tax effect	1,713		(3,475)		3,503		(1,363)
NFE tax adjustment	3,990		2,174		1,922		(37)
Net financial earnings	$	170,604	$	84,291	$	215,261	$	119,222
Basic earnings per share	$	1.56	$	0.78	$	2.40	$	1.60
Add:
Unrealized gain on derivative instruments and related transactions	0.30		(0.04)		(0.09)		(0.49)
Tax effect	(0.08)		0.01		0.02		0.11
Effects of economic hedging related to natural gas inventory (1)	(0.07)		0.15		(0.15)		0.06
Tax effect	0.02		(0.04)		0.04		(0.01)
NFE tax adjustment	0.04		0.02		0.02		—
Basic NFE per share	$	1.77	$	0.88	$	2.24	$	1.27

(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								Six Months Ended
	March 31,								March 31,
(Thousands)	2021				2020				2021				2020
Net financial earnings (loss)
Natural Gas Distribution	$	80,541	47	%	$	86,336	102	%	$	130,008	60	%	$	130,192	109	%
Clean Energy Ventures	(8,872)		(5)		(8,829)		(10)		(19,146)		(9)		(17,008)		(14)
Energy Services	96,528		57		2,487		3		98,028		46		(2,635)		(2)
Storage and Transportation	4,711		3		4,258		5		8,219		4		7,262		6
Home Services and Other	747		—		148		—		685		—		1,257		1
Eliminations (1)	(3,051)		(2)		(109)		—		(2,533)		(1)		154		—
Total	$	170,604	100	%	$	84,291	100	%	$	215,261	100	%	$	119,222	100	%

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

The increase in NFE during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, was due primarily to increased earnings at Energy Services as previously discussed.

Natural Gas Distribution Segment

Overview

Our Natural Gas Distribution segment is comprised of NJNG, a natural gas utility that provides regulated retail natural gas service throughout Burlington, Middlesex, Monmouth, Morris and Ocean counties in New Jersey to approximately 561,500 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 and may include but is 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

48

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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 receives most of its natural gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the year.

As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 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.

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 six months ended March 31, 2021, and estimates of expected investments for fiscal 2021 and 2022:

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

On February 28, 2019, NJNG filed a petition with the BPU seeking authority to implement a five-year IIP. The IIP consists of two components: transmission and distribution investments and information technology replacement and enhancements. The total investment for the IIP is approximately $507 million. All approved investments will be recovered through annual filings to adjust base rates. On October 28, 2020, the BPU approved the Company’s transmission and

49

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

distribution component of the IIP for $150 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 must be requested for recovery in base rate cases, of which $23.4 million was approved in NJNG’s 2019 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.

On March 30, 2020, NJNG filed a petition with the BPU requesting a rate increase of approximately $7.4 million for the recovery associated with NJ RISE and SAFE II capital investment costs of approximately $57.9 million. On July 24, 2020, the Company updated the filing with actual information through June 30, 2020 and the revised rate increase requested was $7.1 million based on $55.1 million of actual capital investments. On September 9, 2020, the BPU approved the increase to base rate revenue, effective October 1, 2020.

On March 31, 2021, NJNG filed a petition with the BPU requesting the final base rate increase of approximately $311,000 for the recovery associated with NJ RISE and SAFE II capital investments cost of approximately $3.4 million made through June 30, 2021. This filing will be updated for actual information through June 30, 2021. Changes to base rates are anticipated to be effective October 1, 2021.

Southern Reliability Link

The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG’s service territory. Construction began on the project in December 2018 and is estimated to cost between $290 million and $310 million upon completion. On March 30, 2021, NJNG filed a base rate case with the BPU requesting rate recovery for SRL and other infrastructure investments. SRL is expected to be placed in service during fiscal 2021.

Customer Growth

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

NJNG's total customers include the following:

	March 31, 2021	March 31, 2020
Firm customers
Residential	498,583	491,419
Commercial, industrial & other	31,313	30,545
Residential transport	22,574	22,783
Commercial transport	8,971	9,230
Total firm customers	561,441	553,977
Other	45	59
Total customers	561,486	554,036

50

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

During the six months ended March 31, 2021 and 2020, respectively, NJNG added 3,694 and 4,339 new customers. NJNG expects these new customer additions, and those customers who added additional natural gas services to their premises to contribute approximately $2.7 million to utility gross margin during the fiscal year.

NJNG continues to expect to add approximately 28,000 to 30,000 new customers during the three-year period of fiscal 2021 to 2023. 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 $6.3 million annually, as calculated under NJNG's CIP tariff. See the Natural Gas Distribution Segment Operating Results section of Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations that follows for a definition and further discussion of utility gross margin.

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. On March 3, 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, to be effective July 1, 2021.

On May 29, 2020, NJNG filed a petition with the BPU to minimally decrease its EE recovery rate. Throughout the course of the proceeding, NJNG updated the filing with additional actual information. Based on the updated information, 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.

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

(Thousands)	March 31, 2021		September 30, 2020
Loans	$	126,400	$	119,400
Grants, rebates and related investments	82,900		80,500
Total	$	209,300	$	199,900

Program recoveries from customers during the six months ended March 31, 2021 and 2020, were $5.3 million and $4.5 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 9.75 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. In May 2014, the BPU approved the continuation of the CIP program with no expiration date.

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Weather (1)	$	6,335	$	25,363	$	12,790	$	23,144
Usage	(3,839)		(2,321)		(3,245)		(1,278)
Total	$	2,496	$	23,042	$	9,545	$	21,866

(1)Compared with the 20-year average, weather was 4.1 percent warmer-than-normal and 19.8 percent warmer-than-normal during the three months ended March 31, 2021 and 2020, respectively and 6.4 percent warmer-than-normal and 11.2 percent warmer-than-normal during the.six months ended March 31, 2021 and 2020, respectively.

51

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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.

On March 27, 2020, the BPU approved, on a final basis, a decrease to NJNG’s BGSS rate for residential and small commercial customers, an increase to its balancing charge rate, resulting in a $2.0 million decrease to the annual revenues credited to BGSS, as well as changes to the CIP rates, which resulted in a $10.6 million annual recovery increase, effective October 1, 2019.

On November 20, 2020, NJNG notified the BPU of its intent to provide BGSS bill credits to residential and small commercial sales customers effective December 1, 2020 to December 31, 2020. On December 22, 2020, NJNG notified the BPU of the extension of the BGSS bill credits through January 31, 2021. The actual bill credits given to customers totaled $20.6 million, $19.3 million net of tax.

On March 3, 2021, the BPU approved, on a final basis, NJNG’s annual petition to modify its BGSS, balancing charge and CIP rates for residential and small commercial customers. The rate changes resulted in a $20.4 million decrease to the annual revenues credited to BGSS, a $3.8 million annual decrease related to its balancing charge, as well as changes to CIP rates, which resulted in a $16.5 million annual recovery increase, effective October 1, 2020. 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.

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 $2.1 million and $1.6 million during the three months ended March 31, 2021 and 2020, respectively, and $6.7 million and $4.3 million during the six months ended March 31, 2021 and 2020, respectively.

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.

52

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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 source from S&P Global Platts.

The maximum price per MMBtu was $14.57 and $5.59 and the minimum price was $0.28 and $0.68 for the six months ended March 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 Results of Operations 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. On June 25, 2020, NJNG filed its annual USF compliance filing proposing a decrease to the statewide USF rate, which will result in annual decreases of approximately $400,000. On September 23, 2020, the BPU approved the decrease, effective October 1, 2020.

On March 16, 2020, the BPU approved on a final basis NJNG's annual SBC application including recovery of remediation expenses, an increase in the RAC of approximately $1.2 million annually and an annual decrease to the NJCEP factor of $600,000, which was effective April 1, 2020.

On April 7, 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 April 1, 2021.

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 $143.5 million as of March 31, 2021, a decrease of $7.1 million compared with the prior fiscal period.

53

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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 Company is in the process of conducting site investigation activities to identify and evaluate the nature and extent of MGP-related contaminants present at the location. The costs associated with preliminary assessment and site 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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues	$	310,167	$	297,220	$	505,896	$	516,843
Operating expenses
Natural gas purchases (1)	118,452		114,256		177,761		210,078
Operation and maintenance	52,951		39,815		96,589		76,000
Regulatory rider expense	18,413		15,330		29,114		27,072
Depreciation and amortization	19,475		18,100		38,644		34,917
Total operating expenses	209,291		187,501		342,108		348,067
Operating income	100,876		109,719		163,788		168,776
Other income, net	4,293		3,792		8,189		5,058
Interest expense, net of capitalized interest	9,006		7,473		17,980		15,305
Income tax provision	15,622		19,702		23,989		28,337
Net income	$	80,541	$	86,336	$	130,008	$	130,192

(1)Includes related party transactions of approximately $5.2 million and $2.7 million for the three months ended March 31, 2021 and 2020, respectively, and $8.4 million and $6.7 million for the six months ended March 31, 2021 and 2020, respectively, the majority of which is eliminated in consolidation.

Operating Revenues and Natural Gas Purchases

During the three months ended March 31, 2021, compared with the three months ended March 31, 2020, operating revenues increased by 4.4 percent and natural gas purchases increased 3.7 percent. During the six months ended March 31, 2021, compared with the six months ended March 31, 2020, operating revenues decreased by 2.1 percent and natural gas purchases decreased 15.4 percent.

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
	2021 v. 2020				2021 v. 2020
(Thousands)	Operating revenues		Natural gas purchases		Operating revenues		Natural gas purchases
Firm sales	$	39,422	$	17,970	$	31,218	$	12,144
BGSS incentives	5,193		4,666		(5,682)		(8,058)
SAFE II/NJ RISE	2,681		—		5,012		—
Base rate impact	(117)		—		5,076		—
CIP adjustments	(20,546)		—		(12,321)		—
Average BGSS rates	(6,551)		(6,551)		(14,891)		(14,891)
Bill credits	(11,071)		(11,071)		(20,590)		(20,590)
Other (1)	3,936		(818)		1,231		(922)
Total increase (decrease)	$	12,947	$	4,196	$	(10,947)	$	(32,317)

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

54

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Non-GAAP Financial Measures

Management 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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues	$	310,167	$	297,220	$	505,896	$	516,843
Less:
Natural gas purchases	118,452		114,256		177,761		210,078
Regulatory rider expense	18,413		15,330		29,114		27,072
Utility gross margin	$	173,302	$	167,634	$	299,021	$	279,693

Utility gross margin consists of three components:

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

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

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

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

	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2021			2020			2021			2020
($ in thousands)	Margin		Bcf	Margin		Bcf	Margin		Bcf	Margin		Bcf
Utility gross margin/throughput
Residential	$	124,468	22.7	$	120,541	18.9	$	210,443	36.3	$	197,623	33.5
Commercial, industrial and other	23,050		4.3	22,884		3.6	40,090		6.7	38,071		6.4
Firm transportation	22,878		5.7	21,469		5.1	40,166		9.6	37,128		9.4
Total utility firm gross margin/throughput	170,396		32.7	164,894		27.6	290,699		52.6	272,822		49.3
BGSS incentive programs	2,114		23.6	1,587		28.2	6,692		49.5	4,316		56.1
Interruptible/off-tariff agreements	792		0.8	1,153		4.7	1,630		5.3	2,555		13.7
Total utility gross margin/throughput	$	173,302	57.1	$	167,634	60.5	$	299,021	107.4	$	279,693	119.1

Utility Firm Gross Margin

Utility firm gross margin increased $5.5 million during the three months ended March 31, 2021, compared with the three months ended March 31, 2020, due primarily to increased returns on infrastructure programs related to SAFE II and NJ RISE. Utility firm gross margin increased $17.9 million during the six months ended March 31, 2021, compared with the six months ended March 31, 2020, due primarily to the increase in base rates, along with increased returns on infrastructure programs as previously discussed.

55

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

BGSS Incentive Programs

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

	Three Months Ended			Six Months Ended
	March 31,			March 31,
(Thousands)	2021 v. 2020			2021 v. 2020
Off-system sales		$	903		$	767
Storage		(327)			1,749
Capacity release		(49)			(140)
Total increase		$	527		$	2,376

The increase in BGSS incentive programs during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, was due primarily to increased margins from off-system sales along with improved and earlier opportunities for storage incentive compared with the prior year.

Operation and Maintenance Expense

O&M expense increased $13.1 million during the three months ended March 31, 2021, compared with the three months ended March 31, 2020, due primarily to increased compensation and information technologies expenses. O&M expense increased $20.6 million during the six months ended March 31, 2021, compared with the six months ended March 31, 2020, due primarily to increased compensation, information technology and bad debt expenses.

Depreciation Expense

Depreciation expense increased $1.4 million and $3.7 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, as a result of additional utility plant being placed into service.

Interest Expense

Interest expense increased $1.5 million and $2.7 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to increased outstanding long-term debt.

Other Income

Other income increased $501,000 and $3.1 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to increased AFUDC earned on infrastructure projects.

Income Tax Provision

Income tax provision decreased $4.1 million and $4.3 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due to lower operating income.

Net Income

Net income decreased $5.8 million during the three months ended March 31, 2021, compared with the three months ended March 31, 2020, due primarily to increased O&M, depreciation and interest expenses, as previously discussed. Net income remained relatively flat during the six months ended March 31, 2021, compared with the six months ended March 31, 2020.

56

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Clean Energy Ventures Segment

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 SRECs. 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
	March 31,
($ in Thousands)	2021				2020
Placed in service	Projects	MW	Costs		Projects	MW	Costs
Grid-connected	1	2.7	$	5,492	2	20.0	$	40,385
Net-metered:
Residential	80	0.8	2,230		157	1.7	5,075
Total placed in service	81	3.5	$	7,722	159	21.7	$	45,460

	Six Months Ended
	March 31,
($ in Thousands)	2021				2020
Placed in service	Projects	MW	Costs		Projects	MW	Costs
Grid-connected	2	5.6	$	9,175	3	22.9	$	52,092
Net-metered:
Residential	126	1.3	3,829		281	3.0	9,085
Total placed in service	128	6.9	$	13,004	284	25.9	$	61,177

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

Since inception, Clean Energy Ventures has constructed a total of 364.3 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.

57

New Jersey Resources Corporation

Part I

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 SRECs, TRECs 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. In December 2020, Clean Energy Ventures received proceeds of $12.1 million in connection with the sale leaseback of commercial solar assets. Clean Energy Ventures did not enter into any sale leaseback transactions for its commercial solar assets during the six months ended March 31, 2020.

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:	Six Months Ended
	March 31,
	2021		2020
	SRECs	TRECs	SRECs
Inventory balance as of October 1,	35,011	9,270	53,395
RECs generated	141,071	10,310	138,700
RECs delivered	(9,495)	(5,294)	(19,693)
Inventory balance as of December 31,	166,587	14,286	172,402

The average SREC sales price was $218 and $189 during the six months ended March 31, 2021 and 2020, respectively and the average TREC price was $147 during the six months ended March 31, 2021.

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
2021	98%
2022	97%
2023	97%
2024	93%
2025	36%
2026	10%

(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 various fees.

58

New Jersey Resources Corporation

Part I

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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues	$	6,476	$	5,995	$	12,846	$	12,207
Operating expenses
Operation and maintenance	8,260		7,479		17,461		14,813
Depreciation and amortization	4,685		6,603		10,118		12,919
Total operating expenses	12,945		14,082		27,579		27,732
Operating loss	(6,469)		(8,087)		(14,733)		(15,525)
Other income (expense), net	149		(41)		87		(124)
Interest expense, net	5,266		4,835		10,300		9,327
Income tax benefit	(2,714)		(4,134)		(5,800)		(7,968)
Net loss	$	(8,872)	$	(8,829)	$	(19,146)	$	(17,008)

Operating Revenues

Operating revenues increased $481,000 and $639,000 during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to the recognition of TREC revenue, which was not present during the same period in the prior year.

Operation and Maintenance Expense

O&M expense increased $781,000 and $2.6 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to increased project maintenance, lease and information technology expenses.

Depreciation Expense

Depreciation expense decreased $1.9 million and $2.8 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, primarily due to the change in estimated useful lives of our commercial solar assets, effective July 1, 2020.

Income Tax Benefit

Income tax benefit decreased $1.4 million and $2.2 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to a decreased state tax rate.

Net Income

Net income remained relatively flat during the three months ended March 31, 2021, compared with the three months ended March 31, 2020. Net income decreased $2.1 million during the six months ended March 31, 2021, compared with the six months ended March 31, 2020, due primarily to the increased O&M, partially offset by decreased depreciation expense, 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

59

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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 them 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 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.

Operating Results

Energy Services’ financial results are summarized as follows:

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues (1)	$	462,569	$	313,701	$	692,046	$	684,116
Operating expenses
Natural gas purchases (including demand charges (2)(3))	330,280		318,912		504,117		636,636
Operation and maintenance	32,998		4,822		37,014		9,560
Depreciation and amortization	13		27		55		56
Total operating expenses	363,291		323,761		541,186		646,252
Operating income (loss)	99,278		(10,060)		150,860		37,864
Other income, net	87		113		179		192
Interest expense, net	575		937		1,255		2,163
Income tax provision (benefit)	23,128		(2,449)		35,250		8,303
Net income (loss)	$	75,662	$	(8,435)	$	114,534	$	27,590

(1)Includes related party transactions of approximately $2.8 million and $259,000 for the three months ended March 31, 2021 and 2020, respectively, and $4.9 million and $1.9 million for the six months ended March 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 $226,000 and $46,000 for the three months ended March 31, 2021 and 2020, respectively, and $391,000 and $92,000 for the six months ended March 31, 2021 and 2020, respectively, a portion of which is eliminated in consolidation.

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

	Six Months Ended
	March 31,
(in Bcf)	2021	2020
Net short futures contracts	12.4	29.9

60

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Operating Revenues and Natural Gas Purchases

Operating revenues increased $148.9 million and natural gas purchases increased $11.4 million during the three months ended March 31, 2021, compared with the three months ended March 31, 2020. Operating revenues increased $7.9 million and natural gas purchases decreased $132.5 million during the six months ended March 31, 2021, compared with the six months ended March 31, 2020. The increases during the three and six months were due primarily to increased natural gas price volatility related to the extreme weather in the mid-continent and southern regions of the U.S. during February 2021 compared to the prior period. The decrease in gas purchases during the six months ended March 31, 2021, compared with the six months ended March 31, 2020, was due primarily to the timing of injections and withdrawals for natural gas in storage.

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.

Operation and Maintenance Expense

O&M expense increased $28.2 million and $27.5 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to increased compensation costs, charitable contributions and bad debt expense.

Income Tax Provision

Income tax provision increased $25.6 million and $26.9 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to increased operating income related to increased natural gas price volatility during February 2021 as discussed above.

Net Income

Net income increased $84.1 million and $86.9 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, respectively, due primarily to increased operating income, partially offset by higher O&M expenses, 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. Accordingly, for NFE purposes, the annual estimated effective tax rate is 18.8 percent for fiscal 2021 and 18.2 percent for fiscal 2020.

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.

61

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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues (1)	$	462,569	$	313,701	$	692,046	$	684,116
Less: Natural gas purchases	330,280		318,912		504,117		636,636
Add:
Unrealized loss (gain) on derivative instruments and related transactions	29,348		(3,146)		(9,433)		(45,340)
Effects of economic hedging related to natural gas inventory (2)	(7,209)		14,622		(14,741)		5,735
Financial margin	$	154,428	$	6,265	$	163,755	$	7,875

(1)Includes unrealized (gains) losses related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $(91,000) and $(626,000) for the three months ended March 31, 2021 and 2020, respectively, $1.2 million and $(199,000) for the six months ended March 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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating income (loss)	$	99,278	$	(10,060)	$	150,860	$	37,864
Add:
Operation and maintenance	32,998		4,822		37,014		9,560
Depreciation and amortization	13		27		55		56
Subtotal	132,289		(5,211)		187,929		47,480
Add:
Unrealized loss (gain) on derivative instruments and related transactions	29,348		(3,146)		(9,433)		(45,340)
Effects of economic hedging related to natural gas inventory	(7,209)		14,622		(14,741)		5,735
Financial margin	$	154,428	$	6,265	$	163,755	$	7,875

Financial margin increased $148.2 million and $155.9 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to natural gas price volatility during February 2021, as previously discussed compared to the prior period.

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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Net income (loss)	$	75,662	$	(8,435)	$	114,534	$	27,590
Add:
Unrealized loss (gain) on derivative instruments and related transactions	29,348		(3,146)		(9,433)		(45,340)
Tax effect (1)	(6,976)		747		2,243		10,780
Effects of economic hedging related to natural gas inventory	(7,209)		14,622		(14,741)		5,735
Tax effect	1,713		(3,475)		3,503		(1,363)
Net income to NFE tax adjustment	3,990		2,174		1,922		(37)
Net financial earnings (loss)	$	96,528	$	2,487	$	98,028	$	(2,635)

(1)Includes taxes related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $23,000 and $150,000 for the three months ended and 2020, respectively, and $(284,000) and $48,000 for the six months ended March 31, 2021 and 2020, respectively.

62

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

NFE increased $94.0 million and $100.7 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 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 regulated 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 constructions 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 a 50 percent ownership interest in Steckman Ridge, a storage facility that operates under market-based rates and a 20 percent ownership interest in PennEast, a natural gas pipeline. NJR Pipeline Company acquired 100 percent of Leaf River for $367.5 million, on October 11, 2019. Leaf River owns and operates a 32.2 million Dth salt dome natural gas storage facility that operates under market-based rates. In addition, on January 13, 2020, Adelphia Gateway, acquired all of Talen’s membership interests in IEC, an existing 84-mile pipeline in southeastern Pennsylvania, including related assets and rights of way, for a base purchase price of $166.0 million. 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 received a partial Notice to Proceed with construction from FERC and have begun the conversion of the southern zone of the pipeline to natural gas.

Through our subsidiary NJR Pipeline Company, we are a 20 percent investor in PennEast, a partnership whose purpose is to construct and operate a 120-mile natural gas pipeline that will extend from northeast Pennsylvania to western New Jersey. PennEast received a Certificate of Public Convenience and Necessity for the project from FERC on January 19, 2018.

On September 10, 2019, the Third Circuit issued an order overturning the U.S. District Court for the District of New Jersey’s order granting PennEast condemnation and immediate access in accordance with the Natural Gas Act to certain properties in which the State of New Jersey holds an interest. A Petition for Rehearing was denied by the Third Circuit on November 5, 2019.

On October 8, 2019, the NJDEP issued a letter indicating that it deemed PennEast’s freshwater wetlands permit application to be administratively incomplete and closed the matter without prejudice. On October 11, 2019, PennEast submitted a letter to the NJDEP objecting to its position that the application is administratively incomplete. PennEast's objections were rejected by the NJDEP on November 18, 2019.

On October 4, 2019, PennEast filed a petition for Declaratory Order with FERC requesting an interpretation of the eminent domain authority of a FERC certificate holder under the Natural Gas Act. The Declaratory Order was granted on January 30, 2020.

On January 30, 2020, PennEast filed an amendment with FERC to construct the PennEast pipeline in two phases. Phase one consists of construction of a 68-mile pipeline in Pennsylvania from the eastern Marcellus Shale region in Luzerne County that would end in Northampton County. Phase two includes construction of the remaining original certificated route in Pennsylvania and New Jersey. Construction is expected to begin following approval by FERC of the phased approach and receipt of any remaining governmental and regulatory permits.

63

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

On February 18, 2020, PennEast filed a writ of certiorari with the Supreme Court of the United States to review the September 10, 2019 Third Circuit decision.

On June 29, 2020, the Supreme Court requested that the Solicitor General of the United States file a brief that expresses the views on the question of the use of eminent domain to acquire state owned lands for pipeline construction. The Solicitor General filed its brief with the Supreme Court on December 9, 2020.

The State of New Jersey filed a brief with the Supreme Court on December 23, 2020, in response to the brief of the Solicitor General.

On February 3, 2021, the Supreme Court granted the petition for a writ of certiorari. The matter was argued before the Supreme Court on April 28, 2021.

We evaluated our investment in PennEast for an other-than-temporary impairment and determined an impairment charge was not necessary. It is reasonably possible that future unfavorable developments, such as a reduced likelihood of success from development options and legal outcomes, estimated increases in construction costs, increases in the discount rate, or further significant delays, could result in an impairment of our equity method investment. Also, the use of alternate judgments and assumptions could result in a different calculation of fair value, which could ultimately result in the recognition of an impairment charge in the Unaudited Condensed Consolidated Financial Statements.

Due to the expiration of a customer contract for Steckman Ridge, we evaluated our investment in Steckman Ridge for other-than-temporary impairment and determined an impairment charge was not necessary.

The fair value of our investment in Steckman Ridge was determined using a discounted cash flow method and utilized management’s best estimates and assumptions related to expected future results, including the price and capacity of firm natural gas storage contracting, operations and maintenance costs, the nature and timing of major maintenance and capital investment, and discount rates. Fair value determinations require considerable judgment and are sensitive to changes in underlying assumptions and other factors. As a result, it is reasonably possible that future unfavorable developments, such as the failure to execute storage contracts and other services for available capacity at anticipated price levels could result in an other-than temporary impairment charge in the Unaudited Condensed Consolidated Financial Statements.

As of March 31, 2021, our investments in Steckman Ridge and PennEast were $111.4 million and $103.1 million, respectively.

Operating Results

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues (1)	$	13,926	$	11,076	$	27,030	$	20,148
Operating expenses
Natural gas purchases	238		193		471		539
Operation and maintenance	7,139		6,094		13,681		10,972
Depreciation and amortization	2,364		2,397		5,004		4,078
Total operating expenses	9,741		8,684		19,156		15,589
Operating income	4,185		2,392		7,874		4,559
Other income, net	1,591		4,671		2,845		5,368
Interest expense, net	3,578		5,621		7,560		8,443
Income tax provision	873		1,105		1,519		1,807
Equity in earnings of affiliates	3,386		3,921		6,579		7,585
Net income	$	4,711	$	4,258	$	8,219	$	7,262

(1)Includes related party transactions of approximately $669,000 and $675,000 for the three months ended March 31, 2021 and 2020, respectively, and $1.3 million for both the six months ended March 31, 2021 and 2020, which are eliminated in consolidation.

64

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Operating Revenues

Operating revenues increased $2.9 million and $6.9 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due to increased operating revenues at Leaf River and Adelphia Gateway.

Equity in earnings of affiliates decreased $535,000 and $1.0 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to decreases in storage revenue at Steckman Ridge.

Operation and Maintenance Expense

O&M increased $1.0 million and $2.7 million during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to operations of Adelphia Gateway and increases at Leaf River.

Depreciation Expense

Depreciation expense remained relatively flat during the three months ended March 31, 2021, compared with the three months ended March 31, 2020. Depreciation expense increased $926,000 during the six months ended March 31, 2021, compared with the six months ended March 31, 2020, due primarily to operations of Adelphia Gateway during the six months ended March 31, 2021, that were not present in the first quarter of fiscal 2020.

Interest Expense

Interest expense decreased $2.0 million and $883,000 during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to higher interest expense related to the acquisition of Leaf River and Adelphia during fiscal 2020.

Net Income

Net income increased $453,000 and $957,000 during the three and six months ended March 31, 2021, compared with the three and six months ended March 31, 2020, due primarily to increased operating revenue, partially offset by increased O&M and depreciation 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 rental income at CR&R.

Operating Results

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues	$	12,773	$	12,365	$	25,350	$	25,272
Operation and maintenance	$	9,254	$	8,926	$	19,575	$	19,459
Interest expense, net	$	1,728	$	565	$	2,844	$	837
Income tax (benefit) provision	$	(59)	$	1,956	$	59	$	2,175
Net income	$	747	$	148	$	685	$	1,257

65

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Operating Revenues

Operating revenues increased $408,000 during the three months ended March 31, 2021, compared with the three months ended March 31, 2020, due primarily to increased service contract and installation revenue at NJRHS. Operating revenues remained relatively flat during the six months ended March 31, 2021, compared with the six months ended March 31, 2020.

Net Income

Net income increased $599,000 during the three months ended March 31, 2021, compared with the three months ended March 31, 2020, due primarily to increased operating revenues as previously discussed along with decreased income tax expense, partially offset by higher interest expense. Net income decreased $572,000 during the six months ended March 31, 2021, compared with the six months ended March 31, 2020, due primarily to increased shared corporate costs and information technology expense.

Liquidity and Capital Resources

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

Our consolidated capital structure was as follows:

	March 31, 2021		September 30, 2020
Common stock equity	44	%	43	%
Long-term debt	55		53
Short-term debt	1		4
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 $3.6 million of equity through the DRP by issuing 23,000 shares of common stock during the three months ended March 31, 2021 and raised $5.2 million during the three months ended March 31, 2020 by issuing 143,000 shares of treasury stock. NJR raised approximately $7.5 million of equity through the DRP by issuing 23,000 shares of common stock and approximately 140,000 shares of treasury stock during the six months ended March 31, 2021, and raised $8.8 million during the six months ended March 31, 2020, by issuing approximately 223,000 shares of treasury stock. There were no shares of common stock issued through the waiver discount feature of the DRP during the three and six months ended March 31, 2021 and 2020.

On December 4, 2019, we completed an equity offering of 6,545,454 common shares, consisting of 5,333,334 common shares issued directly by NJR and 1,212,120 common shares issuable pursuant to forward sales agreements with investment banks. The issuance of 5,333,334 common shares resulted in proceeds of approximately $212.9 million, net of issuance costs, and was reflected in shareholders' equity and as a financing activity on the statement of cash flows.

Under the forward sale agreements, a total of 1,212,120 common shares were borrowed from third parties and sold to the underwriters. Each forward sale agreement allows us, at our election and prior to September 30, 2020, to physically settle the forward sale agreements by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement, which was initially $40.0125 per share, or, alternatively, to settle the forward sale agreements in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease with respect to certain fixed amounts specified in the agreements, such as dividends.

66

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

On September 18, 2020, we amended our forward sale agreements to extend the maturity date of such forward sales agreements from September 30, 2020 to September 10, 2021. On March 3, 2021, we cash settled a portion of the forward sale agreement for a payout of approximately $388,000 for 727,272 common shares. As of March 31, 2021, if we had elected to net settle the remaining forward sale agreement, we would have paid approximately $1.4 million under a cash settlement or issued 31,607 common shares under a net share settlement.

In 1996, the Board of Directors authorized us to implement a share repurchase program, which was expanded seven times since the inception of the program, authorizing a total of 19.5 million shares of common stock for repurchase. As of March 31, 2021, we had repurchased a total of approximately 17.1 million of those shares and may repurchase an additional 2.4 million shares under the approved program. There were no shares repurchased during the six months ended March 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 periodically access the capital markets to fund long-life assets through the issuance of long-term debt securities.

We believe that our existing borrowing availability, equity proceeds and cash flow from operations will be sufficient to satisfy our working capital, capital expenditures and dividend requirements for 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 March 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. 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 and PennEast contributions, 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 March 31, 2021, NJR had revolving credit facilities totaling $425 million, with $406.2 million available under the facilities.

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.

NJNG’s commercial paper is sold through several commercial banks under an issuing and paying agency agreement and is supported by the $250 million NJNG Credit Facility. As of March 31, 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 $249.3 million.

67

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Short-term borrowings were as follows:

	Three Months Ended			Six Months Ended
(Thousands)	March 31, 2021
NJR
Notes Payable to banks:
Balance at end of period	$	8,500			$	8,500
Weighted average interest rate at end of period	1.75		%		1.75		%
Average balance for the period	$	141,381			$	123,582
Weighted average interest rate for average balance	1.04		%		1.04		%
Month end maximum for the period	$	153,000			$	153,000
NJNG
Commercial Paper and Notes Payable to banks:
Balance at end of period	$	—			$	—
Weighted average interest rate at end of period	—		%		—		%
Average balance for the period	$	106			$	292
Weighted average interest rate for average balance	.06		%		.04		%
Month end maximum for the period	$	5,100			$	14,350

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 and six months ended March 31, 2021, NJR's average interest rate was 1.04 percent and 1.04 percent, resulting in interest expense of approximately $362,000 and $643,000, respectively.

As of March 31, 2021, NJR had seven letters of credit outstanding totaling $10.3 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 and six months ended March 31, 2021, NJNG's average interest rate was 0.06 percent and 0.04 percent, respectively. NJNG's interest expense was immaterial for the three and six months ended March 31, 2021.

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

•incur additional debt;

•incur liens and encumbrances;

•make dispositions of assets;

•enter into transactions with affiliates; and

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

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

68

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Default Provisions

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

•defaults for non-payment;

•defaults for breach of representations and warranties;

•defaults for insolvency;

•defaults for non-performance of covenants;

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

•guarantor defaults.

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

Long-Term Debt

NJR

As of March 31, 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.

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

NJNG

As of March 31, 2021, NJNG's long-term debt consisted of $1.1 billion in fixed-rate debt issuances secured by the Mortgage Indenture, with maturities ranging from 2024 to 2060, and $58.3 million in finance leases with various maturities ranging from 2021 to 2037.

NJR is not obligated directly or contingently with respect to 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 65 percent of the consolidated total capitalization of the borrower, as those terms are defined in the applicable agreements, and a covenant limiting priority debt to 20 percent of the borrower's consolidated total capitalization, as those terms are defined in the applicable agreements);

•incur liens and encumbrances;

•make loans and investments;

•make dispositions of assets;

•make dividends or restricted payments;

•enter into transactions with affiliates; and

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

69

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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 pursuant to the Mortgage Indenture. The interest rate on defaulted principal and interest, to the extent permitted by law, on the FMBs issued under the Mortgage Indenture is the rate stated in the applicable supplement or, if no such rate is stated, six percent per annum.

Sale Leaseback

NJNG

NJNG received $4.0 million in December 2019, in connection with the sale leaseback of its natural gas meters. NJNG records a capital lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease. NJNG exercised early purchase options with respect to certain outstanding meter leases by making final principal payments of $1.2 million for both the six months ended March 31, 2021 and 2020. There were no natural gas meter sale leasebacks recorded during the six months ended March 31, 2021.

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 SREC and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if applicable. Clean Energy Ventures continues to operate the solar assets, including related expenses, and retain the revenue generated from SRECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. In December 2020, Clean Energy Ventures received proceeds of $12.1 million in connection with the sale leaseback of two commercial solar projects. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during the six months ended March 31, 2020.

Contractual Obligations

NJNG's total capital expenditures are projected to be between $424 million and $454 million during fiscal 2021. Total capital expenditures spent or accrued during the six months ended March 31, 2021, were $188.4 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 March 31, 2021, NJNG's future MGP expenditures are estimated to be $143.5 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.

70

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

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. During the six months ended March 31, 2021, total capital expenditures spent or accrued related to the purchase and installation of solar equipment were $37.5 million. We estimate solar-related capital expenditures for projects during fiscal 2021 to be between $96 million and $118 million.

During the six months ended March 31, 2021, our Storage and Transportation segment had capital expenditures for the Adelphia Gateway project totaling $27.4 million and capital expenditures for Leaf River totaling $2.6 million. During fiscal 2021, we expect expenditures related to the Adelphia Gateway project to be between $110 million and $130 million and expenditures related to Leaf River to be between $22 million and $23 million.

Energy Services does not currently anticipate any significant capital expenditures during fiscal 2021 and 2022.

On December 16, 2020, Energy Services entered into a series of asset management agreements with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts. The utility will provide 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 asset management agreements include a series of initial and permanent releases commencing 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.

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, 2020.

Off-Balance-Sheet Arrangements

As of March 31, 2021, our off-balance-sheet arrangements consist of guarantees covering approximately $196.5 million of natural gas purchases, SREC sales and demand fee commitments and outstanding letters of credit totaling $11.0 million.

Cash Flows

Operating Activities

Cash flows from operating activities during the six months ended March 31, 2021, totaled $356.3 million compared with $179.1 million during the six months ended March 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 increase of $177.1 million in cash flows from operating activities during the six months ended March 31, 2021, compared with the six months ended March 31, 2020, was due primarily to higher net income due primarily to increased earnings at Energy Services along with increased working capital.

71

New Jersey Resources Corporation

Part I

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

OPERATIONS (Continued)                                                                                                                                                             

Investing Activities

Cash flows used in investing activities totaled $245.5 million during the six months ended March 31, 2021, compared with $751.1 million during the six months ended March 31, 2020. The decrease of $505.6 million was due primarily to the acquisition of Leaf River and Adelphia in the prior period that did not recur along with a decrease of $28.9 million in solar capital expenditures, partially offset by an increase in capital expenditures of $20.1 million for utility plant investments and $20.8 million for Storage and Transportation.

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 used in financing activities totaled $171.2 million during the six months ended March 31, 2021, compared with cash flows from financing activities of $596.3 million during the six months ended March 31, 2020. The decrease of $767.6 million is due primarily to increased short-term debt activity at NJR related to the acquisitions of Leaf River and Adelphia in the prior period that did not recur and current period payments of short-term debt, partially offset by proceeds of $12.1 million from solar sale leasebacks at Clean Energy Ventures in the current period.

Credit Ratings

The table below summarizes NJNG's credit ratings as of March 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. NJNG's Moody's and Fitch ratings are investment-grade ratings. NJR is not a rated entity.

On March 18, 2020, Moody’s revised NJNG's secured rating from Aa3 to A1 and its commercial paper rating from P-1 to P-2 resulting from higher debt levels to fund NJNG’s elevated capital program. The outlook was increased to stable from negative. This action does not currently affect any of NJNG’s long-term borrowing rates or credit facility pricing.

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.

72

New Jersey Resources Corporation

Part I

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 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, 2020			(Decrease) in Fair Market Value		Amounts Settled		March 31, 2021
Natural Gas Distribution		$	(211)		(1,440)		(2,152)		$	501
Energy Services		4,397			24,569		23,184		5,782
Total		$	4,186		23,129		21,032		$	6,283

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

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

(Thousands)	2021		2022	2023 - 2025		After 2025		Total Fair Value
Price based on NYMEX/CME	$	139	42		12				$	193
Price based on ICE	4,658		1,372		60				6,090
Total	$	4,797	1,414		72		—		$	6,283

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

		Volume Bcf	Price per MMBtu(1)	Amounts included in Derivatives (Thousands)
Natural Gas Distribution	Futures	22.1	$0.00 - $3.03		$	501
Energy Services	Futures	(11.6)	$1.67 - $4.73		5,589
	Swaps	(0.8)	$2.72 - $3.08		193
Total					$	6,283

(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, 2020			(Decrease) in Fair Market Value		Amounts Settled		March 31, 2021
Natural Gas Distribution - Prices based on other external data		$	2		782		608		$	176
Energy Services - Prices based on other external data		(24,723)			(7,121)		(371)		(31,473)
Total		$	(24,721)		(6,339)		237		$	(31,297)

73

New Jersey Resources Corporation

Part I

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 $2.4 million. This analysis does not include potential changes to reported credit adjustments embedded in the $0.4 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	$	—	$	(1,179)	$	(2,357)	$	(3,536)	$	(4,715)
Ending derivative fair value	$	423	$	(756)	$	(1,934)	$	(3,113)	$	(4,292)
Percent decrease in NYMEX natural gas futures prices	0%		(5)%		(10)%		(15)%		(20)%
Estimated change in derivative fair value	$	—	$	1,179	$	2,357	$	3,536	$	4,715
Ending derivative fair value	$	423	$	1,602	$	2,780	$	3,959	$	5,138

Wholesale Credit Risk

The following is a summary of gross and net credit exposures, grouped by investment and non-investment grade counterparties, as of March 31, 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 March 31, 2021, is as follows:

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	122,148		$	107,865
Noninvestment grade		9,445			1,114
Internally rated investment grade		23,607			17,921
Internally rated noninvestment grade		19,949			11,966
Total		$	175,149		$	138,866

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

(Thousands)	Gross Credit Exposure			Net Credit Exposure
Investment grade		$	6,437		$	6,182
Noninvestment grade		26			—
Internally rated investment grade		54			32
Internally rated noninvestment grade		169			2
Total		$	6,686		$	6,216

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.

74

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, 2020.

Effects of Inflation

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

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 March 31, 2021, that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

75

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, 2020, 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 March 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 2020 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 2020 Annual Report on Form 10-K.

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

The following table sets forth our repurchase activity for the quarter ended March 31, 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
01/01/21 - 01/31/21	—	$	—	—	2,431,053
02/01/21 - 02/28/21	—	—		—	2,431,053
03/01/21 - 03/31/21	—	—		—	2,431,053
Total	—	$	—	—	2,431,053

The stock repurchase plan, which was authorized by our Board of Directors, became effective in September 1996 and as of March 31, 2021, included 19.5 million shares of common stock for repurchase, of which, approximately 2.4 million shares remained available for repurchase. The stock repurchase plan will expire when we have repurchased all shares authorized for repurchase thereunder, unless the repurchase plan is earlier terminated by action of our Board of Directors or further shares are authorized for repurchase.

76

New Jersey Resources Corporation

Part II

ITEM 6. EXHIBITS                                                                                                                                                                         

Exhibit
Number Exhibit Description

31.1+	Certification of the Chief Executive Officer pursuant to section 302 of the Sarbanes-Oxley Act of 2002
31.2+	Certification of the Chief Financial Officer pursuant to section 302 of the Sarbanes-Oxley Act of 2002
32.1+ †	Certification of the Chief Executive Officer pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.2+ †	Certification of the Chief Financial Officer pursuant to section 906 of the Sarbanes-Oxley Act of 2002
101+	Interactive Data File (Form 10-Q, for the fiscal period ended March 31, 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 Securities Exchange Act of 1934, as amended.

77

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:	May 6, 2021
		By:/s/ Patrick Migliaccio
		Patrick Migliaccio
		Senior Vice President and
		Chief Financial Officer

78

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:	May 6, 2021	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, Patrick Migliaccio, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 6, 2021	By:	/s/ Patrick Migliaccio
			Patrick Migliaccio
			Senior Vice President and Chief Financial Officer

EX-32.1

EXHIBIT 32.1

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

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

The undersigned, 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 March 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:	May 6, 2021	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, Patrick Migliaccio hereby certifies as follows:

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

(b)To the best of my knowledge, this quarterly report on Form 10-Q for the fiscal quarter ended March 31, 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:	May 6, 2021	By:	/s/ Patrick Migliaccio
			Patrick Migliaccio
			Senior Vice President and Chief Financial Officer

XML

Cover Page - shares	6 Months Ended
	Mar. 31, 2021	May 03, 2021
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 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		96,339,849
Entity Central Index Key	0000356309
Current Fiscal Year End Date	--09-30
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q2

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
OPERATING REVENUES
Utility	$ 310,167	$ 297,220	$ 505,896	$ 516,843
Nonutility	492,020	342,394	750,596	737,807
Total operating revenues	802,187	639,614	1,256,492	1,254,650
Natural gas purchases:
Gas purchases - Related parties	1,730	1,506	3,464	3,030
Operation and maintenance	110,265	66,832	183,901	130,177
Regulatory rider expenses	18,413	15,330	29,114	27,072
Depreciation and amortization	26,848	27,516	54,210	52,153
Total operating expenses	600,979	541,131	943,804	1,051,549
OPERATING INCOME	201,208	98,483	312,688	203,101
Other income, net	5,007	7,261	9,124	7,547
Interest expense, net of capitalized interest	20,153	19,203	39,939	35,273
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	186,062	86,541	281,873	175,375
Income tax provision	39,057	16,284	56,498	32,755
Equity in earnings of affiliates	2,804	3,589	5,479	6,978
NET INCOME	$ 149,809	$ 73,846	$ 230,854	$ 149,598
EARNINGS PER COMMON SHARE
Basic (usd per share)	$ 1.56	$ 0.78	$ 2.40	$ 1.60
Diluted (usd per share)	$ 1.55	$ 0.77	$ 2.39	$ 1.59
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic (in shares)	96,248	95,584	96,181	93,747
Diluted (in shares)	96,618	95,890	96,598	94,073
Regulated
Natural gas purchases:
Gas purchases - Utility and Nonutility	$ 113,235	$ 111,563	$ 169,380	$ 203,377
Unregulated
Natural gas purchases:
Gas purchases - Utility and Nonutility	$ 330,488	$ 318,384	$ 503,735	$ 635,740

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Statement of Comprehensive Income [Abstract]
Net income	$ 149,809	$ 73,846	$ 230,854	$ 149,598
Other comprehensive income, net of tax
Reclassifications of losses to net income on derivatives designated as hedging instruments, net of tax of $(79), $0, $(191) and $0, respectively	263	0	494	0
Loss on derivatives designated as hedging instruments, net of tax of $0, $2,781, $0 and $2,781, respectively	0	(9,711)	0	(9,711)
Adjustment to postemployment benefit obligation, net of tax of $(244), $(1,753), $(489) and $(1,970), respectively	813	6,100	1,625	6,859
Other comprehensive income (loss)	1,076	(3,611)	2,119	(2,852)
Comprehensive income	$ 150,885	$ 70,235	$ 232,973	$ 146,746

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Statement of Comprehensive Income [Abstract]
Tax on reclassifications of losses to net income on derivatives	$ (79)	$ 0	$ (191)	$ 0
Tax on loss on derivatives	0	2,781	0	2,781
Tax on adjustment to postemployment benefit obligation	$ (244)	$ (1,753)	$ (489)	$ (1,970)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($)	6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 230,854,000	$ 149,598,000
Adjustments to reconcile net income to cash flows from operating activities
Unrealized gain on derivative instruments	(8,235,000)	(45,539,000)
Depreciation and amortization	54,210,000	52,153,000
Amortization of acquired wholesale energy contracts	3,401,000	3,953,000
Allowance for equity used during construction	(10,603,000)	(8,053,000)
Allowance for doubtful accounts	10,607,000	951,000
Non cash lease expense	1,957,000	1,856,000
Deferred income taxes	20,909,000	34,975,000
Manufactured gas plant remediation costs	(6,284,000)	(5,291,000)
Equity in earnings, net of distributions received from equity investees	(3,543,000)	(2,760,000)
Cost of removal - asset retirement obligations	(512,000)	(122,000)
Contributions to postemployment benefit plans	(2,018,000)	(5,742,000)
Taxes related to stock-based compensation	(145,000)	803,000
Changes in:
Components of working capital	6,846,000	3,526,000
Other noncurrent assets	18,854,000	(1,258,000)
Other noncurrent liabilities	39,993,000	95,000
Cash flows from operating activities	356,291,000	179,145,000
Expenditures for:
Cost of removal	(23,989,000)	(17,487,000)
Acquisition of assets, net of cash acquired of $5.1 million	0	(523,647,000)
Distribution from equity investees in excess of equity in earnings	871,000	1,132,000
Investments in equity investees	(482,000)	(1,266,000)
Cash flows used in investing activities	(245,498,000)	(751,130,000)
CASH FLOWS (USED IN) FROM FINANCING ACTIVITIES
Payments of long-term debt	(11,001,000)	(9,764,000)
Proceeds from term loan	0	350,000,000
Payments of term loan	0	(212,900,000)
(Payments of) proceeds from short-term debt, net	(116,850,000)	304,023,000
Proceeds from sale leaseback transaction - solar	12,124,000	0
Proceeds from sale leaseback transaction	0	4,000,000
Payments of common stock dividends	(60,894,000)	(56,821,000)
Proceeds from issuance of common stock - public equity offering	0	212,900,000
Cash settlement of equity forward agreement	(388,000)	0
Proceeds from issuance of common stock - DRP	7,540,000	8,767,000
Tax withholding payments related to net settled stock compensation	(1,772,000)	(3,893,000)
Cash flows (used in) from financing activities	(171,241,000)	596,312,000
Change in cash, cash equivalents and restricted cash	(60,448,000)	24,327,000
Cash, cash equivalents and restricted cash at beginning of period	119,423,000	4,063,000
Cash, cash equivalents and restricted cash at end of period	58,975,000	28,390,000
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	(136,295,000)	(87,532,000)
Inventories	94,233,000	90,484,000
Recovery of natural gas costs	(20,279,000)	(21,891,000)
Natural gas purchases payable	33,191,000	(10,933,000)
Natural gas purchases payable - related parties	62,000	11,000
Accounts payable and other	(19,621,000)	(27,345,000)
Prepaid expenses	(8,170,000)	(602,000)
Prepaid and accrued taxes	59,614,000	22,258,000
Restricted broker margin accounts	7,644,000	39,193,000
Customers' credit balances and deposits	(5,171,000)	(7,788,000)
Other current assets	1,638,000	7,671,000
Total	6,846,000	3,526,000
Cash paid for:
Interest (net of amounts capitalized)	40,465,000	32,872,000
Income taxes	3,733,000	1,193,000
Accrued capital expenditures	22,840,000	17,930,000
Utility Plant
Expenditures for:
Payments to acquire PP&E	(152,496,000)	(132,352,000)
Solar Equipment
Expenditures for:
Payments to acquire PP&E	(40,884,000)	(69,786,000)
Storage and Transportation and other
Expenditures for:
Payments to acquire PP&E	$ (28,518,000)	$ (7,724,000)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (Parenthetical) $ in Millions	6 Months Ended
	Mar. 31, 2020 USD ($)
Statement of Cash Flows [Abstract]
Cash acquired from asset acquisition	$ 5.1

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 2,883,656	$ 2,800,052
Construction work in progress	456,513	379,846
Nonutility plant and equipment, at cost	1,121,155	1,108,512
Construction work in progress	229,923	176,556
Total property, plant and equipment	4,691,247	4,464,966
Accumulated depreciation and amortization, utility plant	(620,028)	(601,635)
Accumulated depreciation and amortization, nonutility plant and equipment	(156,063)	(140,562)
Property, plant and equipment, net	3,915,156	3,722,769
CURRENT ASSETS
Cash and cash equivalents	57,654	117,012
Customer accounts receivable
Billed	237,229	134,173
Unbilled revenues	41,941	9,226
Allowance for doubtful accounts	(17,325)	(7,242)
Regulatory assets	23,527	36,530
Natural gas in storage, at average cost	74,853	167,504
Materials and supplies, at average cost	18,824	20,406
Prepaid expenses	14,729	6,639
Prepaid and accrued taxes	3,432	24,301
Derivatives, at fair value	17,433	23,310
Restricted broker margin accounts	45,916	69,444
Other	17,015	21,029
Total current assets	535,228	622,332
NONCURRENT ASSETS
Investments in equity method investees	214,521	208,375
Regulatory assets	522,027	527,459
Operating lease assets	144,326	131,769
Derivatives, at fair value	1,977	3,349
Intangible assets, net	6,462	10,060
Software costs	5,485	4,707
Other noncurrent assets	79,952	85,657
Total noncurrent assets	974,750	971,376
Total assets	5,425,134	5,316,477
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding March 31, 2021 — 96,262,016; September 30, 2020 — 95,949,183	240,497	240,243
Premium on common stock	497,167	491,982
Accumulated other comprehensive loss, net of tax	(42,196)	(44,315)
Treasury stock at cost and other; shares March 31, 2021 — 16,313; September 30, 2020 — 148,310	11,983	8,485
Retained earnings	1,114,382	947,501
Common stock equity	1,821,833	1,643,896
Long-term debt	2,265,202	2,259,466
Total capitalization	4,087,035	3,903,362
CURRENT LIABILITIES
Current maturities of long-term debt	22,635	27,236
Short-term debt	8,500	125,350
Natural gas purchases payable	129,136	95,945
Natural gas purchases payable to related parties	853	791
Accounts payable and other	126,154	141,500
Dividends payable	32,007	31,902
Accrued taxes	41,462	2,717
Regulatory liabilities	717	26,188
New Jersey Clean Energy Program	6,148	15,570
Derivatives, at fair value	23,690	33,865
Operating lease liabilities	4,001	6,724
Customers' credit balances and deposits	20,763	25,934
Total current liabilities	416,066	533,722
NONCURRENT LIABILITIES
Deferred income taxes	166,238	138,081
Deferred investment tax credits	3,171	3,332
Deferred gain	894	1,035
Derivatives, at fair value	20,506	13,352
Manufactured gas plant remediation	143,490	150,590
Postemployment employee benefit liability	236,432	237,221
Regulatory liabilities	193,817	196,450
Operating lease liabilities	111,034	95,030
Asset retirement obligation	34,102	33,723
Other	12,349	10,579
Total noncurrent liabilities	922,033	879,393
Commitments and contingent liabilities (Note 13)
Total capitalization and liabilities	$ 5,425,134	$ 5,316,477

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Mar. 31, 2021	Sep. 30, 2020
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)	96,262,016	95,949,183
Treasury stock at cost and other, shares (in shares)	16,313	148,310

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, 2019			89,999,000
Balance as of beginning of period at Sep. 30, 2019		$ 1,345,615	$ 226,649	$ 291,331	$ (31,787)	$ (10,436)	$ 869,858
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		75,752					75,752
Other comprehensive income		759			759
Common stock issued:
Common stock offering (in shares)			5,333,000
Common stock offering		212,900	$ 13,333	199,567
Incentive compensation plan (in shares)			96,000
Incentive compensation plan		3,292	$ 239	3,053
Dividend reinvestment plan (in shares)	[1]		80,000
Dividend reinvestment plan	[1]	3,499		314		3,185
Cash dividend declared		(29,846)					(29,846)
Treasury stock and other		(3,879)				(3,879)
Balance as of end of period (in shares) at Dec. 31, 2019			95,508,000
Balance as of end of period at Dec. 31, 2019		1,608,092	$ 240,221	494,265	(31,028)	(11,130)	915,764
Balance as of beginning of period (in shares) at Sep. 30, 2019			89,999,000
Balance as of beginning of period at Sep. 30, 2019		1,345,615	$ 226,649	291,331	(31,787)	(10,436)	869,858
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		149,598
Other comprehensive income		(2,852)
Balance as of end of period (in shares) at Mar. 31, 2020			95,643,000
Balance as of end of period at Mar. 31, 2020		1,654,737	$ 240,221	493,956	(34,639)	(4,523)	959,722
Balance as of beginning of period (in shares) at Dec. 31, 2019			95,508,000
Balance as of beginning of period at Dec. 31, 2019		1,608,092	$ 240,221	494,265	(31,028)	(11,130)	915,764
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		73,846					73,846
Other comprehensive income		(3,611)			(3,611)
Common stock issued:
Dividend reinvestment plan (in shares)	[1]		143,000
Dividend reinvestment plan	[1]	5,205		(416)		5,621
Cash dividend declared		(29,888)					(29,888)
Treasury stock and other (in shares)			(8,000)
Treasury stock and other		1,093		107		986
Balance as of end of period (in shares) at Mar. 31, 2020			95,643,000
Balance as of end of period at Mar. 31, 2020		$ 1,654,737	$ 240,221	493,956	(34,639)	(4,523)	959,722
Balance as of beginning of period (in shares) at Sep. 30, 2020		95,949,183	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, 2020		95,949,183	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		230,854
Other comprehensive income		$ 2,119
Balance as of end of period (in shares) at Mar. 31, 2021		96,262,016	96,262,000
Balance as of end of period at Mar. 31, 2021		$ 1,821,833	$ 240,497	497,167	(42,196)	11,983	1,114,382
Balance as of beginning of period (in shares) at Dec. 31, 2020			96,139,000
Balance as of beginning of period at Dec. 31, 2020		1,698,214	$ 240,367	492,890	(43,272)	11,649	996,580
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		149,809					149,809
Other comprehensive income		1,076			1,076
Common stock issued:
Common stock offering		(388)		(388)
Incentive compensation plan (in shares)			28,000
Incentive compensation plan		1,216	$ 72	1,144
Dividend reinvestment plan (in shares)			103,000
Dividend reinvestment plan		3,579	$ 58	3,521
Cash dividend declared		(32,007)					(32,007)
Treasury stock and other (in shares)			(8,000)
Treasury stock and other		$ 334				334
Balance as of end of period (in shares) at Mar. 31, 2021		96,262,016	96,262,000
Balance as of end of period at Mar. 31, 2021		$ 1,821,833	$ 240,497	$ 497,167	$ (42,196)	$ 11,983	$ 1,114,382

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

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019
Statement of Stockholders' Equity [Abstract]
Cash dividend declared per share (usd per share)	$ 0.3325	$ 0.3325	$ 0.3125	$ 0.3125

XML

NATURE OF THE BUSINESS

6 Months Ended

Mar. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

NATURE OF THE BUSINESS

1. NATURE OF THE BUSINESS

NJR provides regulated natural gas distribution services, transportation and storage services and operates certain unregulated businesses primarily through the following:

NJNG provides natural gas utility service to approximately 561,500 customers throughout Burlington, Middlesex, Monmouth, Morris and Ocean 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 consists of the Company's capital investments in commercial and residential solar projects.

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, formerly the Midstream segment, invests in energy-related ventures through its subsidiaries. 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. The Company also operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River, which was acquired on October 11, 2019 and Adelphia Gateway, which was acquired on January 13, 2020 and is subject to rate regulation by FERC. See Note 17. Acquisitions and Dispositions for more information regarding these acquisitions.

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.

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Mar. 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 NJR in accordance with the rules and regulations of the SEC and GAAP. The September 30, 2020 Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in NJR's 2020 Annual Report on Form 10-K.

The Unaudited Condensed Consolidated Financial Statements include the accounts of NJR and its subsidiaries. In the opinion of management, the accompanying Unaudited Condensed Consolidated Financial Statements reflect all adjustments necessary for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of NJR's utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ending September 30, 2021. 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. ARO 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 United States. 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 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 March 31, 2021.

Acquisitions

The Company follows the guidance in ASC 805, Business Combinations, for determining the appropriate accounting treatment for acquisitions. ASU No. 2017-01, Clarifying the Definition of a Business, provides an initial fair value screen to determine if substantially all of the fair value of the assets acquired is concentrated in a single asset or group of similar assets. If the initial screening test is not met, the set is considered a business based on whether there are inputs and substantive processes in place. Based on the results of this analysis and conclusion on an acquisition’s classification of a business combination or an asset acquisition, the accounting treatment is derived.

If the acquisition is deemed to be a business, the acquisition method of accounting is applied. Identifiable assets acquired and liabilities assumed at the acquisition date are recorded at fair value. If the transaction is deemed to be an asset purchase, the cost accumulation and allocation model is used whereby the assets and liabilities are recorded based on the purchase price and allocated to the individual assets and liabilities based on relative fair values.

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various assumptions and valuation methodologies requiring considerable management judgment. The most significant variables in these valuations are discount rates and the number of years on which to base the cash flow projections, as well as other assumptions and estimates used to determine the cash inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets, specific risks, industry beta and capital structure of guideline companies. The valuation of an acquired business is based on available information at the acquisition date and assumptions that are believed to be reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date.

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.

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 escrow balances for utility plant projects at NJNG and irrevocable letters of credit at Leaf River, which is recorded in other current and 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)	March 31, 2021		September 30, 2020		March 31, 2020		September 30, 2019
Balance Sheet
Cash and cash equivalents	$	57,654	$	117,012	$	25,968	$	2,676
Restricted cash in other noncurrent assets	$	1,321	$	2,411	$	2,422	$	1,387
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	58,975	$	119,423	$	28,390	$	4,063

Allowance for Doubtful Accounts

As of October 1, 2021, the Company adopted ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The Company segregates financial assets that fall within the scope of ASC 326, 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.

In February 2021, severe winter weather affected the U.S. mid-continent and southern regions that resulted in increased demand for natural gas supply and increases in wholesale energy prices. As a result, at March 31, 2021, Energy Services evaluated its counterparties for credit deterioration, as well as the related receivables for the purchase and receipt of natural gas for amounts past due.

The Company examined the credit characteristics of its counterparties, including the history of past due amounts for contractual settlements, counterparty credit ratings, and the likelihood of recovering amounts owed. As of March 31, 2021, the Company recorded a reserve for expected credit losses for Energy Services totaling $5.2 million within operations and maintenance expense on the Unaudited Condensed Consolidated Statement of Operations, representing management’s best estimate of expected credit losses at this time.

It is possible that future developments could occur that could result in impairment of a portion or all of the remaining amounts owed to Energy Services, which would result in an additional charge to earnings.

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 recorded $14.3 million and $13.7 million in other current assets and $33.9 million and $35.3 million in other noncurrent assets as of March 31, 2021 and September 30, 2020, 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 March 31, 2021 and September 30, 2020, 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:

	March 31, 2021				September 30, 2020
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	40,083	9.4		$	110,037	27.2
Energy Services		34,439		13.3		57,352		34.3
Storage and Transportation		331		0.1		115		0.02
Total		$	74,853	22.8		$	167,504	61.52

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 table presents the software costs included in the Unaudited Condensed Consolidated Financial Statements:

(Thousands)	March 31, 2021		September 30, 2020
Balance Sheets
Utility plant, at cost	$	14,011	$	13,452
Nonutility plant and equipment, at cost	$	334	$	316
Accumulated depreciation and amortization, utility plant	$	(790)	$	(279)
Accumulated depreciation and amortization, nonutility plant and equipment	$	(17)	$	(5)
Software costs	$	5,485	$	4,707

	Three Months Ended				Six Months Ended
	March 31,				March 31,
Statements of Operations	2021		2020		2021		2020
Operation and maintenance (1)	$	2,847	$	1,109	$	4,770	$	2,596
Depreciation and amortization	$	270	$	—	$	523	$	—

(1)During the three and six months ended March 31, 2021, $111,000 and $188,000 was amortized from software costs into O&M. There were no amounts amortized for the three and six months ended March 31, 2020.

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 $4.0 million in December 2019, in connection with the sale leaseback of its natural gas meters. There were no natural gas meter sale leasebacks recorded during the six months ended March 31, 2021.

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 terms of 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 SRECs, TRECs 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.

In December 2020, Clean Energy Ventures received proceeds of $12.1 million in connection with the sale leaseback of two commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during the three and six months ended March 31, 2020.

Accumulated Other Comprehensive 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 March 31, 2021 and 2020:

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at December 31, 2020	$	(10,166)	$	(33,106)		$	(43,272)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive income, net of tax of $(79), $(244), $(323), respectively	263		813		(1)	1,076
Balance at March 31, 2021	$	(9,903)	$	(32,293)		$	(42,196)
Balance at December 31, 2019	$	—	$	(31,028)		$	(31,028)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $2,781, $(1,681), $1,100	(9,711)		5,378			(4,333)
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(72), $(72)	—		722		(1)	722
Net current-period other comprehensive income, net of tax of $2,781, $(1,753), $1,028	(9,711)		6,100			(3,611)
Balance at March 31, 2020	$	(9,711)	$	(24,928)		$	(34,639)

(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.

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

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2020	$	(10,397)	$	(33,918)		$	(44,315)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive income, net of tax of $(191), $(489), $(680), respectively	494		1,625		(1)	2,119
Balance at March 31, 2021	$	(9,903)	$	(32,293)		$	(42,196)
Balance at September 30, 2019	$	—	$	(31,787)		$	(31,787)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $2,781, $(1,681), $1,100	(9,711)		5,378			(4,333)
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(289) and $(289)	—		1,481		(1)	1,481
Net current-period other comprehensive income, net of tax of $2,781, $(1,970), $811	(9,711)		6,859			(2,852)
Balance at March 31, 2020	$	(9,711)	$	(24,928)		$	(34,639)

(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.

Change in Accounting Policy

Effective October 1, 2020, the Company changed its method of accounting for ITCs at Clean Energy Ventures from the flow through method to the deferral method. Prior to the change, the Company recognized ITCs as a reduction of income tax expense in the period that the qualified solar energy property, to which it relates, was placed in service. Effective with the accounting change, the Company records ITCs as a reduction to the carrying value of the related asset when placed in service and recognizes ITCs in earnings as a reduction to depreciation expense over the productive life of the related property. The deferral method is considered the preferred method per the authoritative guidance as described in ASC 740 - Income Taxes. The change to the deferral method is also consistent with the application of authoritative accounting guidance throughout other reporting segments and promotes proper matching of the benefits of the recognition of the ITC with the expected use of the asset.

The Company applied the change in accounting method retrospectively to all prior periods presented.

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the three months ended March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	30,784	(3,268)	$	27,516
Total operating expenses	$	544,399	(3,268)	$	541,131
Operating income	$	95,215	3,268	$	98,483
Income before income taxes and equity in earnings of affiliates	$	83,273	3,268	$	86,541
Income tax (benefit) expense	$	(1,643)	17,927	$	16,284
Net income	$	88,505	(14,659)	$	73,846
Earnings per common share
Basic	$	0.93	(0.15)	$	0.78
Diluted	$	0.92	(0.15)	$	0.77

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the six months ended March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	58,542	(6,389)	$	52,153
Total operating expenses	$	1,057,938	(6,389)	$	1,051,549
Operating income	$	196,712	6,389	$	203,101
Income before income taxes and equity in earnings of affiliates	$	168,986	6,389	$	175,375
Income tax (benefit) expense	$	(1,902)	34,657	$	32,755
Net income	$	177,866	(28,268)	$	149,598
Earnings per common share
Basic	$	1.90	(0.30)	$	1.60
Diluted	$	1.89	(0.30)	$	1.59

The cumulative effect of the change in accounting policy on the Unaudited Condensed Consolidated Balance Sheets as of September 30, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Assets
Nonutility plant and equipment, at cost	$	1,430,723	(322,211)	$	1,108,512
Accumulated depreciation and amortization, nonutility plant and equipment	$	(202,507)	61,945	$	(140,562)
Property, plant and equipment, net	$	3,983,035	(260,266)	$	3,722,769
Other noncurrent assets	$	78,716	6,941	$	85,657
Total noncurrent assets	$	964,435	6,941	$	971,376
Total assets	$	5,569,802	(253,325)	$	5,316,477
Capitalization
Retained earnings	$	1,148,297	(200,796)	$	947,501
Common stock equity	$	1,844,692	(200,796)	$	1,643,896
Total capitalization	$	4,104,158	(200,796)	$	3,903,362
Liabilities
Deferred income taxes	$	190,610	(52,529)	$	138,081
Total noncurrent liabilities	$	931,922	(52,529)	$	879,393
Total capitalization and liabilities	$	5,569,802	(253,325)	$	5,316,477

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Cash Flows as of March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	58,542	(6,389)	$	52,153
Deferred income taxes	$	318	34,657	$	34,975

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Common Stock Equity as of March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Retained Earnings
Balance at September 30, 2019	$	1,075,960	(206,102)	$	869,858
Net income	$	89,361	(13,609)	$	75,752
Balance at December 31, 2019	$	1,135,475	(219,711)	$	915,764
Net income	$	88,505	(14,659)	$	73,846
Balance at March 31, 2020	$	1,194,092	(234,370)	$	959,722
Total
Balance at September 30, 2019	$	1,551,717	(206,102)	$	1,345,615
Net income	$	89,361	(13,609)	$	75,752
Balance at December 31, 2019	$	1,827,803	(219,711)	$	1,608,092
Net income	$	88,505	(14,659)	$	73,846
Balance at March 31, 2020	$	1,889,107	(234,370)	$	1,654,737

Recently Adopted Updates to the Accounting Standards Codification

Financial Instruments

In June 2016, the FASB issued ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. An entity will apply the amendment through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The Company assessed the impact of the guidance on NJR's reserve methodologies and credit policies and procedures for any assets that could be impacted, noting the majority of NJR's financial assets are short-term in nature, such as trade receivables and unbilled revenues.

The Company completed its evaluation of this amendment and all subsequent amendments related to this topic and adopted this guidance on October 1, 2020 using the modified retrospective method. The adoption did not result in a cumulative effect adjustment to retained earnings as the current expected lifetime loss estimates were not materially different from the reserves already in place.

The Company segregates financial assets that fall within the scope of ASC 326, 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.

Fair Value

In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The Company adopted this guidance on October 1, 2020 on a prospective basis. The Company does not have either Level 3 fair value measurements or transfers between Level 1 or Level 2 in its current portfolios, and therefore, this ASU did not have an impact to the Company's financial position, results of operations or cash flows.

Compensation - Retirement Benefits

In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures and adds new disclosure requirements identified as relevant. The Company adopted this guidance on October 1, 2020. There was no impact to the Company's financial position, results of operations or cash flows.

Reference Rate Reform

In January 2021, the FASB issued ASU 2021-01, which refines the scope of ASC 848, Reference Rate Reform, and clarifies some of its guidance of global reference rate reform activities. The amendments in this update permits entities to elect certain optional expedients and exceptions when accounting for derivative contracts and certain hedging relationships affected by changes in the interest rates used for discounting cash flows, for computing variation margin settlements, and for calculating price alignment interest in connection with reference rate reform activities under way in global financial markets (the “discounting transition”). The amendments in this update are effective upon the ASU issuance through December 31, 2022. There was no impact to the Company's financial position, results of operations or cash flows as a result of its adoption.

Other Recent 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 guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. Upon adoption, the amendments will be applied 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.

Investments - Equity Method and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, Investments - Equity Securities (Topic 321), Investments - Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815): Clarifying the Interactions between Topic 321, Topic 323, and Topic 815. 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 guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of these amendments but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

Other

In October 2020, the FASB issued ASU 2020-10, 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 guidance is effective for the Company on October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of these amendments but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

XML

REVENUE

6 Months Ended

Mar. 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 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 on a monthly basis in line with the terms of the contract and based on the services provided. Payment is due each month for the previous month's invoiced services.
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, related usage fees for the use of storage space, 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 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:
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 hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. 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 March 31, 2021 and 2020, is as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales	$	296,888	—		—	—	—	$	296,888
Natural gas services	—		—		11,011	13,926	—	24,937
Service contracts	—		—		—	—	8,314	8,314
Installations and maintenance	—		—		—	—	4,459	4,459
Renewable energy certificates	—		817		—	—	—	817
Electricity sales	—		4,882		—	—	—	4,882
Eliminations (1)	—		—		—	(669)	(252)	(921)
Revenues from contracts with customers	296,888		5,699		11,011	13,257	12,521	339,376
Alternative revenue programs (2)	(6,664)		—		—	—	—	(6,664)
Derivative instruments	19,943		777	(3)	451,558	—	—	472,278
Eliminations (1)	—		—		(2,803)	—	—	(2,803)
Revenues out of scope	13,279		777		448,755	—	—	462,811
Total operating revenues	$	310,167	6,476		459,766	13,257	12,521	$	802,187
2020
Natural gas utility sales	$	266,868	—		—	—	—	$	266,868
Natural gas services	—		—		9,634	11,076	—	20,710
Service contracts	—		—		—	—	8,073	8,073
Installations and maintenance	—		—		—	—	4,292	4,292
Electricity sales	—		4,458		—	—	—	4,458
Eliminations (1)	—		—		—	(675)	(326)	(1,001)
Revenues from contracts with customers	266,868		4,458		9,634	10,401	12,039	303,400
Alternative revenue programs (2)	22,073		—		—	—	—	22,073
Derivative instruments	8,279		1,537		304,067	—	—	313,883
Eliminations (1)	—		—		258	—	—	258
Revenues out of scope	30,352		1,537		304,325	—	—	336,214
Total operating revenues	$	297,220	5,995		313,959	10,401	12,039	$	639,614

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

(2)Includes CIP revenue.

(3)Includes SREC revenue.

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

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales	$	486,252	—		—	—	—	$	486,252
Natural gas services	—		—		17,439	27,030	—	44,469
Service contracts	—		—		—	—	16,573	16,573
Installations and maintenance	—		—		—	—	8,777	8,777
Renewable energy certificates	—		1,507		—	—	—	1,507
Electricity sales	—		9,270		—	—	—	9,270
Eliminations (1)	—		—		—	(1,326)	(419)	(1,745)
Revenues from contracts with customers	486,252		10,777		17,439	25,704	24,931	565,103
Alternative revenue programs (2)	(5,096)		—		—	—	—	(5,096)
Derivative instruments	24,740		2,069	(3)	674,607	—	—	24,740
Eliminations (1)	—		—		(4,931)	—	—	(4,931)
Revenues out of scope	19,644		2,069		669,676	—	—	691,389
Total operating revenues	$	505,896	12,846		687,115	25,704	24,931	$	1,256,492
2020
Natural gas utility sales	$	486,762	—		—	—	—	$	486,762
Natural gas services	—		—		16,955	20,148	—	37,103
Service contracts	—		—		—	—	16,111	16,111
Installations and maintenance	—		—		—	—	9,161	9,161
Electricity sales	—		8,476		—	—	—	8,476
Eliminations (1)	—		—		—	(1,342)	(741)	(2,083)
Revenues from contracts with customers	486,762		8,476		16,955	18,806	24,531	555,530
Alternative revenue programs (2)	20,130		—		—	—	—	20,130
Derivative instruments	9,951		3,731	(3)	667,161	—	—	680,843
Eliminations (1)	—		—		(1,853)	—	—	(1,853)
Revenues out of scope	30,081		3,731		665,308	—	—	699,120
Total operating revenues	$	516,843	12,207		682,263	18,806	24,531	$	1,254,650

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

(2)Includes CIP revenue.

(3)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 March 31, 2021 and 2020, is as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	225,174	2,692	—	—	12,234	$	240,100
Commercial and industrial	42,824		3,007	11,011	13,257	287	70,386
Firm transportation	28,190		—	—	—	—	28,190
Interruptible and off-tariff	700		—	—	—	—	700
Revenues out of scope	13,279		777	448,755	—	—	462,811
Total operating revenues	$	310,167	6,476	459,766	13,257	12,521	$	802,187
2020
Residential	$	199,776	2,469	—	—	11,831	$	214,076
Commercial and industrial	41,635		1,989	9,634	10,401	208	63,867
Firm transportation	24,123		—	—	—	—	24,123
Interruptible and off-tariff	1,334		—	—	—	—	1,334
Revenues out of scope	30,352		1,537	304,325	—	—	336,214
Total operating revenues	$	297,220	5,995	313,959	10,401	12,039	$	639,614

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

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	362,398	5,414	—	—	24,438	$	392,250
Commercial and industrial	72,053		5,363	17,439	25,704	493	121,052
Firm transportation	49,294		—	—	—	—	49,294
Interruptible and off-tariff	2,507		—	—	—	—	2,507
Revenues out of scope	19,644		2,069	669,676	—	—	691,389
Total operating revenues	$	505,896	12,846	687,115	25,704	24,931	$	1,256,492
2020
Residential	$	352,998	4,929	—	—	24,110	$	382,037
Commercial and industrial	87,057		3,547	16,955	18,806	421	126,786
Firm transportation	43,712		—	—	—	—	43,712
Interruptible and off-tariff	2,995		—	—	—	—	2,995
Revenues out of scope	30,081		3,731	665,308	—	—	699,120
Total operating revenues	$	516,843	12,207	682,263	18,806	24,531	$	1,254,650

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 six months ended March 31, 2021 are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of October 1, 2020	$	134,173	$	9,226	$	25,934
Increase (Decrease)	103,056		32,715		(5,171)
Balance as of March 31, 2021	$	237,229	$	41,941	$	20,763

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 March 31, 2021:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
Customer accounts receivable
Billed	$	119,845	4,794	107,353	3,437	1,800	$	237,229
Unbilled	39,652		2,289	—	—	—	41,941
Customers' credit balances and deposits	(20,763)		—	—	—	—	(20,763)
Total	$	138,734	7,083	107,353	3,437	1,800	$	258,407

XML

REGULATION

6 Months Ended

Mar. 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 annual filings to the BPU for review of its BGSS, CIP and various other programs and related rates. Annual rate changes are typically requested to be effective at the beginning of the following fiscal year. 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)	March 31, 2021		September 30, 2020
Regulatory assets-current
New Jersey Clean Energy Program	$	6,147	$	15,570
Conservation Incentive Program	14,025		19,120
Derivatives at fair value, net	1,509		—
Other current regulatory assets	1,730		1,682
Total current regulatory assets	$	23,411	$	36,372
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	37,476	$	36,516
Liability for future expenditures	143,495		150,590
Deferred income taxes	31,603		28,241
Derivatives at fair value, net	4		1
SAVEGREEN	21,842		21,281
Postemployment and other benefit costs	180,360		188,170
Deferred storm damage costs	5,429		6,515
Cost of removal	82,353		75,080
Other noncurrent regulatory assets	17,952		20,068
Total noncurrent regulatory assets	$	520,514	$	526,462
Regulatory liability-current
Overrecovered natural gas costs	$	541	$	25,914
Derivatives at fair value, net	176		274
Total current regulatory liabilities	$	717	$	26,188
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	192,895	$	195,425
Derivatives at fair value, net	—		352
Other noncurrent regulatory liabilities	759		509
Total noncurrent regulatory liabilities	$	193,654	$	196,286

(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.

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

(Thousands)	March 31, 2021		September 30, 2020
Total current regulatory assets	$	116	$	158
Total noncurrent regulatory assets	$	1,514	$	997
Total-noncurrent regulatory liabilities	$	164	$	—

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 October 28, 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. The recovery of information technology replacement and enhancements, that was included in the original IIP filing, will be included as part of base rate filings as projects are placed in service.

•On November 20, 2020, NJNG notified the BPU of its intent to provide BGSS bill credits to residential and small commercial sales customers effective December 1, 2020 to December 31, 2020. On December 22, 2020, NJNG notified the BPU of the extension of the BGSS bill credits through January 31, 2021. The actual bill credits given to customers totaled $20.6 million, $19.3 million net of tax.

•On March 3, 2021, the BPU approved the three-year SAVEGREEN program consisting of approximately $126.1 million of direct investment, $109.4 million in financing options, and $23.4 million in operation and maintenance expenses, to be effective July 1, 2021.

•On March 3, 2021, the BPU approved, on a final basis, NJNG’s annual petition to modify its BGSS, balancing charge and CIP rates for residential and small commercial customers. The rate changes resulted in a $20.4 million decrease to the annual revenues credited to BGSS, a $3.8 million annual decrease related to its balancing charge, as well as changes to CIP rates, which resulted in a $16.5 million annual recovery increase, effective October 1, 2020.

•On March 30, 2021, NJNG filed a base rate case with the BPU requesting a natural gas revenue increase of $165.7 million including a rate recovery for SRL and other infrastructure investments. SRL is expected to be placed in service during fiscal 2021.

•On March 31, 2021, NJNG filed a petition with the BPU requesting the final base rate increase of approximately $311,000 for the recovery associated with NJ RISE and SAFE II capital investments cost of approximately $3.4 million made through June 30, 2021. This filing will be updated for actual information through June 30, 2021. Changes to base rates are anticipated to be effective October 1, 2021.

•On April 7, 2021, the BPU approved a stipulation resolving NJNG’s annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $1.3 million annually and an increase to the NJCEP factor, resulting in an annual increase of approximately $6 million, effective April 1, 2021.

XML

DERIVATIVE INSTRUMENTS

6 Months Ended

Mar. 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.

In February 2020 and March 2020, NJNG entered into treasury lock transactions to fix the benchmark treasury rate associated with a $75 million debt tranche that was issued in September 2020. Settlement of the treasury locks resulted in a $6.6 million loss, which was recorded as a component of regulatory assets on the Unaudited Condensed Consolidated Balance Sheets. The loss is being amortized into earnings over the term of the debt as a component of interest expense on the Unaudited Condensed Consolidated Statements of Operations, which totaled $54,000 and $114,000 during the three and six months ended March 31, 2021.

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.

Home Services and Other

During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with a $260 million debt issuance that was finalized in July 2020 and a $200 million debt issuance that was finalized in September 2020. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks in fiscal 2020 resulted in a loss of $13.7 million, which was recorded within OCI. The loss is being amortized into earnings over the term of the debt as a component of interest expense on the Unaudited Condensed Consolidated Statements of Operations, which totaled $263,000 and $494,000, net of tax, during the three and six months ended March 31, 2021.

Fair Value of Derivatives

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

			Derivatives at Fair Value
			March 31, 2021						September 30, 2020
(Thousands)	Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	177		$	1		$	78		$	76
Financial commodity contracts	Derivatives - current		589			88			71			282
Energy Services:
Physical commodity contracts	Derivatives - current		3,668			16,415			6,454			20,438
	Derivatives - noncurrent		1,364			20,090			1,264			12,003
Financial commodity contracts	Derivatives - current		12,770			7,166			16,671			12,965
	Derivatives - noncurrent		585			407			2,037			1,346
Foreign currency contracts	Derivatives - current		229			20			36			104
	Derivatives - noncurrent		28			9			48			3
Total fair value of derivatives			$	19,410		$	44,196		$	26,659		$	47,217

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 March 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	5,032		$	(1,757)		$	(200)		$	3,075
Financial commodity contracts		13,355			(7,573)						5,782
Foreign currency contracts		257			(29)						228
Total Energy Services		$	18,644		$	(9,359)		$	(200)		$	9,085
Natural Gas Distribution
Physical commodity contracts		$	177		$	(1)		$	—		$	176
Financial commodity contracts		589			(88)			—			501
Total Natural Gas Distribution		$	766		$	(89)		$	—		$	677
Derivative liabilities:
Energy Services
Physical commodity contracts		$	36,505		$	(1,757)		$	—		$	34,748
Financial commodity contracts		7,573			(7,573)			—			—
Foreign currency contracts		29			(29)			—			—
Total Energy Services		$	44,107		$	(9,359)		$	—		$	34,748
Natural Gas Distribution
Physical commodity contracts		$	1		$	(1)					$	—
Financial commodity contracts		88			(88)						—
Total Natural Gas Distribution		$	89		$	(89)		$	—		$	—
As of September 30, 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222

(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				Six Months Ended
		March 31,				March 31,
Derivatives not designated as hedging instruments:		2021		2020		2021		2020
Energy Services:
Physical commodity contracts	Operating revenues	$	36,419	$	12,096	$	41,671	$	21,932
Physical commodity contracts	Natural gas purchases	2,650		(1,892)		(2,404)		(3,302)
Financial commodity contracts	Natural gas purchases	(27,315)		23,319		20,440		69,412
Foreign currency contracts	Natural gas purchases	27		(475)		227		(360)
Total unrealized and realized gains		$	11,781	$	33,048	$	59,934	$	87,682

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Natural Gas Distribution:
Physical commodity contracts	$	1,091	$	209	$	1,433	$	1,049
Financial commodity contracts	645		(11,434)		(3,627)		(12,522)
Interest rate contracts	—		(6,692)		—		(6,692)
Total unrealized and realized losses	$	1,736	$	(17,917)	$	(2,194)	$	(18,165)

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.

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

(Thousands)	Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives				Location of Gain (Loss) Reclassified from OCI into Income	Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income
	Three Months Ended					Three Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(342)	$	—
	Six Months Ended					Six Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(685)	$	—

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

		Volume (Bcf)
	Transaction Type	March 31, 2021	September 30, 2020
Natural Gas Distribution	Futures	22.1	23.7
	Physical Commodity	16.6	6.0
Energy Services	Futures	(11.6)	(27.5)
	Swaps	(0.8)	(1.8)
	Physical Commodity	1.5	5.0

Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $42,000 as of March 31, 2021 and $5.1 million as of September 30, 2020 and 1,588,000 and 960,000 SRECs that were open as of March 31, 2021 and September 30, 2020, respectively.

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	March 31, 2021		September 30, 2020
Natural Gas Distribution	Restricted broker margin accounts	$	4,190	$	13,525
Energy Services	Restricted broker margin accounts	$	41,726	$	55,919

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 March 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		$	128,585
Noninvestment grade		9,471
Internally rated investment grade		23,661
Internally rated noninvestment grade		20,118
Total		$	181,835

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 March 31, 2021. 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.

XML

FAIR VALUE

6 Months Ended

Mar. 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)	March 31, 2021		September 30, 2020
Carrying value (1) (2) (3)	$	2,102,845	$	2,102,845
Fair market value	$	2,259,855	$	2,417,748

(1)Excludes finance leases of $68.2 million and $74.2 million as of March 31, 2021 and September 30, 2020, respectively.

(2)Excludes NJNG's debt issuance costs of $9.4 million and $9.2 million as of March 31, 2021 and September 30, 2020, respectively.

(3)Excludes NJR's debt issuance costs of $3.3 million and $3.4 million as of March 31, 2021 and September 30, 2020, 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 March 31, 2021 and September 30, 2020 was $155.6 million and $149.2 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 March 31, 2021, NJR discloses its debt within Level 2 of the fair value hierarchy.

Fair Value Hierarchy

NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, 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. NJR's Level 1 assets and liabilities include exchange traded natural gas futures and options contracts, listed equities and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX, CME and ICE that NJR refers 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. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG's treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:

•widely accepted and public;

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

•observable and published.

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

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

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of March 31, 2021:
Assets:
Physical commodity contracts		$	—		$	5,209		$	—	$	5,209
Financial commodity contracts		13,751			193			—		13,944
Financial commodity contracts - foreign exchange		—			257			—		257
Money market funds		50,368			—			—		50,368
Other		1,818			—			—		1,818
Total assets at fair value		$	65,937		$	5,659		$	—	$	71,596
Liabilities:
Physical commodity contracts		$	—		$	36,506		$	—	$	36,506
Financial commodity contracts		7,661			—			—		7,661
Financial commodity contracts - foreign exchange		—			29			—		29
Total liabilities at fair value		$	7,661		$	36,535		$	—	$	44,196
As of September 30, 2020:
Assets:
Physical commodity contracts		$	—		$	7,796		$	—	$	7,796
Financial commodity contracts		18,279			500			—		18,779
Financial commodity contracts - foreign exchange		—			84			—		84
Money market funds		112,291			—			—		112,291
Other		1,840			—			—		1,840
Total assets at fair value		$	132,410		$	8,380		$	—	$	140,790
Liabilities:
Physical commodity contracts		$	—		$	32,517		$	—	$	32,517
Financial commodity contracts		14,593			—			—		14,593
Financial commodity contracts - foreign exchange		—			107			—		107
Total liabilities at fair value		$	14,593		$	32,624		$	—	$	47,217

XML

INVESTMENTS IN EQUITY INVESTEES

6 Months Ended

Mar. 31, 2021

Investments, All Other Investments [Abstract]

INVESTMENTS IN EQUITY INVESTEES

7. INVESTMENTS IN EQUITY INVESTEES

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

(Thousands)	March 31, 2021		September 30, 2020
Steckman Ridge (1)	$	111,435	$	112,378
PennEast (2)	103,086		95,997
Total	$	214,521	$	208,375

(1)Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2021 and September 30, 2020, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

(2)Includes a deferred tax component related to AFUDC equity of $7.6 million and $4.6 million for March 31, 2021 and September 30, 2020, respectively.

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. Due to the expiration of a customer contract in October 2020, the Company evaluated its investment in Steckman Ridge for other-than-temporary impairment and determined an impairment charge was not necessary.

The fair value of the Company’s investment in Steckman Ridge was determined using a discounted cash flow method and utilized management’s best estimates and assumptions related to expected future results, including the price and capacity of firm natural gas storage contracting, operations and maintenance costs, the nature and timing of major maintenance and capital investment, and discount rates. Fair value determinations require considerable judgment and are sensitive to changes in underlying assumptions and other factors. As a result, it is reasonably possible that unfavorable developments, such as the failure to execute storage contracts and other services for available capacity at anticipated price levels could result in an other-than temporary impairment charge in the Unaudited Condensed Consolidated Financial Statements.

PennEast

The Company, through its subsidiary NJR Pipeline Company, is a 20 percent investor in PennEast, a partnership whose purpose is to construct and operate a 120-mile natural gas pipeline that will extend from northeast Pennsylvania to western New Jersey. PennEast received a Certificate of Public Convenience and Necessity for the project from FERC on January 19, 2018.

On September 10, 2019, the Third Circuit issued an order overturning the United States District Court for the District of New Jersey’s order granting PennEast condemnation and immediate access in accordance with the Natural Gas Act to certain properties in which the State of New Jersey holds an interest. A Petition for Rehearing was denied by the Third Circuit on November 5, 2019.

On October 8, 2019, the NJDEP issued a letter indicating that it deemed PennEast’s freshwater wetlands permit application to be administratively incomplete and closed the matter without prejudice. On October 11, 2019, PennEast submitted a letter to the NJDEP objecting to its position that the application is administratively incomplete. PennEast's objections were rejected by the NJDEP on November 18, 2019.

On October 4, 2019, PennEast filed a petition for Declaratory Order with FERC requesting an interpretation of the eminent domain authority of a FERC certificate holder under the Natural Gas Act. The Declaratory Order was granted on January 30, 2020.

On January 30, 2020, PennEast filed an amendment with FERC to construct the PennEast pipeline in two phases. Phase one consists of construction of a 68-mile pipeline in Pennsylvania from the eastern Marcellus Shale region in Luzerne County that would terminate in Northampton County. Phase two includes construction of the remaining original certificated route in Pennsylvania and New Jersey. Construction is expected to begin following approval by FERC of the phased approach and receipt of any remaining governmental and regulatory permits.

On February 18, 2020, PennEast filed a writ of certiorari with the Supreme Court of the United States to review the September 10, 2019 Third Circuit decision.

On June 29, 2020, the Supreme Court requested that the Solicitor General of the United States file a brief that expresses the views on the question of the use of eminent domain to acquire state owned lands for pipeline construction. The Solicitor General filed its brief with the Supreme Court on December 9, 2020.

The State of New Jersey filed a brief with the Supreme Court on December 23, 2020 in response to the brief of the Solicitor General.

On February 3, 2021, the Supreme Court granted the petition for a writ of certiorari. The matter was argued before the Supreme Court on April 28, 2021.

The Company evaluated its investment in PennEast for an other-than-temporary impairment and determined an impairment charge was not necessary. It is reasonably possible that future unfavorable developments, such as a reduced likelihood of success from development options and legal outcomes, estimated increases in construction costs, increases in the discount rate, or further significant delays, could result in an impairment of the Company's equity method investment. Also, the use of alternate judgments and assumptions could result in a different calculation of fair value, which could ultimately result in the recognition of an impairment charge.

XML

EARNINGS PER SHARE

6 Months Ended

Mar. 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				Six Months Ended
	March 31,				March 31,
(Thousands, except per share amounts)	2021		2020		2021		2020
Net income, as reported	$	149,809	$	73,846	$	230,854	$	149,598
Basic earnings per share
Weighted average shares of common stock outstanding-basic	96,248		95,584		96,181		93,747
Basic earnings per common share	$1.56		$0.78		$2.40		$1.60
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	96,248		95,584		96,181		93,747
Equity forward sale agreement (1)	—		—		—		4
Other (2)	370		306		417		322
Weighted average shares of common stock outstanding-diluted	96,618		95,890		96,598		94,073
Diluted earnings per common share (3)	$1.55		$0.77		$2.39		$1.59

(1)See Note 14. Common Stock Equity for details regarding the forward sale agreement.

(2)Consist primarily of unvested stock awards and performance shares.

(3)There were anti-dilutive shares of 24,101 and 30,708 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement during the three months ended March 31, 2021 and 2020. There were anti-dilutive shares of 65,334 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement during the six months ended March 31, 2021. There were no anti-dilutive shares excluded during the six months ended March 31, 2020.

XML

DEBT

6 Months Ended

Mar. 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)	March 31, 2021			September 30, 2020			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	425,000		$	425,000		December 2023
Notes outstanding at end of period	$	8,500		$	125,350
Weighted average interest rate at end of period	1.75		%	1.49		%
Amount available at end of period (2)	$	406,206		$	289,356
Bank revolving credit facilities (1)	$	—		$	250,000
Notes outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (2)	$	—		$	250,000
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		December 2023
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2)Letters of credit outstanding total $10.3 million for both March 31, 2021 and September 30, 2020, which reduces 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 for both March 31, 2021 and September 30, 2020, which reduces the amount available by the same amount.

On April 24, 2020, NJR entered into a 364-day $250 million revolving credit facility with an interest rate based on LIBOR plus 1.625 percent. After six months, all outstanding amounts under the credit facility would convert to a term loan and would be due on April 23, 2021. In connection with entry into this credit facility, all outstanding borrowings under NJR's December 13, 2019, $150 million revolving line of credit facility were repaid. On October 24, 2020, there was no balance outstanding on the $250 million credit facility. As a result, the credit facility was considered terminated.

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

NJNG received $4.0 million in December 2019, in connection with the sale leaseback of its natural gas meters. NJNG records a capital lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease. NJNG exercised early purchase options with respect to certain outstanding meter leases by making final principal payments of $1.2 million for both the six months ended March 31, 2021 and 2020. There were no natural gas meter sale leasebacks recorded during the six months ended March 31, 2021.

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 SREC, TRECs and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if applicable. Clean Energy Ventures continues to operate the solar assets, including related expenses, and retain the revenue generated from SRECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. In December 2020, Clean Energy Ventures received proceeds of $12.1 million in connection with the sale leaseback of two commercial solar projects. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during the six months ended March 31, 2020.

XML

EMPLOYEE BENEFIT PLANS

6 Months Ended

Mar. 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				Six Months Ended				Three Months Ended				Six Months Ended
	March 31,				March 31,				March 31,				March 31,
(Thousands)	2021		2020		2021		2020		2021		2020		2021		2020
Service cost	$	2,183	$	2,055	$	4,365	$	4,111	$	1,211	$	1,072	$	2,422	$	2,427
Interest cost	2,278		2,646		4,556		5,293		1,517		1,509		3,035		3,513
Expected return on plan assets	(4,851)		(5,232)		(10,075)		(10,289)		(1,565)		(1,695)		(3,248)		(3,255)
Recognized actuarial loss	2,861		2,466		5,723		5,212		1,978		930		3,955		3,721
Prior service cost (credit) amortization	26		26		51		51		(45)		(50)		(90)		(99)
Net periodic benefit cost	$	2,497	$	1,961	$	4,620	$	4,378	$	3,096	$	1,766	$	6,074	$	6,307

The Company does not expect to be required to make additional contributions to fund the pension plans during fiscal 2020 or 2021 based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents. In addition, as in the past, the Company may elect to make contributions in excess of the minimum required amount to the plans. There were no discretionary contributions made during the six months ended March 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.

The Company's OPEB liability was revalued for changes related to the Affordable Care Act-mandated excise tax applicable to high-cost health plans, commonly known as the Cadillac Tax. The Company applied a practical expedient to remeasure the plan assets and obligations as of December 31, 2019, which was the nearest calendar month-end date. The impact of the revaluation of the OPEB liability was recorded as of January 1, 2020.

XML

INCOME TAXES

6 Months Ended

Mar. 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, NJR 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.

NJR 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.

The Company evaluates certain tax benefits that have been recorded in the financial statements for uncertainties. During fiscal 2019 the Company concluded that a portion of tax benefits were uncertain at this time. As a result, the Company recorded a reserve that was included in accrued taxes on the Unaudited Condensed Consolidated Balance Sheets. During fiscal 2021, a tax audit was completed and the positions that the prior tax reserves related to are now considered effectively settled and the tax reserve has been released. As a result of the change in the Company's method of accounting for ITCs from the flow through method to the deferral method, which was effective October 1, 2020, the settlement of the reserve was recorded as an adjustment to nonutility plant and equipment, at cost on the Unaudited Condensed Consolidated Balance Sheets.

The reserve for uncertain tax benefits is as follows:

(Thousands)	March 31, 2021		September 30, 2020
Balance at October 1,	$	4,930	$	4,930
Settlements	(4,930)		—
Balance at period end	$	—	$	4,930

The tax benefits related to fiscal tax years open to examination by the IRS may be subject to subsequent adjustments.

On March 27, 2020, the President of the U.S. signed the CARES Act, which is aimed at providing emergency assistance and health care for individuals, families, and businesses affected by the COVID-19 pandemic and generally supporting the U.S. economy. The CARES Act, among other things, includes several business tax provisions which include, but are not limited to modifications of federal net operating loss carrybacks and deductibility, changes to prior year refundable alternative minimum tax liabilities, increase of limitations on business interest deductions from 30 percent to 50 percent of earnings before interest, taxes, depreciation, and amortization, technical corrections of the classification of qualified improvement property making them eligible for bonus depreciation, increase of the limits on charitable contribution deductions from 10 percent to 25 percent of adjusted taxable income, modifications of the treatment of federal loans, loan guarantees, and other investments, suspension of industry specific excise taxes, deferral of the company portion of OASDI, and implementation of a refundable employee retention tax credit.

The CARES Act provides for the delay in the required deposit of the employer portion of the OASDI payroll tax from the date of enactment through the end of 2020. Of the taxes that the Company can defer, 50 percent of the deferred taxes are required to be deposited by the end of 2021 and the remaining 50 percent are required to be deposited by the end of 2022. Additionally, The CARES Act provides a refundable tax credit, the employee retention tax credit, to certain employers who are ordered by a competent governmental authority to suspend or reduce business operations due to concern about the spread of COVID-19 or suffered a significant decline in the business during a calendar quarter during 2020 compared to the same calendar quarter during the previous year. As of March 31, 2021 and September 30, 2020, the Company deferred $5.1 million and $3.1 million, respectively, related to the employer portion of the OASDI tax.

On March 11, 2021, the President of the U.S. signed the American Rescue Plan Act of 2021, which is primarily an economic stimulus package. It also expanded the scope of Section 162(m) of the Internal Revenue Code, which imposes a $1 million deduction limit on compensation paid to covered employees from the top five officers to include the additional top five highest paid employees for tax years beginning after December 31, 2026.

Effective Tax Rate

The forecasted effective tax rates were 19.9 percent and 19.4 percent, for the six months ended March 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 six months ended March 31, 2021, discrete items totaled $(145,000) related to excess tax expense associated with the vesting of share-based awards. During the six months ended March 31, 2020, discrete items totaled $2.7 million related to a revaluation of certain state deferred tax assets and liabilities as a result of a change in the New Jersey state apportionment factor and excess tax benefits associated with the vesting of share-based awards. NJR’s actual effective tax rate was 19.7 percent and 18.0 percent during the six months ended March 31, 2021 and 2020, respectively.

Other Tax Items

As of March 31, 2021 and September 30, 2020, the Company has federal income tax net operating losses of approximately $134.0 million. Federal net operating losses can generally be carried back two years and forward 20 years and will begin to expire in fiscal 2036, with the remainder expiring by 2038. The Company expects to exercise its ability to carryback federal net operating losses to offset taxable income in prior periods.

For the net operating losses it expects to carryback, the Company estimated the portion considered refundable and recorded receivables of approximately $22.8 million as of March 31, 2021 and September 30, 2020, as a component of other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets. Upon filing amended federal income tax returns to carryback its remaining federal net operating losses totaling $24.1 million, the Company will reduce its taxable income in those periods and recapture ITCs of the same amount that were previously utilized to offset taxable income.

In addition, as of March 31, 2021 and September 30, 2020, the Company has tax credit carryforwards of approximately $193.2 million and $195.2 million, respectively, which each have a life of 20 years. When the Company carries back the federal net operating losses noted above, it expects to recapture investment tax credits totaling $24.1 million. These recaptured tax credits are in addition to the $193.2 million and will be carried forward to offset future taxable income. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2034.

As of March 31, 2021 and September 30, 2020, the Company has state income tax net operating losses of approximately $442.4 million and $487.7 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 would begin to expire in fiscal 2021, with the majority expiring after 2035. The Company expects to utilize this entire carryforward, other than as described below.

As of March 31, 2021 and September 30, 2020, the Company has a valuation allowance of $17.6 million, which is primarily related to the recognition of state net operating loss carryforwards in New Jersey.

XML

LEASES

6 Months Ended

Mar. 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 leases terms are between 15 and 35 years and may include multiple options to extend the terms for an additional five to 10 years. The Company’s office leases vary in duration, ranging from one to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of seven years with purchase options available prior to the end of the seven year term. Equipment leases include general office equipment that also vary in duration, most of which are for a term of five 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				Six Months Ended
		March 31,				March 31,
(Thousands)	Income Statement Location	2021		2020		2021		2020
Operating lease cost (1)	Operation and maintenance	$	1,356	1,719		3,445		3,111
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	1,191	$	1,299	$	2,437	$	2,460
Interest on lease liabilities	Interest expense, net of capitalized interest	113		301		334		548
Total finance lease cost		1,304		1,600		2,771		3,008
Short-term lease cost	Operation and maintenance	127		172		254		626
Variable lease cost	Operation and maintenance	549		403		702		1,110
Total lease cost		$	3,336	$	3,894	$	7,172	$	7,855

(1)Net of capitalized costs.

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

	Six Months Ended
	March 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,932	$	2,856
Operating cash flows for finance leases	$	791	$	704
Financing cash flows for finance leases	$	5,690	$	4,038

Assets obtained or modified through amendments in exchange for operating lease liabilities totaled $5.7 million and $12.4 million during the three months ended March 31, 2021 and 2020, respectively, and totaled $13.3 million and $34.0 million during the six months ended March 31, 2021 and 2020, respectively. Assets obtained or modified through finance lease liabilities totaled $45.7 million and $49.7 million during the three and six months ended March 31, 2020, respectively. There were no assets obtained or modified through finance lease liabilities during the three and six months ended March 31, 2021.

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	March 31, 2021		September 30, 2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	144,326	$	131,769
Finance lease assets	Utility plant	61,432		71,085
Total lease assets		$	205,758	$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,001	$	6,724
Finance lease liabilities	Current maturities of long-term debt	5,855		10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	111,034		95,030
Finance lease liabilities	Long-term debt	62,334		63,743
Total lease liabilities		$	183,224	$	175,913

For operating lease assets and liabilities, the weighted average remaining lease term was 27.6 years and 25.5 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.3 percent and 3.2 percent as of March 31, 2021 and September 30, 2020, respectively. For finance lease assets and liabilities as of March 31, 2021 and September 30, 2020, the weighted average remaining lease term was 11.9 years and 11.5 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.5 percent as of both March 31, 2021 and September 30, 2020.

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 leases terms are between 15 and 35 years and may include multiple options to extend the terms for an additional five to 10 years. The Company’s office leases vary in duration, ranging from one to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of seven years with purchase options available prior to the end of the seven year term. Equipment leases include general office equipment that also vary in duration, most of which are for a term of five 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				Six Months Ended
		March 31,				March 31,
(Thousands)	Income Statement Location	2021		2020		2021		2020
Operating lease cost (1)	Operation and maintenance	$	1,356	1,719		3,445		3,111
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	1,191	$	1,299	$	2,437	$	2,460
Interest on lease liabilities	Interest expense, net of capitalized interest	113		301		334		548
Total finance lease cost		1,304		1,600		2,771		3,008
Short-term lease cost	Operation and maintenance	127		172		254		626
Variable lease cost	Operation and maintenance	549		403		702		1,110
Total lease cost		$	3,336	$	3,894	$	7,172	$	7,855

(1)Net of capitalized costs.

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

	Six Months Ended
	March 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,932	$	2,856
Operating cash flows for finance leases	$	791	$	704
Financing cash flows for finance leases	$	5,690	$	4,038

Assets obtained or modified through amendments in exchange for operating lease liabilities totaled $5.7 million and $12.4 million during the three months ended March 31, 2021 and 2020, respectively, and totaled $13.3 million and $34.0 million during the six months ended March 31, 2021 and 2020, respectively. Assets obtained or modified through finance lease liabilities totaled $45.7 million and $49.7 million during the three and six months ended March 31, 2020, respectively. There were no assets obtained or modified through finance lease liabilities during the three and six months ended March 31, 2021.

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	March 31, 2021		September 30, 2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	144,326	$	131,769
Finance lease assets	Utility plant	61,432		71,085
Total lease assets		$	205,758	$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,001	$	6,724
Finance lease liabilities	Current maturities of long-term debt	5,855		10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	111,034		95,030
Finance lease liabilities	Long-term debt	62,334		63,743
Total lease liabilities		$	183,224	$	175,913

For operating lease assets and liabilities, the weighted average remaining lease term was 27.6 years and 25.5 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.3 percent and 3.2 percent as of March 31, 2021 and September 30, 2020, respectively. For finance lease assets and liabilities as of March 31, 2021 and September 30, 2020, the weighted average remaining lease term was 11.9 years and 11.5 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.5 percent as of both March 31, 2021 and September 30, 2020.

XML

COMMITMENTS AND CONTINGENT LIABILITIES

6 Months Ended

Mar. 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 $156.0 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 March 31, 2021, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

(Thousands)	2021		2022		2023		2024		2025		Thereafter
Energy Services:
Natural gas purchases	$	98,845	$	—	$	—	$	—	$	—	$	—
Storage demand fees	18,712		14,248		6,712		3,318		2,742		277
Pipeline demand fees	60,585		49,224		21,689		18,673		16,245		34,074
Sub-total Energy Services	$	178,142	$	63,472	$	28,401	$	21,991	$	18,987	$	34,351
NJNG:
Natural gas purchases	$	32,320	$	—	$	—	$	—	$	—	$	—
Storage demand fees	37,285		28,593		17,090		11,506		2,207		2,495
Pipeline demand fees	118,672		150,719		136,124		158,600		154,297		1,437,814
Sub-total NJNG	$	188,277	$	179,312	$	153,214	$	170,106	$	156,504	$	1,440,309
Total	$	366,419	$	242,784	$	181,615	$	192,097	$	175,491	$	1,474,660

Certain pipeline demand fees totaling $4.0 million per year, for which Energy Services is the responsible party, will be 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, and Freehold, New Jersey, collectively, the "former MGP sites", including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future expenditures at the former MGP sites for which it is responsible, including potential liabilities for further and continued natural resource damages, may be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites. At the MGP site in Freehold, New Jersey, as the Company has not yet completed the remedial investigation of the site, the total amount of potential costs of all remedial actions cannot be reasonably estimated at this time.

The estimated total future expenditures for all former MGP sites will range from approximately $143.1 million to $181.7 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, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets of $143.5 million as of March 31, 2021, and $150.6 million as of September 30, 2020, based on the most likely amount. The remediation liability at March 31, 2021, includes adjustments for actual expenditures during fiscal 2021. 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. NJNG will continue to gather information to determine whether the obligation exists to undertake remedial action.

NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. On September 9, 2020, the BPU approved NJNG's increase in the RAC, which increased the annual recovery from $8.5 million to $9.7 million and is effective October 1, 2020. As of March 31, 2021, $37.5 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, NJR 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. NJR also discloses contingent matters for which there is a reasonable possibility of a loss. Based upon currently available information, NJR believes that the results of litigation that is 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 NJR’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.

XML

COMMON STOCK EQUITY

6 Months Ended

Mar. 31, 2021

Equity [Abstract]

COMMON STOCK EQUITY

14. COMMON STOCK EQUITY

In December 2019, the Company completed an equity offering of 6,545,454 common shares, consisting of 5,333,334 common shares issued directly by the Company and 1,212,120 common shares issuable pursuant to forward sales agreements with investment banks. The issuance of 5,333,334 resulted in proceeds of approximately $212.9 million, net of issuance costs, and was reflected in shareholders' equity and as a financing activity on the statement of cash flows.

Under the forward sale agreements, a total of 1,212,120 common shares were borrowed from third parties and sold to the underwriters. Each forward sale agreement allows the Company, at its election and prior to September 30, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement, which was initially $40.0125 per share, or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as anticipated dividends.

On September 18, 2020, the Company amended its forward sale agreements to extend the maturity date of such forward sales agreements from September 30, 2020 to September 10, 2021. On March 3, 2021, the Company cash settled a portion of the forward sale agreement for a payout of $387,744 for 727,272 common shares. As of March 31, 2021, if the Company elected to net settle the remaining forward sale agreement, the Company would have paid approximately $1.4 million under a cash settlement or would have issued 31,607 common shares under a net share settlement.

Issuances of shares under the forward sale agreements are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreements have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method until settlement of the forward sale agreements. Under this method, the number of the Company common shares used in calculating diluted EPS is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreements less the number of shares that would be purchased by the Company in the market (based on the average market price during the same reporting period) using the proceeds receivable upon settlement (based on the adjusted forward sale price at the end of that reporting period). Share dilution occurs when the average market price of the Company's common shares is higher than the adjusted forward sale price. See Note 8. Earnings Per Share for the impact of the forward sale agreements on the calculation of diluted earnings per share.

XML

REPORTING SEGMENT AND OTHER OPERATIONS DATA

6 Months Ended

Mar. 31, 2021

Segment Reporting [Abstract]

REPORTING SEGMENT AND OTHER OPERATIONS DATA

15. 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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues
Natural Gas Distribution
External customers	$	310,167	$	297,220	$	505,896	$	516,843
Clean Energy Ventures
External customers	6,476		5,995		12,846		12,207
Energy Services
External customers (1)	459,766		313,959		687,115		682,263
Intercompany	2,803		(258)		4,931		1,853
Storage and Transportation
External customers	13,257		10,401		25,704		18,806
Intercompany	669		675		1,326		1,342
Subtotal	793,138		627,992		1,237,818		1,233,314
Home Services and Other
External customers	12,521		12,039		24,931		24,531
Intercompany	252		326		419		741
Eliminations	(3,724)		(743)		(6,676)		(3,936)
Total	$	802,187	$	639,614	$	1,256,492	$	1,254,650
Depreciation and amortization
Natural Gas Distribution	$	19,475	$	18,100	$	38,644	$	34,917
Clean Energy Ventures	4,685		6,603		10,118		12,919
Energy Services (2)	13		27		55		56
Storage and Transportation	2,364		2,397		5,004		4,078
Subtotal	26,537		27,127		53,821		51,970
Home Services and Other	227		250		487		496
Eliminations	84		139		(98)		(313)
Total	$	26,848	$	27,516	$	54,210	$	52,153
Interest income (3)
Natural Gas Distribution	$	76	$	136	$	158	$	243
Clean Energy Ventures	240		—		240		—
Energy Services	—		52		—		89
Storage and Transportation	851		2,085		1,545		2,782
Subtotal	1,167		2,273		1,943		3,114
Home Services and Other	127		208		259		699
Eliminations	(237)		(760)		(476)		(1,906)
Total	$	1,057	$	1,721	$	1,726	$	1,907

(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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Interest expense, net of capitalized interest
Natural Gas Distribution	$	9,006	$	7,473	$	17,980	$	15,305
Clean Energy Ventures	5,266		4,835		10,300		9,327
Energy Services	575		937		1,255		2,163
Storage and Transportation	3,578		5,621		7,560		8,443
Subtotal	18,425		18,866		37,095		35,238
Home Services and Other	1,728		565		2,844		837
Eliminations	—		(228)		—		(802)
Total	$	20,153	$	19,203	$	39,939	$	35,273
Income tax provision (benefit)
Natural Gas Distribution	$	15,622	$	19,702	$	23,989	$	28,337
Clean Energy Ventures	(2,714)		(4,134)		(5,800)		(7,968)
Energy Services	23,128		(2,449)		35,250		8,303
Storage and Transportation	873		1,105		1,519		1,807
Subtotal	36,909		14,224		54,958		30,479
Home Services and Other	(59)		1,956		59		2,175
Eliminations	2,207		104		1,481		101
Total	$	39,057	$	16,284	$	56,498	$	32,755
Equity in earnings of affiliates
Storage and Transportation	$	3,386	$	3,921	$	6,579	$	7,585
Eliminations	(582)		(332)		(1,100)		(607)
Total	$	2,804	$	3,589	$	5,479	$	6,978
Net financial earnings (loss)
Natural Gas Distribution	$	80,541	$	86,336	$	130,008	$	130,192
Clean Energy Ventures	(8,872)		(8,829)		(19,146)		(17,008)
Energy Services	96,528		2,487		98,028		(2,635)
Storage and Transportation	4,711		4,258		8,219		7,262
Subtotal	172,908		84,252		217,109		117,811
Home Services and Other	747		148		685		1,257
Eliminations	(3,051)		(109)		(2,533)		154
Total	$	170,604	$	84,291	$	215,261	$	119,222
Capital expenditures
Natural Gas Distribution	$	97,239	$	72,042	$	176,485	$	149,839
Clean Energy Ventures	18,549		24,087		40,884		69,786
Storage and Transportation	20,094		5,148		27,707		7,709
Subtotal	135,882		101,277		245,076		227,334
Home Services and Other	125		(111)		811		15
Total	$	136,007	$	101,166	$	245,887	$	227,349
Investments in equity investees
Storage and Transportation	$	196	$	757	$	482	$	1,266
Total	$	196	$	757	$	482	$	1,266

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Net financial earnings	$	170,604	$	84,291	$	215,261	$	119,222
Less:
Unrealized gain on derivative instruments and related transactions	29,255		(3,773)		(8,235)		(45,539)
Tax effect	(6,954)		897		1,958		10,828
Effects of economic hedging related to natural gas inventory	(7,209)		14,622		(14,741)		5,735
Tax effect	1,713		(3,475)		3,503		(1,363)
NFE tax adjustment	3,990		2,174		1,922		(37)
Net income	$	149,809	$	73,846	$	230,854	$	149,598

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 is 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. Additionally, realized derivative gains and losses are also included in current period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical natural gas flows. Included in the tax effects are current and deferred income tax expense corresponding with the NFE. NJR also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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

(Thousands)	March 31, 2021		September 30, 2020
Assets at end of period:
Natural Gas Distribution	$	3,593,630	$	3,531,477
Clean Energy Ventures	848,290		814,277
Energy Services	224,069		244,836
Storage and Transportation	874,976		844,799
Subtotal	5,540,965		5,435,389
Home Services and Other	136,531		138,375
Intercompany assets (1)	(252,362)		(257,287)
Total	$	5,425,134	$	5,316,477

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

XML

RELATED PARTY TRANSACTIONS

6 Months Ended

Mar. 31, 2021

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

16. 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 March 31, 2021, Energy Services has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2021.

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Natural Gas Distribution	$	1,505	$	1,477	$	3,073	$	2,971
Energy Services	226		29		391		59
Total	$	1,731	$	1,506	$	3,464	$	3,030

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

(Thousands)	March 31, 2021		September 30, 2020
Natural Gas Distribution	$	775	$	775
Energy Services	78		16
Total	$	853	$	791

NJNG and Energy Services have entered into various asset management agreements, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. As of March 31, 2021, NJNG and Energy Services had three asset management agreements with expiration dates ranging from October 31, 2021 through March 31, 2022.

NJNG has entered into a 15-year transportation precedent agreement for committed capacity of 180,000 Dths per day and NJRES has entered into a 5-year, 50,000 Dths per day transportation precedent agreement with PennEast, both to commence when PennEast is placed in service.

NJNG has entered into a transportation precedent agreement with Adelphia Gateway for committed capacity of 130,000 Dths per day, which expires in October 2026.

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. On February 19, 2021, Energy Services entered into a park and loan agreement with Leaf River for 330,000 Dths, which expired on April 30, 2021 and is eliminated in consolidation.

NJNG and Clean Energy Ventures entered into a sublease agreement and PPA agreement related to an onsite solar array and the related energy output at the Company’s headquarters in Wall, New Jersey.

XML

ACQUISITIONS AND DISPOSITIONS

6 Months Ended

Mar. 31, 2021

Business Combinations [Abstract]

ACQUISITIONS AND DISPOSITIONS

17. ACQUISITIONS AND DISPOSITIONS

Acquisitions

Adelphia Gateway

On January 13, 2020, Adelphia Gateway, an indirect wholly-owned subsidiary of NJR, acquired all of Talen’s membership interests in IEC, an existing 84-mile pipeline in southeastern Pennsylvania, including related assets and rights of

way, for a base purchase price of $166 million. In November 2017, the Company made an initial payment of $10 million towards the base purchase price, which was included in other noncurrent assets on the Consolidated Balance Sheets. The remaining purchase price of $156 million was paid upon the close of the acquisition of the related assets. As additional consideration, Adelphia Gateway will pay Talen specified amounts of up to $23 million contingent upon the achievement of certain regulatory approvals and binding natural gas capacity commitments. On December 20, 2019, FERC issued Adelphia Gateway’s Certificate of Public Convenience and Necessity. Adelphia Gateway has agreed to provide firm natural gas transportation service for 10 years following the closing to two power generators owned by affiliates of Talen that are currently served by the pipeline.

The Company evaluated the acquisition under the guidance of ASU 2017-01, Clarifying the Definition of a Business and concluded that the acquisition did not meet the definition of a business, as almost all of the fair value relates to the pipeline assets acquired. As a result, the purchase was accounted for as an asset acquisition.

The following table summarizes the consideration transferred and purchase price allocation based upon the relative fair value of the assets acquired and liabilities to be assumed:

(Thousands)	Estimated Fair Value
Purchase price	$	166,000
Net working capital adjustment	(449)
Transaction costs	9,456
Total costs capitalized	$	175,007
Identifiable assets acquired
Property, plant and equipment	$	174,438
Other	1,018
Net working capital	(449)
Net assets acquired	$	175,007

The Company utilized a discounted cash flow valuation technique to measure the fair value of the property, plant, and equipment based upon the present value of their future economic benefits reflecting current market expectations. The assumptions used in the discounted cash flow valuation are not observable in active markets and thus represent non-recurring Level 3 fair value measurements.

Property, plant and equipment consist primarily of pipeline related assets, land, buildings and other structures and software. Depreciation is computed on a straight-line basis over the estimated useful life of the assets, ranging from five to 30 years, based on various classes of depreciable property. Other assets consist primarily of an assembled workforce and base natural gas.

Asset retirement obligations are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The Company records any asset retirement obligations in the period in which information permitting a reasonable estimate of such obligation becomes available. The Company is unable to predict when, or if, the pipelines would become completely obsolete and require decommissioning. As such, upon acquisition, there were no liabilities recorded for asset retirement obligations, as both the timing and future estimates of decommissioning the pipeline was indeterminable.

Leaf River

On October 11, 2019, NJR Pipeline Company, an indirect wholly-owned subsidiary of NJR, acquired 100 percent of the issued and outstanding limited liability company interests of Leaf River Energy Center LLC for $367.5 million. The purchase price was subject to certain contractual conditions, including customary purchase price adjustments related to the amount of net working capital and transaction expenses. Leaf River owns and operates a 32.2 million Dth salt dome natural gas storage facility, located in southeastern Mississippi.

The Company evaluated the acquisition under the guidance of ASU 2017-01, Clarifying the Definition of a Business and concluded that the acquisition did not meet the definition of a business, as almost all of the fair value relates to the natural gas storage assets acquired. As a result, the purchase was accounted for as an asset acquisition.

The following table summarizes the consideration transferred and purchase price allocation based upon the relative fair value of the assets acquired and liabilities to be assumed:

(Thousands)	Estimated Fair Value
Purchase price	$	367,500
Net working capital adjustment	4,111
Transaction costs	1,664
Total costs capitalized	$	373,275
Identifiable assets acquired
Property, plant and equipment	$	365,715
Base gas	3,445
Other assets, net	4
Net working capital	4,111
Net assets acquired	$	373,275

The total consideration transferred is comprised of the purchase price to the seller and the transaction costs incurred during the acquisition. The Company utilized a discounted cash flow valuation technique to measure the fair value of the property, plant, and equipment based upon the present value of their future economic benefits reflecting current market expectations. Base gas is valued based upon the estimated replacement costs associated with the respective assets.

Base gas is needed to maintain the necessary pressure to allow efficient operation of the storage facility. The base gas is determined to be recoverable and is considered a component of the facility and presented as a component in property, plant and equipment. This natural gas is not depreciated, as it is expected to be recovered and sold.

Property, plant and equipment consist primarily of surface equipment and pipelines necessary to operate the facility. Depreciation is computed on a straight-line basis over the estimated useful life of the assets, ranging from five to 50 years, based on various classes of depreciable property.

Asset retirement obligations are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The Company records any asset retirement obligations in the period in which information permitting a reasonable estimate of such obligation becomes available. The Company is unable to predict when, or if, the storage facilities and related pipelines would become completely obsolete and require decommissioning. As such, upon acquisition, there were no liabilities recorded for asset retirement obligations, as both the timing and future estimates of decommissioning the storage facilities and related pipelines were indeterminable.

The assumptions used in the discounted cash flow valuation are not observable in active markets and thus represent non-recurring Level 3 fair value measurements.

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Mar. 31, 2021

Accounting Policies [Abstract]

Consolidation

The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by NJR in accordance with the rules and regulations of the SEC and GAAP. The September 30, 2020 Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in NJR's 2020 Annual Report on Form 10-K.

The Unaudited Condensed Consolidated Financial Statements include the accounts of NJR and its subsidiaries. In the opinion of management, the accompanying Unaudited Condensed Consolidated Financial Statements reflect all adjustments necessary for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of NJR's utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ending September 30, 2021. 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. ARO 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.

Acquisitions

Acquisitions

The Company follows the guidance in ASC 805, Business Combinations, for determining the appropriate accounting treatment for acquisitions. ASU No. 2017-01, Clarifying the Definition of a Business, provides an initial fair value screen to determine if substantially all of the fair value of the assets acquired is concentrated in a single asset or group of similar assets. If the initial screening test is not met, the set is considered a business based on whether there are inputs and substantive processes in place. Based on the results of this analysis and conclusion on an acquisition’s classification of a business combination or an asset acquisition, the accounting treatment is derived.

If the acquisition is deemed to be a business, the acquisition method of accounting is applied. Identifiable assets acquired and liabilities assumed at the acquisition date are recorded at fair value. If the transaction is deemed to be an asset purchase, the cost accumulation and allocation model is used whereby the assets and liabilities are recorded based on the purchase price and allocated to the individual assets and liabilities based on relative fair values.

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various assumptions and valuation methodologies requiring considerable management judgment. The most significant variables in these valuations are discount rates and the number of years on which to base the cash flow projections, as well as other assumptions and estimates used to determine the cash inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets, specific risks, industry beta and capital structure of guideline companies. The valuation of an acquired business is based on available information at the acquisition date and assumptions that are believed to be reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date.

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.

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 escrow balances for utility plant projects at NJNG and irrevocable letters of credit at Leaf River, which is recorded in other current and noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets, respectively.

Allowance for Doubtful Accounts

Allowance for Doubtful Accounts

As of October 1, 2021, the Company adopted ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The Company segregates financial assets that fall within the scope of ASC 326, 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.

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 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.

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 $4.0 million in December 2019, in connection with the sale leaseback of its natural gas meters. There were no natural gas meter sale leasebacks recorded during the six months ended March 31, 2021.

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 terms of 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 SRECs, TRECs 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.

In December 2020, Clean Energy Ventures received proceeds of $12.1 million in connection with the sale leaseback of two commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during the three and six months ended March 31, 2020.

Recently Adopted Updates to the Accounting Standards Codification

Recently Adopted Updates to the Accounting Standards Codification

Financial Instruments

In June 2016, the FASB issued ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. An entity will apply the amendment through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The Company assessed the impact of the guidance on NJR's reserve methodologies and credit policies and procedures for any assets that could be impacted, noting the majority of NJR's financial assets are short-term in nature, such as trade receivables and unbilled revenues.

The Company completed its evaluation of this amendment and all subsequent amendments related to this topic and adopted this guidance on October 1, 2020 using the modified retrospective method. The adoption did not result in a cumulative effect adjustment to retained earnings as the current expected lifetime loss estimates were not materially different from the reserves already in place.

The Company segregates financial assets that fall within the scope of ASC 326, 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.

Fair Value

In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The Company adopted this guidance on October 1, 2020 on a prospective basis. The Company does not have either Level 3 fair value measurements or transfers between Level 1 or Level 2 in its current portfolios, and therefore, this ASU did not have an impact to the Company's financial position, results of operations or cash flows.

Compensation - Retirement Benefits

In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures and adds new disclosure requirements identified as relevant. The Company adopted this guidance on October 1, 2020. There was no impact to the Company's financial position, results of operations or cash flows.

Reference Rate Reform

In January 2021, the FASB issued ASU 2021-01, which refines the scope of ASC 848, Reference Rate Reform, and clarifies some of its guidance of global reference rate reform activities. The amendments in this update permits entities to elect certain optional expedients and exceptions when accounting for derivative contracts and certain hedging relationships affected by changes in the interest rates used for discounting cash flows, for computing variation margin settlements, and for calculating price alignment interest in connection with reference rate reform activities under way in global financial markets (the “discounting transition”). The amendments in this update are effective upon the ASU issuance through December 31, 2022. There was no impact to the Company's financial position, results of operations or cash flows as a result of its adoption.

Other Recent 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 guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. Upon adoption, the amendments will be applied 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.

Investments - Equity Method and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, Investments - Equity Securities (Topic 321), Investments - Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815): Clarifying the Interactions between Topic 321, Topic 323, and Topic 815. 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 guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of these amendments but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

Other

In October 2020, the FASB issued ASU 2020-10, 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 guidance is effective for the Company on October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of these amendments but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

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

NJR applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, 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. NJR's Level 1 assets and liabilities include exchange traded natural gas futures and options contracts, listed equities and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX, CME and ICE that NJR refers 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. NJR's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG's treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:

•widely accepted and public;

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

•observable and published.

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

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

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 leases terms are between 15 and 35 years and may include multiple options to extend the terms for an additional five to 10 years. The Company’s office leases vary in duration, ranging from one to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of seven years with purchase options available prior to the end of the seven year term. Equipment leases include general office equipment that also vary in duration, most of which are for a term of five 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.

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

6 Months Ended

Mar. 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)	March 31, 2021		September 30, 2020		March 31, 2020		September 30, 2019
Balance Sheet
Cash and cash equivalents	$	57,654	$	117,012	$	25,968	$	2,676
Restricted cash in other noncurrent assets	$	1,321	$	2,411	$	2,422	$	1,387
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	58,975	$	119,423	$	28,390	$	4,063

Summary of Natural Gas in Storage

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

	March 31, 2021				September 30, 2020
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	40,083	9.4		$	110,037	27.2
Energy Services		34,439		13.3		57,352		34.3
Storage and Transportation		331		0.1		115		0.02
Total		$	74,853	22.8		$	167,504	61.52

Schedule of Software Costs Included in the Consolidated Financial Statements

The following table presents the software costs included in the Unaudited Condensed Consolidated Financial Statements:

(Thousands)	March 31, 2021		September 30, 2020
Balance Sheets
Utility plant, at cost	$	14,011	$	13,452
Nonutility plant and equipment, at cost	$	334	$	316
Accumulated depreciation and amortization, utility plant	$	(790)	$	(279)
Accumulated depreciation and amortization, nonutility plant and equipment	$	(17)	$	(5)
Software costs	$	5,485	$	4,707

	Three Months Ended				Six Months Ended
	March 31,				March 31,
Statements of Operations	2021		2020		2021		2020
Operation and maintenance (1)	$	2,847	$	1,109	$	4,770	$	2,596
Depreciation and amortization	$	270	$	—	$	523	$	—

(1)During the three and six months ended March 31, 2021, $111,000 and $188,000 was amortized from software costs into O&M. There were no amounts amortized for the three and six months ended March 31, 2020.

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 March 31, 2021 and 2020:

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at December 31, 2020	$	(10,166)	$	(33,106)		$	(43,272)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive income, net of tax of $(79), $(244), $(323), respectively	263		813		(1)	1,076
Balance at March 31, 2021	$	(9,903)	$	(32,293)		$	(42,196)
Balance at December 31, 2019	$	—	$	(31,028)		$	(31,028)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $2,781, $(1,681), $1,100	(9,711)		5,378			(4,333)
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(72), $(72)	—		722		(1)	722
Net current-period other comprehensive income, net of tax of $2,781, $(1,753), $1,028	(9,711)		6,100			(3,611)
Balance at March 31, 2020	$	(9,711)	$	(24,928)		$	(34,639)

(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.

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

(Thousands)	Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2020	$	(10,397)	$	(33,918)		$	(44,315)
Other comprehensive income, net of tax
Amounts reclassified from accumulated other comprehensive income, net of tax of $(191), $(489), $(680), respectively	494		1,625		(1)	2,119
Balance at March 31, 2021	$	(9,903)	$	(32,293)		$	(42,196)
Balance at September 30, 2019	$	—	$	(31,787)		$	(31,787)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $2,781, $(1,681), $1,100	(9,711)		5,378			(4,333)
Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(289) and $(289)	—		1,481		(1)	1,481
Net current-period other comprehensive income, net of tax of $2,781, $(1,970), $811	(9,711)		6,859			(2,852)
Balance at March 31, 2020	$	(9,711)	$	(24,928)		$	(34,639)

(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.

Impact of Changes Resulting from Change in Accounting Principle

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the three months ended March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	30,784	(3,268)	$	27,516
Total operating expenses	$	544,399	(3,268)	$	541,131
Operating income	$	95,215	3,268	$	98,483
Income before income taxes and equity in earnings of affiliates	$	83,273	3,268	$	86,541
Income tax (benefit) expense	$	(1,643)	17,927	$	16,284
Net income	$	88,505	(14,659)	$	73,846
Earnings per common share
Basic	$	0.93	(0.15)	$	0.78
Diluted	$	0.92	(0.15)	$	0.77

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the six months ended March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	58,542	(6,389)	$	52,153
Total operating expenses	$	1,057,938	(6,389)	$	1,051,549
Operating income	$	196,712	6,389	$	203,101
Income before income taxes and equity in earnings of affiliates	$	168,986	6,389	$	175,375
Income tax (benefit) expense	$	(1,902)	34,657	$	32,755
Net income	$	177,866	(28,268)	$	149,598
Earnings per common share
Basic	$	1.90	(0.30)	$	1.60
Diluted	$	1.89	(0.30)	$	1.59

The cumulative effect of the change in accounting policy on the Unaudited Condensed Consolidated Balance Sheets as of September 30, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Assets
Nonutility plant and equipment, at cost	$	1,430,723	(322,211)	$	1,108,512
Accumulated depreciation and amortization, nonutility plant and equipment	$	(202,507)	61,945	$	(140,562)
Property, plant and equipment, net	$	3,983,035	(260,266)	$	3,722,769
Other noncurrent assets	$	78,716	6,941	$	85,657
Total noncurrent assets	$	964,435	6,941	$	971,376
Total assets	$	5,569,802	(253,325)	$	5,316,477
Capitalization
Retained earnings	$	1,148,297	(200,796)	$	947,501
Common stock equity	$	1,844,692	(200,796)	$	1,643,896
Total capitalization	$	4,104,158	(200,796)	$	3,903,362
Liabilities
Deferred income taxes	$	190,610	(52,529)	$	138,081
Total noncurrent liabilities	$	931,922	(52,529)	$	879,393
Total capitalization and liabilities	$	5,569,802	(253,325)	$	5,316,477

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Cash Flows as of March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Depreciation and amortization	$	58,542	(6,389)	$	52,153
Deferred income taxes	$	318	34,657	$	34,975

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Common Stock Equity as of March 31, 2020 is as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Retained Earnings
Balance at September 30, 2019	$	1,075,960	(206,102)	$	869,858
Net income	$	89,361	(13,609)	$	75,752
Balance at December 31, 2019	$	1,135,475	(219,711)	$	915,764
Net income	$	88,505	(14,659)	$	73,846
Balance at March 31, 2020	$	1,194,092	(234,370)	$	959,722
Total
Balance at September 30, 2019	$	1,551,717	(206,102)	$	1,345,615
Net income	$	89,361	(13,609)	$	75,752
Balance at December 31, 2019	$	1,827,803	(219,711)	$	1,608,092
Net income	$	88,505	(14,659)	$	73,846
Balance at March 31, 2020	$	1,889,107	(234,370)	$	1,654,737

XML

REVENUE (Tables)

6 Months Ended

Mar. 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 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 on a monthly basis in line with the terms of the contract and based on the services provided. Payment is due each month for the previous month's invoiced services.
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, related usage fees for the use of storage space, 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 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:
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 hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. 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 March 31, 2021 and 2020, is as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales	$	296,888	—		—	—	—	$	296,888
Natural gas services	—		—		11,011	13,926	—	24,937
Service contracts	—		—		—	—	8,314	8,314
Installations and maintenance	—		—		—	—	4,459	4,459
Renewable energy certificates	—		817		—	—	—	817
Electricity sales	—		4,882		—	—	—	4,882
Eliminations (1)	—		—		—	(669)	(252)	(921)
Revenues from contracts with customers	296,888		5,699		11,011	13,257	12,521	339,376
Alternative revenue programs (2)	(6,664)		—		—	—	—	(6,664)
Derivative instruments	19,943		777	(3)	451,558	—	—	472,278
Eliminations (1)	—		—		(2,803)	—	—	(2,803)
Revenues out of scope	13,279		777		448,755	—	—	462,811
Total operating revenues	$	310,167	6,476		459,766	13,257	12,521	$	802,187
2020
Natural gas utility sales	$	266,868	—		—	—	—	$	266,868
Natural gas services	—		—		9,634	11,076	—	20,710
Service contracts	—		—		—	—	8,073	8,073
Installations and maintenance	—		—		—	—	4,292	4,292
Electricity sales	—		4,458		—	—	—	4,458
Eliminations (1)	—		—		—	(675)	(326)	(1,001)
Revenues from contracts with customers	266,868		4,458		9,634	10,401	12,039	303,400
Alternative revenue programs (2)	22,073		—		—	—	—	22,073
Derivative instruments	8,279		1,537		304,067	—	—	313,883
Eliminations (1)	—		—		258	—	—	258
Revenues out of scope	30,352		1,537		304,325	—	—	336,214
Total operating revenues	$	297,220	5,995		313,959	10,401	12,039	$	639,614

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

(2)Includes CIP revenue.

(3)Includes SREC revenue.

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

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Natural gas utility sales	$	486,252	—		—	—	—	$	486,252
Natural gas services	—		—		17,439	27,030	—	44,469
Service contracts	—		—		—	—	16,573	16,573
Installations and maintenance	—		—		—	—	8,777	8,777
Renewable energy certificates	—		1,507		—	—	—	1,507
Electricity sales	—		9,270		—	—	—	9,270
Eliminations (1)	—		—		—	(1,326)	(419)	(1,745)
Revenues from contracts with customers	486,252		10,777		17,439	25,704	24,931	565,103
Alternative revenue programs (2)	(5,096)		—		—	—	—	(5,096)
Derivative instruments	24,740		2,069	(3)	674,607	—	—	24,740
Eliminations (1)	—		—		(4,931)	—	—	(4,931)
Revenues out of scope	19,644		2,069		669,676	—	—	691,389
Total operating revenues	$	505,896	12,846		687,115	25,704	24,931	$	1,256,492
2020
Natural gas utility sales	$	486,762	—		—	—	—	$	486,762
Natural gas services	—		—		16,955	20,148	—	37,103
Service contracts	—		—		—	—	16,111	16,111
Installations and maintenance	—		—		—	—	9,161	9,161
Electricity sales	—		8,476		—	—	—	8,476
Eliminations (1)	—		—		—	(1,342)	(741)	(2,083)
Revenues from contracts with customers	486,762		8,476		16,955	18,806	24,531	555,530
Alternative revenue programs (2)	20,130		—		—	—	—	20,130
Derivative instruments	9,951		3,731	(3)	667,161	—	—	680,843
Eliminations (1)	—		—		(1,853)	—	—	(1,853)
Revenues out of scope	30,081		3,731		665,308	—	—	699,120
Total operating revenues	$	516,843	12,207		682,263	18,806	24,531	$	1,254,650

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

(2)Includes CIP revenue.

(3)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 March 31, 2021 and 2020, is as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	225,174	2,692	—	—	12,234	$	240,100
Commercial and industrial	42,824		3,007	11,011	13,257	287	70,386
Firm transportation	28,190		—	—	—	—	28,190
Interruptible and off-tariff	700		—	—	—	—	700
Revenues out of scope	13,279		777	448,755	—	—	462,811
Total operating revenues	$	310,167	6,476	459,766	13,257	12,521	$	802,187
2020
Residential	$	199,776	2,469	—	—	11,831	$	214,076
Commercial and industrial	41,635		1,989	9,634	10,401	208	63,867
Firm transportation	24,123		—	—	—	—	24,123
Interruptible and off-tariff	1,334		—	—	—	—	1,334
Revenues out of scope	30,352		1,537	304,325	—	—	336,214
Total operating revenues	$	297,220	5,995	313,959	10,401	12,039	$	639,614

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

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2021
Residential	$	362,398	5,414	—	—	24,438	$	392,250
Commercial and industrial	72,053		5,363	17,439	25,704	493	121,052
Firm transportation	49,294		—	—	—	—	49,294
Interruptible and off-tariff	2,507		—	—	—	—	2,507
Revenues out of scope	19,644		2,069	669,676	—	—	691,389
Total operating revenues	$	505,896	12,846	687,115	25,704	24,931	$	1,256,492
2020
Residential	$	352,998	4,929	—	—	24,110	$	382,037
Commercial and industrial	87,057		3,547	16,955	18,806	421	126,786
Firm transportation	43,712		—	—	—	—	43,712
Interruptible and off-tariff	2,995		—	—	—	—	2,995
Revenues out of scope	30,081		3,731	665,308	—	—	699,120
Total operating revenues	$	516,843	12,207	682,263	18,806	24,531	$	1,254,650

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 six months ended March 31, 2021 are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of October 1, 2020	$	134,173	$	9,226	$	25,934
Increase (Decrease)	103,056		32,715		(5,171)
Balance as of March 31, 2021	$	237,229	$	41,941	$	20,763

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 March 31, 2021:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
Customer accounts receivable
Billed	$	119,845	4,794	107,353	3,437	1,800	$	237,229
Unbilled	39,652		2,289	—	—	—	41,941
Customers' credit balances and deposits	(20,763)		—	—	—	—	(20,763)
Total	$	138,734	7,083	107,353	3,437	1,800	$	258,407

XML

REGULATION (Tables)

6 Months Ended

Mar. 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)	March 31, 2021		September 30, 2020
Regulatory assets-current
New Jersey Clean Energy Program	$	6,147	$	15,570
Conservation Incentive Program	14,025		19,120
Derivatives at fair value, net	1,509		—
Other current regulatory assets	1,730		1,682
Total current regulatory assets	$	23,411	$	36,372
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	37,476	$	36,516
Liability for future expenditures	143,495		150,590
Deferred income taxes	31,603		28,241
Derivatives at fair value, net	4		1
SAVEGREEN	21,842		21,281
Postemployment and other benefit costs	180,360		188,170
Deferred storm damage costs	5,429		6,515
Cost of removal	82,353		75,080
Other noncurrent regulatory assets	17,952		20,068
Total noncurrent regulatory assets	$	520,514	$	526,462
Regulatory liability-current
Overrecovered natural gas costs	$	541	$	25,914
Derivatives at fair value, net	176		274
Total current regulatory liabilities	$	717	$	26,188
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	192,895	$	195,425
Derivatives at fair value, net	—		352
Other noncurrent regulatory liabilities	759		509
Total noncurrent regulatory liabilities	$	193,654	$	196,286

(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.

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

(Thousands)	March 31, 2021		September 30, 2020
Total current regulatory assets	$	116	$	158
Total noncurrent regulatory assets	$	1,514	$	997
Total-noncurrent regulatory liabilities	$	164	$	—

Schedule of Regulatory Assets

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

(Thousands)	March 31, 2021		September 30, 2020
Regulatory assets-current
New Jersey Clean Energy Program	$	6,147	$	15,570
Conservation Incentive Program	14,025		19,120
Derivatives at fair value, net	1,509		—
Other current regulatory assets	1,730		1,682
Total current regulatory assets	$	23,411	$	36,372
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	37,476	$	36,516
Liability for future expenditures	143,495		150,590
Deferred income taxes	31,603		28,241
Derivatives at fair value, net	4		1
SAVEGREEN	21,842		21,281
Postemployment and other benefit costs	180,360		188,170
Deferred storm damage costs	5,429		6,515
Cost of removal	82,353		75,080
Other noncurrent regulatory assets	17,952		20,068
Total noncurrent regulatory assets	$	520,514	$	526,462
Regulatory liability-current
Overrecovered natural gas costs	$	541	$	25,914
Derivatives at fair value, net	176		274
Total current regulatory liabilities	$	717	$	26,188
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	192,895	$	195,425
Derivatives at fair value, net	—		352
Other noncurrent regulatory liabilities	759		509
Total noncurrent regulatory liabilities	$	193,654	$	196,286

(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.

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

(Thousands)	March 31, 2021		September 30, 2020
Total current regulatory assets	$	116	$	158
Total noncurrent regulatory assets	$	1,514	$	997
Total-noncurrent regulatory liabilities	$	164	$	—

XML

DERIVATIVE INSTRUMENTS (Tables)

6 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Assets and Liabilities

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

			Derivatives at Fair Value
			March 31, 2021						September 30, 2020
(Thousands)	Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	177		$	1		$	78		$	76
Financial commodity contracts	Derivatives - current		589			88			71			282
Energy Services:
Physical commodity contracts	Derivatives - current		3,668			16,415			6,454			20,438
	Derivatives - noncurrent		1,364			20,090			1,264			12,003
Financial commodity contracts	Derivatives - current		12,770			7,166			16,671			12,965
	Derivatives - noncurrent		585			407			2,037			1,346
Foreign currency contracts	Derivatives - current		229			20			36			104
	Derivatives - noncurrent		28			9			48			3
Total fair value of derivatives			$	19,410		$	44,196		$	26,659		$	47,217

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 March 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	5,032		$	(1,757)		$	(200)		$	3,075
Financial commodity contracts		13,355			(7,573)						5,782
Foreign currency contracts		257			(29)						228
Total Energy Services		$	18,644		$	(9,359)		$	(200)		$	9,085
Natural Gas Distribution
Physical commodity contracts		$	177		$	(1)		$	—		$	176
Financial commodity contracts		589			(88)			—			501
Total Natural Gas Distribution		$	766		$	(89)		$	—		$	677
Derivative liabilities:
Energy Services
Physical commodity contracts		$	36,505		$	(1,757)		$	—		$	34,748
Financial commodity contracts		7,573			(7,573)			—			—
Foreign currency contracts		29			(29)			—			—
Total Energy Services		$	44,107		$	(9,359)		$	—		$	34,748
Natural Gas Distribution
Physical commodity contracts		$	1		$	(1)					$	—
Financial commodity contracts		88			(88)						—
Total Natural Gas Distribution		$	89		$	(89)		$	—		$	—
As of September 30, 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222

(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 March 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	5,032		$	(1,757)		$	(200)		$	3,075
Financial commodity contracts		13,355			(7,573)						5,782
Foreign currency contracts		257			(29)						228
Total Energy Services		$	18,644		$	(9,359)		$	(200)		$	9,085
Natural Gas Distribution
Physical commodity contracts		$	177		$	(1)		$	—		$	176
Financial commodity contracts		589			(88)			—			501
Total Natural Gas Distribution		$	766		$	(89)		$	—		$	677
Derivative liabilities:
Energy Services
Physical commodity contracts		$	36,505		$	(1,757)		$	—		$	34,748
Financial commodity contracts		7,573			(7,573)			—			—
Foreign currency contracts		29			(29)			—			—
Total Energy Services		$	44,107		$	(9,359)		$	—		$	34,748
Natural Gas Distribution
Physical commodity contracts		$	1		$	(1)					$	—
Financial commodity contracts		88			(88)						—
Total Natural Gas Distribution		$	89		$	(89)		$	—		$	—
As of September 30, 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222

(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				Six Months Ended
		March 31,				March 31,
Derivatives not designated as hedging instruments:		2021		2020		2021		2020
Energy Services:
Physical commodity contracts	Operating revenues	$	36,419	$	12,096	$	41,671	$	21,932
Physical commodity contracts	Natural gas purchases	2,650		(1,892)		(2,404)		(3,302)
Financial commodity contracts	Natural gas purchases	(27,315)		23,319		20,440		69,412
Foreign currency contracts	Natural gas purchases	27		(475)		227		(360)
Total unrealized and realized gains		$	11,781	$	33,048	$	59,934	$	87,682

Effect of Derivative Instruments Designated as Cash Flow Hedges on OCI

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Natural Gas Distribution:
Physical commodity contracts	$	1,091	$	209	$	1,433	$	1,049
Financial commodity contracts	645		(11,434)		(3,627)		(12,522)
Interest rate contracts	—		(6,692)		—		(6,692)
Total unrealized and realized losses	$	1,736	$	(17,917)	$	(2,194)	$	(18,165)

Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss)

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

(Thousands)	Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives				Location of Gain (Loss) Reclassified from OCI into Income	Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income
	Three Months Ended					Three Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(342)	$	—
	Six Months Ended					Six Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(685)	$	—

Schedule of Outstanding Long (Short) Derivatives

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

		Volume (Bcf)
	Transaction Type	March 31, 2021	September 30, 2020
Natural Gas Distribution	Futures	22.1	23.7
	Physical Commodity	16.6	6.0
Energy Services	Futures	(11.6)	(27.5)
	Swaps	(0.8)	(1.8)
	Physical Commodity	1.5	5.0

Schedule of Broker Margin Accounts by Company

The balances are as follows:

(Thousands)	Balance Sheet Location	March 31, 2021		September 30, 2020
Natural Gas Distribution	Restricted broker margin accounts	$	4,190	$	13,525
Energy Services	Restricted broker margin accounts	$	41,726	$	55,919

Summary of Gross Credit Exposures

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of March 31, 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		$	128,585
Noninvestment grade		9,471
Internally rated investment grade		23,661
Internally rated noninvestment grade		20,118
Total		$	181,835

XML

FAIR VALUE (Tables)

6 Months Ended

Mar. 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)	March 31, 2021		September 30, 2020
Carrying value (1) (2) (3)	$	2,102,845	$	2,102,845
Fair market value	$	2,259,855	$	2,417,748

(1)Excludes finance leases of $68.2 million and $74.2 million as of March 31, 2021 and September 30, 2020, respectively.

(2)Excludes NJNG's debt issuance costs of $9.4 million and $9.2 million as of March 31, 2021 and September 30, 2020, respectively.

(3)Excludes NJR's debt issuance costs of $3.3 million and $3.4 million as of March 31, 2021 and September 30, 2020, respectively.

Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis

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

	Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs			Significant Unobservable Inputs
(Thousands)	(Level 1)			(Level 2)			(Level 3)			Total
As of March 31, 2021:
Assets:
Physical commodity contracts		$	—		$	5,209		$	—	$	5,209
Financial commodity contracts		13,751			193			—		13,944
Financial commodity contracts - foreign exchange		—			257			—		257
Money market funds		50,368			—			—		50,368
Other		1,818			—			—		1,818
Total assets at fair value		$	65,937		$	5,659		$	—	$	71,596
Liabilities:
Physical commodity contracts		$	—		$	36,506		$	—	$	36,506
Financial commodity contracts		7,661			—			—		7,661
Financial commodity contracts - foreign exchange		—			29			—		29
Total liabilities at fair value		$	7,661		$	36,535		$	—	$	44,196
As of September 30, 2020:
Assets:
Physical commodity contracts		$	—		$	7,796		$	—	$	7,796
Financial commodity contracts		18,279			500			—		18,779
Financial commodity contracts - foreign exchange		—			84			—		84
Money market funds		112,291			—			—		112,291
Other		1,840			—			—		1,840
Total assets at fair value		$	132,410		$	8,380		$	—	$	140,790
Liabilities:
Physical commodity contracts		$	—		$	32,517		$	—	$	32,517
Financial commodity contracts		14,593			—			—		14,593
Financial commodity contracts - foreign exchange		—			107			—		107
Total liabilities at fair value		$	14,593		$	32,624		$	—	$	47,217

XML

INVESTMENTS IN EQUITY INVESTEES (Tables)

6 Months Ended

Mar. 31, 2021

Investments, All Other Investments [Abstract]

Schedule of Equity Method Investments

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

(Thousands)	March 31, 2021		September 30, 2020
Steckman Ridge (1)	$	111,435	$	112,378
PennEast (2)	103,086		95,997
Total	$	214,521	$	208,375

(1)Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2021 and September 30, 2020, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

(2)Includes a deferred tax component related to AFUDC equity of $7.6 million and $4.6 million for March 31, 2021 and September 30, 2020, respectively.

XML

EARNINGS PER SHARE (Tables)

6 Months Ended

Mar. 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				Six Months Ended
	March 31,				March 31,
(Thousands, except per share amounts)	2021		2020		2021		2020
Net income, as reported	$	149,809	$	73,846	$	230,854	$	149,598
Basic earnings per share
Weighted average shares of common stock outstanding-basic	96,248		95,584		96,181		93,747
Basic earnings per common share	$1.56		$0.78		$2.40		$1.60
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	96,248		95,584		96,181		93,747
Equity forward sale agreement (1)	—		—		—		4
Other (2)	370		306		417		322
Weighted average shares of common stock outstanding-diluted	96,618		95,890		96,598		94,073
Diluted earnings per common share (3)	$1.55		$0.77		$2.39		$1.59

(1)See Note 14. Common Stock Equity for details regarding the forward sale agreement.

(2)Consist primarily of unvested stock awards and performance shares.

(3)There were anti-dilutive shares of 24,101 and 30,708 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement during the three months ended March 31, 2021 and 2020. There were anti-dilutive shares of 65,334 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement during the six months ended March 31, 2021. There were no anti-dilutive shares excluded during the six months ended March 31, 2020.

XML

DEBT (Tables)

6 Months Ended

Mar. 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)	March 31, 2021			September 30, 2020			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	425,000		$	425,000		December 2023
Notes outstanding at end of period	$	8,500		$	125,350
Weighted average interest rate at end of period	1.75		%	1.49		%
Amount available at end of period (2)	$	406,206		$	289,356
Bank revolving credit facilities (1)	$	—		$	250,000
Notes outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (2)	$	—		$	250,000
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		December 2023
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2)Letters of credit outstanding total $10.3 million for both March 31, 2021 and September 30, 2020, which reduces 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 for both March 31, 2021 and September 30, 2020, which reduces the amount available by the same amount.

XML

EMPLOYEE BENEFIT PLANS (Tables)

6 Months Ended

Mar. 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				Six Months Ended				Three Months Ended				Six Months Ended
	March 31,				March 31,				March 31,				March 31,
(Thousands)	2021		2020		2021		2020		2021		2020		2021		2020
Service cost	$	2,183	$	2,055	$	4,365	$	4,111	$	1,211	$	1,072	$	2,422	$	2,427
Interest cost	2,278		2,646		4,556		5,293		1,517		1,509		3,035		3,513
Expected return on plan assets	(4,851)		(5,232)		(10,075)		(10,289)		(1,565)		(1,695)		(3,248)		(3,255)
Recognized actuarial loss	2,861		2,466		5,723		5,212		1,978		930		3,955		3,721
Prior service cost (credit) amortization	26		26		51		51		(45)		(50)		(90)		(99)
Net periodic benefit cost	$	2,497	$	1,961	$	4,620	$	4,378	$	3,096	$	1,766	$	6,074	$	6,307

XML

INCOME TAXES (Tables)

6 Months Ended

Mar. 31, 2021

Income Tax Disclosure [Abstract]

Schedule of the Reserve for Uncertain Tax Benefits

The reserve for uncertain tax benefits is as follows:

(Thousands)	March 31, 2021		September 30, 2020
Balance at October 1,	$	4,930	$	4,930
Settlements	(4,930)		—
Balance at period end	$	—	$	4,930

XML

LEASES (Tables)

6 Months Ended

Mar. 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				Six Months Ended
		March 31,				March 31,
(Thousands)	Income Statement Location	2021		2020		2021		2020
Operating lease cost (1)	Operation and maintenance	$	1,356	1,719		3,445		3,111
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	1,191	$	1,299	$	2,437	$	2,460
Interest on lease liabilities	Interest expense, net of capitalized interest	113		301		334		548
Total finance lease cost		1,304		1,600		2,771		3,008
Short-term lease cost	Operation and maintenance	127		172		254		626
Variable lease cost	Operation and maintenance	549		403		702		1,110
Total lease cost		$	3,336	$	3,894	$	7,172	$	7,855

(1)Net of capitalized costs.

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

	Six Months Ended
	March 31,
(Thousands)	2021		2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	2,932	$	2,856
Operating cash flows for finance leases	$	791	$	704
Financing cash flows for finance leases	$	5,690	$	4,038

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	March 31, 2021		September 30, 2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	144,326	$	131,769
Finance lease assets	Utility plant	61,432		71,085
Total lease assets		$	205,758	$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	4,001	$	6,724
Finance lease liabilities	Current maturities of long-term debt	5,855		10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	111,034		95,030
Finance lease liabilities	Long-term debt	62,334		63,743
Total lease liabilities		$	183,224	$	175,913

XML

COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

6 Months Ended

Mar. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Long-term Purchase Commitment

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

(Thousands)	2021		2022		2023		2024		2025		Thereafter
Energy Services:
Natural gas purchases	$	98,845	$	—	$	—	$	—	$	—	$	—
Storage demand fees	18,712		14,248		6,712		3,318		2,742		277
Pipeline demand fees	60,585		49,224		21,689		18,673		16,245		34,074
Sub-total Energy Services	$	178,142	$	63,472	$	28,401	$	21,991	$	18,987	$	34,351
NJNG:
Natural gas purchases	$	32,320	$	—	$	—	$	—	$	—	$	—
Storage demand fees	37,285		28,593		17,090		11,506		2,207		2,495
Pipeline demand fees	118,672		150,719		136,124		158,600		154,297		1,437,814
Sub-total NJNG	$	188,277	$	179,312	$	153,214	$	170,106	$	156,504	$	1,440,309
Total	$	366,419	$	242,784	$	181,615	$	192,097	$	175,491	$	1,474,660

XML

REPORTING SEGMENT AND OTHER OPERATIONS DATA (Tables)

6 Months Ended

Mar. 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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Operating revenues
Natural Gas Distribution
External customers	$	310,167	$	297,220	$	505,896	$	516,843
Clean Energy Ventures
External customers	6,476		5,995		12,846		12,207
Energy Services
External customers (1)	459,766		313,959		687,115		682,263
Intercompany	2,803		(258)		4,931		1,853
Storage and Transportation
External customers	13,257		10,401		25,704		18,806
Intercompany	669		675		1,326		1,342
Subtotal	793,138		627,992		1,237,818		1,233,314
Home Services and Other
External customers	12,521		12,039		24,931		24,531
Intercompany	252		326		419		741
Eliminations	(3,724)		(743)		(6,676)		(3,936)
Total	$	802,187	$	639,614	$	1,256,492	$	1,254,650
Depreciation and amortization
Natural Gas Distribution	$	19,475	$	18,100	$	38,644	$	34,917
Clean Energy Ventures	4,685		6,603		10,118		12,919
Energy Services (2)	13		27		55		56
Storage and Transportation	2,364		2,397		5,004		4,078
Subtotal	26,537		27,127		53,821		51,970
Home Services and Other	227		250		487		496
Eliminations	84		139		(98)		(313)
Total	$	26,848	$	27,516	$	54,210	$	52,153
Interest income (3)
Natural Gas Distribution	$	76	$	136	$	158	$	243
Clean Energy Ventures	240		—		240		—
Energy Services	—		52		—		89
Storage and Transportation	851		2,085		1,545		2,782
Subtotal	1,167		2,273		1,943		3,114
Home Services and Other	127		208		259		699
Eliminations	(237)		(760)		(476)		(1,906)
Total	$	1,057	$	1,721	$	1,726	$	1,907

(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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Interest expense, net of capitalized interest
Natural Gas Distribution	$	9,006	$	7,473	$	17,980	$	15,305
Clean Energy Ventures	5,266		4,835		10,300		9,327
Energy Services	575		937		1,255		2,163
Storage and Transportation	3,578		5,621		7,560		8,443
Subtotal	18,425		18,866		37,095		35,238
Home Services and Other	1,728		565		2,844		837
Eliminations	—		(228)		—		(802)
Total	$	20,153	$	19,203	$	39,939	$	35,273
Income tax provision (benefit)
Natural Gas Distribution	$	15,622	$	19,702	$	23,989	$	28,337
Clean Energy Ventures	(2,714)		(4,134)		(5,800)		(7,968)
Energy Services	23,128		(2,449)		35,250		8,303
Storage and Transportation	873		1,105		1,519		1,807
Subtotal	36,909		14,224		54,958		30,479
Home Services and Other	(59)		1,956		59		2,175
Eliminations	2,207		104		1,481		101
Total	$	39,057	$	16,284	$	56,498	$	32,755
Equity in earnings of affiliates
Storage and Transportation	$	3,386	$	3,921	$	6,579	$	7,585
Eliminations	(582)		(332)		(1,100)		(607)
Total	$	2,804	$	3,589	$	5,479	$	6,978
Net financial earnings (loss)
Natural Gas Distribution	$	80,541	$	86,336	$	130,008	$	130,192
Clean Energy Ventures	(8,872)		(8,829)		(19,146)		(17,008)
Energy Services	96,528		2,487		98,028		(2,635)
Storage and Transportation	4,711		4,258		8,219		7,262
Subtotal	172,908		84,252		217,109		117,811
Home Services and Other	747		148		685		1,257
Eliminations	(3,051)		(109)		(2,533)		154
Total	$	170,604	$	84,291	$	215,261	$	119,222
Capital expenditures
Natural Gas Distribution	$	97,239	$	72,042	$	176,485	$	149,839
Clean Energy Ventures	18,549		24,087		40,884		69,786
Storage and Transportation	20,094		5,148		27,707		7,709
Subtotal	135,882		101,277		245,076		227,334
Home Services and Other	125		(111)		811		15
Total	$	136,007	$	101,166	$	245,887	$	227,349
Investments in equity investees
Storage and Transportation	$	196	$	757	$	482	$	1,266
Total	$	196	$	757	$	482	$	1,266

Reconciliation of Consolidated NFE to Consolidated Net Income

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

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Net financial earnings	$	170,604	$	84,291	$	215,261	$	119,222
Less:
Unrealized gain on derivative instruments and related transactions	29,255		(3,773)		(8,235)		(45,539)
Tax effect	(6,954)		897		1,958		10,828
Effects of economic hedging related to natural gas inventory	(7,209)		14,622		(14,741)		5,735
Tax effect	1,713		(3,475)		3,503		(1,363)
NFE tax adjustment	3,990		2,174		1,922		(37)
Net income	$	149,809	$	73,846	$	230,854	$	149,598

Reconciliation of Assets from Segment to Consolidated

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

(Thousands)	March 31, 2021		September 30, 2020
Assets at end of period:
Natural Gas Distribution	$	3,593,630	$	3,531,477
Clean Energy Ventures	848,290		814,277
Energy Services	224,069		244,836
Storage and Transportation	874,976		844,799
Subtotal	5,540,965		5,435,389
Home Services and Other	136,531		138,375
Intercompany assets (1)	(252,362)		(257,287)
Total	$	5,425,134	$	5,316,477

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

XML

RELATED PARTY TRANSACTIONS (Tables)

6 Months Ended

Mar. 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				Six Months Ended
	March 31,				March 31,
(Thousands)	2021		2020		2021		2020
Natural Gas Distribution	$	1,505	$	1,477	$	3,073	$	2,971
Energy Services	226		29		391		59
Total	$	1,731	$	1,506	$	3,464	$	3,030

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

(Thousands)	March 31, 2021		September 30, 2020
Natural Gas Distribution	$	775	$	775
Energy Services	78		16
Total	$	853	$	791

XML

ACQUISITIONS AND DISPOSITIONS (Tables)

6 Months Ended

Mar. 31, 2021

Business Combinations [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

The following table summarizes the consideration transferred and purchase price allocation based upon the relative fair value of the assets acquired and liabilities to be assumed:

(Thousands)	Estimated Fair Value
Purchase price	$	166,000
Net working capital adjustment	(449)
Transaction costs	9,456
Total costs capitalized	$	175,007
Identifiable assets acquired
Property, plant and equipment	$	174,438
Other	1,018
Net working capital	(449)
Net assets acquired	$	175,007

The following table summarizes the consideration transferred and purchase price allocation based upon the relative fair value of the assets acquired and liabilities to be assumed:

(Thousands)	Estimated Fair Value
Purchase price	$	367,500
Net working capital adjustment	4,111
Transaction costs	1,664
Total costs capitalized	$	373,275
Identifiable assets acquired
Property, plant and equipment	$	365,715
Base gas	3,445
Other assets, net	4
Net working capital	4,111
Net assets acquired	$	373,275

XML

NATURE OF THE BUSINESS (Details)	6 Months Ended
	Mar. 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	561,500
NJR Retail Holdings Corporation
Nature of Business [Line Items]
Number of principal subsidiaries | subsidiary	2

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020	Sep. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019
Accounting Policies [Abstract]
Cash and cash equivalents	$ 57,654		$ 117,012	$ 25,968		$ 2,676
Restricted cash in other noncurrent assets	1,321		2,411	2,422		1,387
Cash, cash equivalents and restricted cash	$ 58,975	$ 119,423	$ 119,423	$ 28,390	$ 4,063	$ 4,063

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ADDITIONAL INFORMATION (Details) - USD ($)	1 Months Ended		6 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 31, 2020	Sep. 30, 2020
Finite-Lived Intangible Assets [Line Items]
Reserve for expected credit losses			$ 10,607,000	$ 951,000
Loans receivable in other current assets			14,300,000		$ 13,700,000
Loans receivable in other noncurrent assets			33,900,000		$ 35,300,000
Proceeds from sale leaseback transaction			0	4,000,000
Proceeds from sale leaseback transaction - solar	$ 12,100,000		12,124,000	$ 0
Clean Energy Ventures
Finite-Lived Intangible Assets [Line Items]
Reserve for expected credit losses			5,200,000
Natural Gas Distribution
Finite-Lived Intangible Assets [Line Items]
Proceeds from sale leaseback transaction		$ 4,000,000.0	$ 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

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - NATURAL GAS IN STORAGE (Details) $ in Thousands	Mar. 31, 2021 USD ($) Bcf	Sep. 30, 2020 USD ($) Bcf
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 74,853	$ 167,504
Natural Gas in Storage, Bcf | Bcf	22.8	61.52
Natural Gas Distribution
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 40,083	$ 110,037
Natural Gas in Storage, Bcf | Bcf	9.4	27.2
Energy Services
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 34,439	$ 57,352
Natural Gas in Storage, Bcf | Bcf	13.3	34.3
Storage and Transportation
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 331	$ 115
Natural Gas in Storage, Bcf | Bcf	0.1	0.02

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SOFTWARE COSTS (Details) - USD ($)	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020	Sep. 30, 2020
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Capitalized software costs	$ 5,485,000		$ 5,485,000		$ 4,707,000
Software amortization	111,000	$ 0	188,000	$ 0
Operation and maintenance
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	2,847,000	1,109,000	4,770,000	2,596,000
Depreciation and amortization
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	270,000	$ 0	523,000	$ 0
Utility plant, at cost
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	14,011,000		14,011,000		13,452,000
Nonutility plant and equipment, at cost
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	334,000		334,000		316,000
Accumulated depreciation and amortization, utility plant
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Accumulated depreciation and amortization	(790,000)		(790,000)		(279,000)
Accumulated depreciation and amortization, nonutility plant and equipment
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Accumulated depreciation and amortization	$ (17,000)		$ (17,000)		$ (5,000)

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	$ 1,698,214	$ 1,608,092	$ 1,643,896	$ 1,345,615
Balance as of end of period	1,821,833	1,654,737	1,821,833	1,654,737
Cash Flow Hedges
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(10,166)	0	(10,397)	0
Other comprehensive (loss) income, before reclassifications, net of tax		(9,711)		(9,711)
Amounts reclassified from accumulated other comprehensive income, net of tax	263	0	494	0
Net current-period, other comprehensive income, net of tax		(9,711)		(9,711)
Balance as of end of period	(9,903)	(9,711)	(9,903)	(9,711)
Tax on amounts reclassified from accumulated other comprehensive income	(79)	0	(191)	0
Other comprehensive income (loss), tax		2,781		2,781
Other comprehensive income (loss) before reclassifications, tax		2,781		2,781
Postemployment Benefit Obligation
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(33,106)	(31,028)	(33,918)	(31,787)
Other comprehensive (loss) income, before reclassifications, net of tax		5,378		5,378
Amounts reclassified from accumulated other comprehensive income, net of tax	813	722	1,625	1,481
Net current-period, other comprehensive income, net of tax		6,100		6,859
Balance as of end of period	(32,293)	(24,928)	(32,293)	(24,928)
Tax on amounts reclassified from accumulated other comprehensive income	(244)	(72)	(489)	(289)
Other comprehensive income (loss), tax		(1,753)		(1,970)
Other comprehensive income (loss) before reclassifications, tax		(1,681)		(1,681)
Total
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(43,272)	(31,028)	(44,315)	(31,787)
Other comprehensive (loss) income, before reclassifications, net of tax		(4,333)		(4,333)
Amounts reclassified from accumulated other comprehensive income, net of tax	1,076	722	2,119	1,481
Net current-period, other comprehensive income, net of tax		(3,611)		(2,852)
Balance as of end of period	(42,196)	(34,639)	(42,196)	(34,639)
Tax on amounts reclassified from accumulated other comprehensive income	$ (323)	(72)	$ (680)	(289)
Other comprehensive income (loss), tax		1,028		811
Other comprehensive income (loss) before reclassifications, tax		$ 1,100		$ 1,100

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 740 ON UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended				6 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 31, 2020
OPERATING EXPENSES
Depreciation and amortization	$ 26,848		$ 27,516		$ 54,210	$ 52,153
Total operating expenses	600,979		541,131		943,804	1,051,549
Operating income	201,208		98,483		312,688	203,101
Income before income taxes and equity in earnings of affiliates	186,062		86,541		281,873	175,375
Income tax provision (benefit)	39,057		16,284		56,498	32,755
Net income	$ 149,809	$ 81,045	$ 73,846	$ 75,752	$ 230,854	$ 149,598
EARNINGS PER COMMON SHARE
Basic (usd per share)	$ 1.56		$ 0.78		$ 2.40	$ 1.60
Diluted (usd per share)	$ 1.55		$ 0.77		$ 2.39	$ 1.59
As Previously Reported
OPERATING EXPENSES
Depreciation and amortization			$ 30,784			$ 58,542
Total operating expenses			544,399			1,057,938
Operating income			95,215			196,712
Income before income taxes and equity in earnings of affiliates			83,273			168,986
Income tax provision (benefit)			(1,643)			(1,902)
Net income			$ 88,505	89,361		$ 177,866
EARNINGS PER COMMON SHARE
Basic (usd per share)			$ 0.93			$ 1.90
Diluted (usd per share)			$ 0.92			$ 1.89
Effect of Change
OPERATING EXPENSES
Depreciation and amortization			$ (3,268)			$ (6,389)
Total operating expenses			(3,268)			(6,389)
Operating income			3,268			6,389
Income before income taxes and equity in earnings of affiliates			3,268			6,389
Income tax provision (benefit)			17,927			34,657
Net income			$ (14,659)	$ (13,609)		$ (28,268)
EARNINGS PER COMMON SHARE
Basic (usd per share)			$ (0.15)			$ (0.30)
Diluted (usd per share)			$ (0.15)			$ (0.30)

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 470 ON THE UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020	Sep. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019
Assets
Nonutility plant and equipment, at cost	$ 1,121,155		$ 1,108,512
Accumulated depreciation and amortization, nonutility plant and equipment	(156,063)		(140,562)
Property, plant and equipment, net	3,915,156		3,722,769
Other noncurrent assets	79,952		85,657
Total noncurrent assets	974,750		971,376
Total assets	5,425,134		5,316,477
CAPITALIZATION
Retained earnings	1,114,382		947,501
Common stock equity	1,821,833	$ 1,698,214	1,643,896	$ 1,654,737	$ 1,608,092	$ 1,345,615
Total capitalization	4,087,035		3,903,362
Liabilities
Deferred income taxes	166,238		138,081
Total noncurrent liabilities	922,033		879,393
Total capitalization and liabilities	$ 5,425,134		5,316,477
As Previously Reported
Assets
Nonutility plant and equipment, at cost			1,430,723
Accumulated depreciation and amortization, nonutility plant and equipment			(202,507)
Property, plant and equipment, net			3,983,035
Other noncurrent assets			78,716
Total noncurrent assets			964,435
Total assets			5,569,802
CAPITALIZATION
Retained earnings			1,148,297
Common stock equity			1,844,692	1,889,107	1,827,803	1,551,717
Total capitalization			4,104,158
Liabilities
Deferred income taxes			190,610
Total noncurrent liabilities			931,922
Total capitalization and liabilities			5,569,802
Effect of Change
Assets
Nonutility plant and equipment, at cost			(322,211)
Accumulated depreciation and amortization, nonutility plant and equipment			61,945
Property, plant and equipment, net			(260,266)
Other noncurrent assets			6,941
Total noncurrent assets			6,941
Total assets			(253,325)
CAPITALIZATION
Retained earnings			(200,796)
Common stock equity			(200,796)	$ (234,370)	$ (219,711)	$ (206,102)
Total capitalization			(200,796)
Liabilities
Deferred income taxes			(52,529)
Total noncurrent liabilities			(52,529)
Total capitalization and liabilities			$ (253,325)

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 740 ON THE UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation and amortization	$ 26,848	$ 27,516	$ 54,210	$ 52,153
Deferred income taxes			$ 20,909	34,975
As Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation and amortization		30,784		58,542
Deferred income taxes				318
Effect of Change
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation and amortization		$ (3,268)		(6,389)
Deferred income taxes				$ 34,657

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 740 ON THE UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 31, 2020
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period	$ 1,698,214	$ 1,643,896	$ 1,608,092	$ 1,345,615	$ 1,643,896	$ 1,345,615
Net income	149,809	81,045	73,846	75,752	230,854	149,598
Balance as of end of period	1,821,833	1,698,214	1,654,737	1,608,092	1,821,833	1,654,737
Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period	996,580	947,501	915,764	869,858	947,501	869,858
Net income	149,809	81,045	73,846	75,752
Balance as of end of period	$ 1,114,382	996,580	959,722	915,764	1,114,382	959,722
As Previously Reported
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period		1,844,692	1,827,803	1,551,717	1,844,692	1,551,717
Net income			88,505	89,361		177,866
Balance as of end of period			1,889,107	1,827,803		1,889,107
As Previously Reported | Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period			1,135,475	1,075,960		1,075,960
Net income			88,505	89,361
Balance as of end of period			1,194,092	1,135,475		1,194,092
Effect of Change
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period		$ (200,796)	(219,711)	(206,102)	$ (200,796)	(206,102)
Net income			(14,659)	(13,609)		(28,268)
Balance as of end of period			(234,370)	(219,711)		(234,370)
Effect of Change | Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance as of beginning of period			(219,711)	(206,102)		(206,102)
Net income			(14,659)	(13,609)
Balance as of end of period			$ (234,370)	$ (219,711)		$ (234,370)

XML

REVENUE - DISAGGREGATED REVENUE - PRODUCT (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 339,376	$ 303,400	$ 565,103	$ 555,530
Alternative revenue programs	(6,664)	22,073	(5,096)	20,130
Derivative instruments	472,278	313,883	24,740	680,843
Revenues out of scope	462,811	336,214	691,389	699,120
Total operating revenues	802,187	639,614	1,256,492	1,254,650
Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	296,888	266,868	486,252	486,762
Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	24,937	20,710	44,469	37,103
Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,314	8,073	16,573	16,111
Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,459	4,292	8,777	9,161
Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	817		1,507
Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,882	4,458	9,270	8,476
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues	793,138	627,992	1,237,818	1,233,314
Operating Segments | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	296,888	266,868	486,252	486,762
Alternative revenue programs	(6,664)	22,073	(5,096)	20,130
Derivative instruments	19,943	8,279	24,740	9,951
Revenues out of scope	13,279	30,352	19,644	30,081
Total operating revenues	310,167	297,220	505,896	516,843
Operating Segments | Natural Gas Distribution | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	296,888	266,868	486,252	486,762
Operating Segments | Natural Gas Distribution | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Natural Gas Distribution | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Natural Gas Distribution | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	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	0	0
Operating Segments | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,699	4,458	10,777	8,476
Alternative revenue programs	0	0	0	0
Derivative instruments	777	1,537	2,069	3,731
Revenues out of scope	777	1,537	2,069	3,731
Total operating revenues	6,476	5,995	12,846	12,207
Operating Segments | Clean Energy Ventures | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Clean Energy Ventures | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Clean Energy Ventures | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Clean Energy Ventures | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Clean Energy Ventures | Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	817		1,507
Operating Segments | Clean Energy Ventures | Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,882	4,458	9,270	8,476
Operating Segments | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,011	9,634	17,439	16,955
Alternative revenue programs	0	0	0	0
Derivative instruments	451,558	304,067	674,607	667,161
Revenues out of scope	448,755	304,325	669,676	665,308
Total operating revenues	459,766	313,959	687,115	682,263
Operating Segments | Energy Services | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Energy Services | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,011	9,634	17,439	16,955
Operating Segments | Energy Services | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Energy Services | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	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	0	0
Operating Segments | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,257	10,401	25,704	18,806
Alternative revenue programs	0	0	0	0
Derivative instruments	0	0	0	0
Revenues out of scope	0	0	0	0
Total operating revenues	13,257	10,401	25,704	18,806
Operating Segments | Storage and Transportation | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Storage and Transportation | Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,926	11,076	27,030	20,148
Operating Segments | Storage and Transportation | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Storage and Transportation | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	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	0	0
Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues out of scope	0	0	0	0
Total operating revenues	12,521	12,039	24,931	24,531
Home Services and Other | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,521	12,039	24,931	24,531
Alternative revenue programs	0	0	0	0
Derivative instruments	0	0	0	0
Revenues out of scope	0	0	0	0
Total operating revenues	12,521	12,039	24,931	24,531
Home Services and Other | Home Services and Other | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	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	0	0
Home Services and Other | Home Services and Other | Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,314	8,073	16,573	16,111
Home Services and Other | Home Services and Other | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,459	4,292	8,777	9,161
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	0	0
Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(921)	(1,001)	(1,745)	(2,083)
Revenues out of scope	(2,803)	258	(4,931)	(1,853)
Eliminations | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Revenues out of scope	0	0	0	0
Eliminations | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Revenues out of scope	0	0	0	0
Eliminations | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Revenues out of scope	(2,803)	258	(4,931)	(1,853)
Eliminations | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(669)	(675)	(1,326)	(1,342)
Revenues out of scope	0	0	0	0
Eliminations | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(252)	(326)	(419)	(741)
Revenues out of scope	$ 0	$ 0	$ 0	$ 0

XML

REVENUE - DISAGGREGATED REVENUE - TYPE (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 339,376	$ 303,400	$ 565,103	$ 555,530
Revenues out of scope	462,811	336,214	691,389	699,120
Total operating revenues	802,187	639,614	1,256,492	1,254,650
Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	240,100	214,076	392,250	382,037
Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	70,386	63,867	121,052	126,786
Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	28,190	24,123	49,294	43,712
Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	700	1,334	2,507	2,995
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues	793,138	627,992	1,237,818	1,233,314
Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues out of scope	0	0	0	0
Total operating revenues	12,521	12,039	24,931	24,531
Home Services and Other | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12,234	11,831	24,438	24,110
Home Services and Other | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	287	208	493	421
Home Services and Other | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Home Services and Other | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Natural Gas Distribution | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	296,888	266,868	486,252	486,762
Revenues out of scope	13,279	30,352	19,644	30,081
Total operating revenues	310,167	297,220	505,896	516,843
Natural Gas Distribution | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	225,174	199,776	362,398	352,998
Natural Gas Distribution | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	42,824	41,635	72,053	87,057
Natural Gas Distribution | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	28,190	24,123	49,294	43,712
Natural Gas Distribution | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	700	1,334	2,507	2,995
Clean Energy Ventures | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,699	4,458	10,777	8,476
Revenues out of scope	777	1,537	2,069	3,731
Total operating revenues	6,476	5,995	12,846	12,207
Clean Energy Ventures | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,692	2,469	5,414	4,929
Clean Energy Ventures | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,007	1,989	5,363	3,547
Clean Energy Ventures | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Clean Energy Ventures | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Energy Services | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,011	9,634	17,439	16,955
Revenues out of scope	448,755	304,325	669,676	665,308
Total operating revenues	459,766	313,959	687,115	682,263
Energy Services | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Energy Services | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,011	9,634	17,439	16,955
Energy Services | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Energy Services | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Storage and Transportation | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,257	10,401	25,704	18,806
Revenues out of scope	0	0	0	0
Total operating revenues	13,257	10,401	25,704	18,806
Storage and Transportation | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Storage and Transportation | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,257	10,401	25,704	18,806
Storage and Transportation | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Storage and Transportation | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 0	$ 0	$ 0	$ 0

XML

REVENUE - TIMING OF REVENUE RECOGNITION (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2021 USD ($)
Timing of Revenue Recognition [Roll Forward]
Billed, beginning	$ 134,173
Unbilled, beginning	9,226
Customers' credit, beginning	25,934
Increase (decrease) for accounts receivable, billed	103,056
Increase (decrease) for unbilled revenue	32,715
Increase (decrease) for customers' credits	(5,171)
Billed, end	237,229
Unbilled, end	41,941
Customers' credit, end	$ 20,763

XML

REVENUE - TIMING OF REVENUE RECOGNITION - BALANCE SHEET (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Customer accounts receivable
Billed	$ 237,229	$ 134,173
Unbilled revenues	41,941	9,226
Customers' credit balances and deposits	(20,763)	$ (25,934)
Customers accounts receivables & Customers' credit balances and deposits	258,407
Operating Segments | Natural Gas Distribution
Customer accounts receivable
Billed	119,845
Unbilled revenues	39,652
Customers' credit balances and deposits	(20,763)
Customers accounts receivables & Customers' credit balances and deposits	138,734
Operating Segments | Clean Energy Ventures
Customer accounts receivable
Billed	4,794
Unbilled revenues	2,289
Customers' credit balances and deposits	0
Customers accounts receivables & Customers' credit balances and deposits	7,083
Operating Segments | Energy Services
Customer accounts receivable
Billed	107,353
Unbilled revenues	0
Customers' credit balances and deposits	0
Customers accounts receivables & Customers' credit balances and deposits	107,353
Operating Segments | Storage and Transportation
Customer accounts receivable
Billed	3,437
Unbilled revenues	0
Customers' credit balances and deposits	0
Customers accounts receivables & Customers' credit balances and deposits	3,437
Home Services and Other
Customer accounts receivable
Billed	1,800
Unbilled revenues	0
Customers' credit balances and deposits	0
Customers accounts receivables & Customers' credit balances and deposits	$ 1,800

XML

REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	$ 23,527	$ 36,530
Overrecovered natural gas costs	717	26,188
Regulatory liabilities-noncurrent	193,817	196,450
Adelphia
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	116	158
Regulatory assets-noncurrent	1,514	997
Regulatory liabilities-noncurrent	164	0
NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	23,411	36,372
Regulatory assets-noncurrent	520,514	526,462
Overrecovered natural gas costs	717	26,188
Regulatory liabilities-noncurrent	193,654	196,286
Total current regulatory liabilities | NJNG
Regulatory Assets And Liabilities [Line Items]
Overrecovered natural gas costs	541	25,914
Derivatives at fair value, net | NJNG
Regulatory Assets And Liabilities [Line Items]
Overrecovered natural gas costs	176	274
Regulatory liabilities-noncurrent	0	352
Tax Act impact | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	192,895	195,425
Other noncurrent regulatory liabilities | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	759	509
New Jersey Clean Energy Program | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	6,147	15,570
Conservation Incentive Program | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	14,025	19,120
Derivatives at fair value, net | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	1,509	0
Regulatory assets-noncurrent	4	1
Other current regulatory assets | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	1,730	1,682
Regulatory assets-noncurrent	17,952	20,068
Expended, net of recoveries | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	37,476	36,516
Liability for future expenditures | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	143,495	150,590
Deferred income taxes | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	31,603	28,241
SAVEGREEN | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	21,842	21,281
Postemployment and other benefit costs | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	180,360	188,170
Deferred storm damage costs | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	5,429	6,515
Cost of removal | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	$ 82,353	$ 75,080

XML

REGULATION - REGULATORY FILINGS (Details) - USD ($) $ in Thousands						4 Months Ended
	Apr. 07, 2021	Mar. 31, 2021	Mar. 30, 2021	Mar. 03, 2021	Oct. 28, 2020	Mar. 31, 2021
BPU | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount			$ 165,700
BPU | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Approved rate increase (decrease), amount					$ 150,000
IIP approved term					5 years
BGSS | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount				$ (20,400)
BGSS | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Interim rate increase (decrease), amount						$ (20,600)
Interim rate increase (decrease), amount, net of tax						$ (19,300)
SAVEGREEN
Schedule of Regulatory Filings [Line Items]
Public utility extension term				3 years
Capital investments approved by the BPU				$ 126,100
Financing options				109,400
Operations and maintenance expense				23,400
BGSS Balancing | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount				(3,800)
Conservation Incentive Program | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount				$ 16,500
NJ RISE And SAFE II Capital Investments | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount		$ 311
Capital investment costs		$ 3,400
RAC | Subsequent Event
Schedule of Regulatory Filings [Line Items]
Approved rate increase (decrease), amount	$ 1,300
NJCEP | Subsequent Event
Schedule of Regulatory Filings [Line Items]
Approved rate increase (decrease), amount	$ 6,000

XML

DERIVATIVE INSTRUMENTS - ADDITIONAL INFORMATION (Details) certificate in Thousands, $ in Thousands	1 Months Ended	3 Months Ended	6 Months Ended
	Sep. 30, 2020 USD ($) certificate	Mar. 31, 2021 USD ($) certificate	Mar. 31, 2021 USD ($) certificate
Natural Gas Distribution
Derivative [Line Items]
Amortization of deferred hedge gains		$ 54	$ 114
Treasury Lock | Natural Gas Distribution
Derivative [Line Items]
Amount of (losses) gains recognized in income on derivatives	$ (6,600)
Foreign currency contracts
Derivative [Line Items]
Notional amount	$ 5,100	$ 42	$ 42
Physical commodity contracts | Energy Services
Derivative [Line Items]
Number of SRECs (in certificates) | certificate	960	1,588	1,588
Debt Issued In September 2020 | Natural Gas Distribution
Derivative [Line Items]
Debt issued	$ 75,000
Home Services and Other
Derivative [Line Items]
Amortization of deferred hedge gains		$ 263	$ 494
Home Services and Other | Treasury Lock
Derivative [Line Items]
Amount of (losses) gains recognized in income on derivatives	(13,700)
Home Services and Other | Debt Issued In September 2020
Derivative [Line Items]
Debt issued	200,000
Home Services and Other | Debt Issued In July 2020
Derivative [Line Items]
Debt issued	$ 260,000

XML

DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Fair Value
Derivative assets, current	$ 17,433	$ 23,310
Derivative liabilities, current	23,690	33,865
Derivative assets, noncurrent	1,977	3,349
Derivative liabilities, noncurrent	20,506	13,352
Not Designated as Hedging Instrument
Fair Value
Derivative assets	19,410	26,659
Derivative liabilities	44,196	47,217
Natural Gas Distribution | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	177	78
Derivative liabilities, current	1	76
Natural Gas Distribution | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	589	71
Derivative liabilities, current	88	282
Energy Services | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	3,668	6,454
Derivative liabilities, current	16,415	20,438
Derivative assets, noncurrent	1,364	1,264
Derivative liabilities, noncurrent	20,090	12,003
Energy Services | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	12,770	16,671
Derivative liabilities, current	7,166	12,965
Derivative assets, noncurrent	585	2,037
Derivative liabilities, noncurrent	407	1,346
Energy Services | Not Designated as Hedging Instrument | Foreign currency contracts
Fair Value
Derivative assets, current	229	36
Derivative liabilities, current	20	104
Derivative assets, noncurrent	28	48
Derivative liabilities, noncurrent	$ 9	$ 3

XML

DERIVATIVE INSTRUMENTS - OFFSETTING OF ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Energy Services
Derivative assets:
Amounts Presented in Balance Sheets	$ 18,644	$ 26,510
Offsetting Derivative Instruments	(9,359)	(17,982)
Financial Collateral Received/Pledged	(200)	(200)
Net Amounts	9,085	8,328
Derivative liabilities:
Amounts Presented in Balance Sheets	44,107	46,859
Offsetting Derivative Instruments	(9,359)	(17,982)
Financial Collateral Received/Pledged	0	0
Net Amounts	34,748	28,877
Energy Services | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	5,032	7,718
Offsetting Derivative Instruments	(1,757)	(3,587)
Financial Collateral Received/Pledged	(200)	(200)
Net Amounts	3,075	3,931
Derivative liabilities:
Amounts Presented in Balance Sheets	36,505	32,441
Offsetting Derivative Instruments	(1,757)	(3,587)
Financial Collateral Received/Pledged	0	0
Net Amounts	34,748	28,854
Energy Services | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	13,355	18,708
Offsetting Derivative Instruments	(7,573)	(14,311)
Financial Collateral Received/Pledged		0
Net Amounts	5,782	4,397
Derivative liabilities:
Amounts Presented in Balance Sheets	7,573	14,311
Offsetting Derivative Instruments	(7,573)	(14,311)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	0
Energy Services | Foreign currency contracts
Derivative assets:
Amounts Presented in Balance Sheets	257	84
Offsetting Derivative Instruments	(29)	(84)
Financial Collateral Received/Pledged		0
Net Amounts	228	0
Derivative liabilities:
Amounts Presented in Balance Sheets	29	107
Offsetting Derivative Instruments	(29)	(84)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	23
Natural Gas Distribution
Derivative assets:
Amounts Presented in Balance Sheets	766	149
Offsetting Derivative Instruments	(89)	(136)
Financial Collateral Received/Pledged	0	0
Net Amounts	677	13
Derivative liabilities:
Amounts Presented in Balance Sheets	89	358
Offsetting Derivative Instruments	(89)	(136)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	222
Natural Gas Distribution | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	177	78
Offsetting Derivative Instruments	(1)	(65)
Financial Collateral Received/Pledged	0	0
Net Amounts	176	13
Derivative liabilities:
Amounts Presented in Balance Sheets	1	76
Offsetting Derivative Instruments	(1)	(65)
Financial Collateral Received/Pledged		0
Net Amounts	0	11
Natural Gas Distribution | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	589	71
Offsetting Derivative Instruments	(88)	(71)
Financial Collateral Received/Pledged	0	0
Net Amounts	501	0
Derivative liabilities:
Amounts Presented in Balance Sheets	88	282
Offsetting Derivative Instruments	(88)	(71)
Financial Collateral Received/Pledged		0
Net Amounts	$ 0	$ 211

XML

DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) - Not Designated as Hedging Instrument - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	$ 11,781	$ 33,048	$ 59,934	$ 87,682
Energy Services | Physical commodity contracts | Operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	36,419	12,096	41,671	21,932
Energy Services | Physical commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	2,650	(1,892)	(2,404)	(3,302)
Energy Services | Financial commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	(27,315)	23,319	20,440	69,412
Energy Services | Foreign currency contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	27	(475)	227	(360)
Natural Gas Distribution
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	1,736	(17,917)	(2,194)	(18,165)
Natural Gas Distribution | Physical commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	1,091	209	1,433	1,049
Natural Gas Distribution | Financial commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	645	(11,434)	(3,627)	(12,522)
Natural Gas Distribution | Interest rate contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	$ 0	$ (6,692)	$ 0	$ (6,692)

XML

DERIVATIVE INSTRUMENTS - EFFECT OF DERIVATIVE INSTRUMENTS DESIGNATED AS CASH FLOW HEDGES ON OCI (Details) - Treasury Lock - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Derivative [Line Items]
Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives	$ 0	$ (12,492)	$ 0	$ (12,492)
Interest expense
Derivative [Line Items]
Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income	$ (342)	$ 0	$ (685)	$ 0

XML

DERIVATIVE INSTRUMENTS - VOLUME (Details) - Bcf	Mar. 31, 2021	Sep. 30, 2020
Natural Gas Distribution | Long | Futures
Derivative [Line Items]
Notional amount	22.1	23.7
Natural Gas Distribution | Long | Physical Commodity
Derivative [Line Items]
Notional amount	16.6	6.0
Energy Services | Long | Physical Commodity
Derivative [Line Items]
Notional amount		5.0
Energy Services | Short | Futures
Derivative [Line Items]
Notional amount	11.6	27.5
Energy Services | Short | Physical Commodity
Derivative [Line Items]
Notional amount	1.5
Energy Services | Short | Swaps
Derivative [Line Items]
Notional amount	0.8	1.8

XML

DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Natural Gas Distribution
Derivative [Line Items]
Broker margin - Current assets	$ 4,190	$ 13,525
Energy Services
Derivative [Line Items]
Broker margin - Current assets	$ 41,726	$ 55,919

XML

DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2021 USD ($)
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 181,835
Investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	128,585
Noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	9,471
Internally rated investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	23,661
Internally rated noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 20,118

XML

FAIR VALUE - DEBT (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Finance leases	$ 68,200	$ 74,200
NJR
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	3,300	3,400
Natural Gas Distribution
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	9,400	9,200
Fair market value | Clean Energy Ventures | Solar Asset Financing
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	155,600	149,200
Level 2 | Carrying Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	2,102,845	2,102,845
Level 2 | Fair market value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 2,259,855	$ 2,417,748

XML

FAIR VALUE - HIERARCHY (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	$ 1,818	$ 1,840
Total assets at fair value	71,596	140,790
Total liabilities at fair value	44,196	47,217
Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	5,209	7,796
Liabilities	36,506	32,517
Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	13,944	18,779
Liabilities	7,661	14,593
Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	257	84
Liabilities	29	107
Quoted Prices in Active Markets for Identical Assets, (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	1,818	1,840
Total assets at fair value	65,937	132,410
Total liabilities at fair value	7,661	14,593
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	13,751	18,279
Liabilities	7,661	14,593
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	5,659	8,380
Total liabilities at fair value	36,535	32,624
Significant Other Observable Inputs (Level 2) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	5,209	7,796
Liabilities	36,506	32,517
Significant Other Observable Inputs (Level 2) | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	193	500
Liabilities	0	0
Significant Other Observable Inputs (Level 2) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	257	84
Liabilities	29	107
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	50,368	112,291
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	50,368	112,291
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

XML

INVESTMENTS IN EQUITY INVESTEES (Details) $ in Thousands		6 Months Ended	12 Months Ended
	Jan. 30, 2020 phase mi	Mar. 31, 2021 USD ($) mi	Sep. 30, 2020 USD ($)
Schedule of Equity Method Investments [Line Items]
Investments in equity investees		$ 214,521	$ 208,375
Deferred tax gross up		$ 7,600	4,600
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		$ 111,435	112,378
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		$ 103,086	$ 95,997
Ownership percentage		20.00%
Construction plan, project area (in miles) | mi	68	120
Number of phases | phase	2

XML

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended				6 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 31, 2020
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income, as reported	$ 149,809	$ 81,045	$ 73,846	$ 75,752	$ 230,854	$ 149,598
Basic earnings per share
Weighted average shares of common stock outstanding-basic (in shares)	96,248,000		95,584,000		96,181,000	93,747,000
Basic earnings per common share (usd per share)	$ 1.56		$ 0.78		$ 2.40	$ 1.60
Diluted earnings per share
Weighted average shares of common stock outstanding-basic (in shares)	96,248,000		95,584,000		96,181,000	93,747,000
Equity forward sale agreement (in shares)	0		0		0	4,000
Other (in shares)	370,000		306,000		417,000	322,000
Weighted average shares of common stock outstanding-diluted (in shares)	96,618,000		95,890,000		96,598,000	94,073,000
Diluted earnings per common share (usd per share)	$ 1.55		$ 0.77		$ 2.39	$ 1.59
Share-based Payment Arrangement
Diluted earnings per share
Anti-dilutive shares excluded from the calculation of diluted earnings per share (in shares)	24,101		30,708		65,334	0

XML

DEBT - CREDIT FACILITIES (Details) - USD ($)	6 Months Ended
	Mar. 31, 2021	Sep. 30, 2020	Apr. 24, 2020	Dec. 13, 2019
NJR | Letter of Credit on Behalf of NJRES
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount	$ 10,300,000	$ 10,300,000
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	0.075%
Revolving Credit Facility | NJNG
Line of Credit Facility [Line Items]
Commitment fee percentage	0.075%
Revolving Credit Facility | NJR
Line of Credit Facility [Line Items]
Bank revolving credit facilities			$ 250,000,000
Revolving Credit Facility | Committed Credit Facilities Due December 2023 | NJR
Line of Credit Facility [Line Items]
Bank revolving credit facilities	$ 425,000,000	425,000,000
Amount outstanding at end of period	$ 8,500,000	$ 125,350,000
Weighted average interest rate at end of period	1.75%	1.49%
Amount available at end of period	$ 406,206,000	$ 289,356,000
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	$ 0	$ 0
Weighted average interest rate at end of period	0.00%	0.00%
Amount available at end of period	$ 249,269,000	$ 249,269,000
Revolving Credit Facility | Credit Facilities Due April 2021 | NJR
Line of Credit Facility [Line Items]
Bank revolving credit facilities	0	250,000,000		$ 150,000,000
Amount outstanding at end of period	$ 0	$ 0
Weighted average interest rate at end of period	0.00%	0.00%
Amount available at end of period	$ 0	$ 250,000,000

XML

DEBT - CREDIT FACILITIES NARRATIVE (Details) - USD ($)	Apr. 24, 2020	Mar. 31, 2021	Oct. 24, 2020	Sep. 30, 2020	Dec. 13, 2019
Line of Credit Facility [Line Items]
Short-term debt		$ 8,500,000		$ 125,350,000
NJR | Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, term	364 days
Bank revolving credit facilities, maximum borrowing capacity	$ 250,000,000
NJR | Revolving Credit Facility | LIBOR
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.625%
NJR | Revolving Credit Facility | Credit Facilities Due April 2021
Line of Credit Facility [Line Items]
Bank revolving credit facilities, maximum borrowing capacity		$ 0		$ 250,000,000	$ 150,000,000
Short-term debt			$ 0

XML

DEBT - LONG TERM DEBT (Details) - USD ($)	1 Months Ended		6 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 31, 2020
Debt Instrument [Line Items]
Proceeds from sale leaseback transaction			$ 0	$ 4,000,000
Proceeds from sale leaseback transaction - solar	$ 12,100,000		$ 12,124,000	0
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
NJNG
Debt Instrument [Line Items]
Proceeds from sale leaseback transaction		$ 4,000,000.0	$ 0
Final principal payments for early purchase options			$ 1,200,000	$ 1,200,000

XML

EMPLOYEE BENEFIT PLANS - COMPONENTS OF NET PERIODIC COST (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	$ 2,183	$ 2,055	$ 4,365	$ 4,111
Interest cost	2,278	2,646	4,556	5,293
Expected return on plan assets	(4,851)	(5,232)	(10,075)	(10,289)
Recognized actuarial loss	2,861	2,466	5,723	5,212
Prior service cost (credit) amortization	26	26	51	51
Net periodic benefit cost	2,497	1,961	4,620	4,378
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	1,211	1,072	2,422	2,427
Interest cost	1,517	1,509	3,035	3,513
Expected return on plan assets	(1,565)	(1,695)	(3,248)	(3,255)
Recognized actuarial loss	1,978	930	3,955	3,721
Prior service cost (credit) amortization	(45)	(50)	(90)	(99)
Net periodic benefit cost	$ 3,096	$ 1,766	$ 6,074	$ 6,307

XML

EMPLOYEE BENEFIT PLANS - ADDITIONAL INFORMATION (Details) - USD ($)	6 Months Ended
	Mar. 31, 2021	Mar. 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

XML

INCOME TAXES - RESERVE FOR UNCERTAIN TAX BENEFITS (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Mar. 31, 2021	Sep. 30, 2020
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at October 1,	$ 4,930	$ 4,930
Settlements	(4,930)	0
Balance at period end	$ 0	$ 4,930

XML

INCOME TAXES (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Sep. 30, 2020
Operating Loss Carryforwards [Line Items]
Deferred employer portion of OASDI	$ 5,100		$ 3,100
Forecasted effective tax rate	19.90%	19.40%
Revaluation of deferred tax assets and liabilities	$ (145)	$ 2,700
Actual effective tax rate	19.70%	18.00%
Deferred tax assets, operating loss carryforwards, domestic, refundable and receivables	$ 22,800		22,800
Deferred tax assets, operating loss carryforwards, domestic	24,100
ITC carryforward	$ 193,200		195,200
Effective term	20 years
Valuation allowance	$ 17,600		17,600
Federal
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	134,000		134,000
State
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	$ 442,400		$ 487,700
State | Minimum
Operating Loss Carryforwards [Line Items]
Effective term	7 years
State | Maximum
Operating Loss Carryforwards [Line Items]
Effective term	20 years

XML

LEASES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020	Sep. 30, 2020
Lessee, Lease, Description [Line Items]
ROU asset obtained in exchange for operating lease liability	$ 5.7	$ 12.4	$ 13.3	$ 34.0
ROU asset obtained in exchange for finance lease liability	$ 0.0	$ 45.7	$ 0.0	$ 49.7
Weighted average remaining lease term, operating lease	27 years 7 months 6 days		27 years 7 months 6 days		25 years 6 months
Operating lease, discount rate	3.30%		3.30%		3.20%
Weighted average remaining lease term, finance lease	11 years 10 months 24 days		11 years 10 months 24 days		11 years 6 months
Finance lease, discount rate	2.50%		2.50%		2.50%
Solar Property | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	15 years		15 years
Renewal term	5 years		5 years
Solar Property | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	35 years		35 years
Renewal term	10 years		10 years
Office Building | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	1 year		1 year
Office Building | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	25 years		25 years
Meter License
Lessee, Lease, Description [Line Items]
Term of contract	7 years		7 years
Equipment
Lessee, Lease, Description [Line Items]
Term of contract	5 years		5 years
Storage and Capacity
Lessee, Lease, Description [Line Items]
Term of contract	50 years		50 years

XML

LEASES - LEASE COST (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Leases [Abstract]
Operating lease cost	$ 1,356	$ 1,719	$ 3,445	$ 3,111
Amortization of right-of-use assets	1,191	1,299	2,437	2,460
Interest on lease liabilities	113	301	334	548
Total finance lease cost	1,304	1,600	2,771	3,008
Short-term lease cost	127	172	254	626
Variable lease cost	549	403	702	1,110
Total lease cost	$ 3,336	$ 3,894	$ 7,172	$ 7,855

XML

LEASES - SUPPLEMENTAL CASH FLOW INFORMATION (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Leases [Abstract]
Operating cash flows for operating leases	$ 2,932	$ 2,856
Operating cash flows for finance leases	791	704
Financing cash flows for finance leases	$ 5,690	$ 4,038

XML

LEASES - RIGHT-OF-USE ASSETS AND LEASE LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
NONCURRENT ASSETS
Operating lease assets	$ 144,326	$ 131,769
Finance lease assets	61,432	71,085
Total lease assets	205,758	202,854
Current
Operating lease liabilities	4,001	6,724
Finance lease liabilities	5,855	10,416
Noncurrent
Operating lease liabilities	111,034	95,030
Finance lease liabilities	62,334	63,743
Total lease liabilities	$ 183,224	$ 175,913

XML

COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2021 USD ($)
Long-term Purchase Commitment [Line Items]
Current charges recoverable through BGSS	$ 156,000
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	366,419
2022	242,784
2023	181,615
2024	192,097
2025	175,491
Thereafter	1,474,660
Energy Services
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	178,142
2022	63,472
2023	28,401
2024	21,991
2025	18,987
Thereafter	34,351
Energy Services | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	98,845
2022	0
2023	0
2024	0
2025	0
Thereafter	0
Energy Services | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	18,712
2022	14,248
2023	6,712
2024	3,318
2025	2,742
Thereafter	277
Energy Services | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	60,585
2022	49,224
2023	21,689
2024	18,673
2025	16,245
Thereafter	34,074
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
2021	188,277
2022	179,312
2023	153,214
2024	170,106
2025	156,504
Thereafter	1,440,309
Natural Gas Distribution | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	32,320
2022	0
2023	0
2024	0
2025	0
Thereafter	0
Natural Gas Distribution | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	37,285
2022	28,593
2023	17,090
2024	11,506
2025	2,207
Thereafter	2,495
Natural Gas Distribution | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2021	118,672
2022	150,719
2023	136,124
2024	158,600
2025	154,297
Thereafter	$ 1,437,814
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

XML

COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details) - USD ($) $ in Thousands			6 Months Ended
	Sep. 09, 2020	Sep. 08, 2020	Mar. 31, 2021	Sep. 30, 2020
Site Contingency [Line Items]
Manufactured gas plant remediation			$ 143,490	$ 150,590
Recovery from third party of environmental remediation cost, period			7 years
Regulatory assets			$ 522,027	$ 527,459
Expended, net of recoveries
Site Contingency [Line Items]
Regulatory assets			37,500
RAC
Site Contingency [Line Items]
Approved rate, amount	$ 9,700	$ 8,500
Minimum
Site Contingency [Line Items]
Product liability contingency, loss exposure in excess of accrual, best estimate			143,100
Maximum
Site Contingency [Line Items]
Product liability contingency, loss exposure in excess of accrual, best estimate			$ 181,700

XML

COMMON STOCK EQUITY - NARRATIVE (Details) - USD ($)	1 Months Ended	6 Months Ended
	Dec. 31, 2019	Mar. 31, 2021	Mar. 31, 2020	Mar. 03, 2021
Class of Stock [Line Items]
Number of shares issued in transaction (in shares)	6,545,454
Proceeds from issuance of common stock - public equity offering	$ 212,900,000	$ 0	$ 212,900,000
Forward sale agreement payout		388,000	$ 0
Directly Issued Common Stock
Class of Stock [Line Items]
Number of shares issued in transaction (in shares)	5,333,334
Forward Sales Agreements
Class of Stock [Line Items]
Number of shares issued in transaction (in shares)	1,212,120
Conversion price per share (usd per share)	$ 40.0125
Forward sale agreement payout		$ 387,744
Forward sales agreement, settlement (in shares)		31,607		727,272
Forward sales agreement, settlement, amount		$ 1,400,000

XML

REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020
Segment Reporting Information [Line Items]
Utility	$ 310,167	$ 297,220	$ 505,896	$ 516,843
Nonutility	492,020	342,394	750,596	737,807
Total operating revenues	802,187	639,614	1,256,492	1,254,650
Depreciation and amortization	26,848	27,516	54,210	52,153
Interest income	1,057	1,721	1,726	1,907
Interest expense, net of capitalized interest	20,153	19,203	39,939	35,273
Income tax provision (benefit)	39,057	16,284	56,498	32,755
Equity in earnings of affiliates	2,804	3,589	5,479	6,978
Net financial earnings (loss)	170,604	84,291	215,261	119,222
Capital expenditures	136,007	101,166	245,887	227,349
Investments in equity investees	196	757	482	1,266
Operating Segments
Segment Reporting Information [Line Items]
Total operating revenues	793,138	627,992	1,237,818	1,233,314
Depreciation and amortization	26,537	27,127	53,821	51,970
Interest income	1,167	2,273	1,943	3,114
Interest expense, net of capitalized interest	18,425	18,866	37,095	35,238
Income tax provision (benefit)	36,909	14,224	54,958	30,479
Net financial earnings (loss)	172,908	84,252	217,109	117,811
Capital expenditures	135,882	101,277	245,076	227,334
Operating Segments | Natural Gas Distribution
Segment Reporting Information [Line Items]
Utility	310,167	297,220	505,896	516,843
Total operating revenues	310,167	297,220	505,896	516,843
Depreciation and amortization	19,475	18,100	38,644	34,917
Interest income	76	136	158	243
Interest expense, net of capitalized interest	9,006	7,473	17,980	15,305
Income tax provision (benefit)	15,622	19,702	23,989	28,337
Net financial earnings (loss)	80,541	86,336	130,008	130,192
Capital expenditures	97,239	72,042	176,485	149,839
Operating Segments | Clean Energy Ventures
Segment Reporting Information [Line Items]
Nonutility	6,476	5,995	12,846	12,207
Total operating revenues	6,476	5,995	12,846	12,207
Depreciation and amortization	4,685	6,603	10,118	12,919
Interest income	240	0	240	0
Interest expense, net of capitalized interest	5,266	4,835	10,300	9,327
Income tax provision (benefit)	(2,714)	(4,134)	(5,800)	(7,968)
Net financial earnings (loss)	(8,872)	(8,829)	(19,146)	(17,008)
Capital expenditures	18,549	24,087	40,884	69,786
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Nonutility	459,766	313,959	687,115	682,263
Total operating revenues	459,766	313,959	687,115	682,263
Depreciation and amortization	13	27	55	56
Interest income	0	52	0	89
Interest expense, net of capitalized interest	575	937	1,255	2,163
Income tax provision (benefit)	23,128	(2,449)	35,250	8,303
Net financial earnings (loss)	96,528	2,487	98,028	(2,635)
Operating Segments | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility	13,257	10,401	25,704	18,806
Total operating revenues	13,257	10,401	25,704	18,806
Depreciation and amortization	2,364	2,397	5,004	4,078
Interest income	851	2,085	1,545	2,782
Interest expense, net of capitalized interest	3,578	5,621	7,560	8,443
Income tax provision (benefit)	873	1,105	1,519	1,807
Equity in earnings of affiliates	3,386	3,921	6,579	7,585
Net financial earnings (loss)	4,711	4,258	8,219	7,262
Capital expenditures	20,094	5,148	27,707	7,709
Investments in equity investees	196	757	482	1,266
Intercompany
Segment Reporting Information [Line Items]
Nonutility	252	326	419	741
Intercompany | Energy Services
Segment Reporting Information [Line Items]
Nonutility	2,803	(258)	4,931	1,853
Intercompany | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility	669	675	1,326	1,342
Home Services and Other
Segment Reporting Information [Line Items]
Nonutility	12,521	12,039	24,931	24,531
Total operating revenues	12,521	12,039	24,931	24,531
Depreciation and amortization	227	250	487	496
Interest income	127	208	259	699
Interest expense, net of capitalized interest	1,728	565	2,844	837
Income tax provision (benefit)	(59)	1,956	59	2,175
Net financial earnings (loss)	747	148	685	1,257
Capital expenditures	125	(111)	811	15
Eliminations
Segment Reporting Information [Line Items]
Nonutility	(3,724)	(743)	(6,676)	(3,936)
Depreciation and amortization	84	139	(98)	(313)
Interest income	(237)	(760)	(476)	(1,906)
Interest expense, net of capitalized interest	0	(228)	0	(802)
Income tax provision (benefit)	2,207	104	1,481	101
Equity in earnings of affiliates	(582)	(332)	(1,100)	(607)
Net financial earnings (loss)	$ (3,051)	$ (109)	$ (2,533)	$ 154

XML

REPORTING SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS (LOSS) RECONCILIATION (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 31, 2020
Segment Reporting [Abstract]
Net financial earnings (loss)	$ 170,604		$ 84,291		$ 215,261	$ 119,222
Less:
Unrealized gain on derivative instruments and related transactions	29,255		(3,773)		(8,235)	(45,539)
Tax effect	(6,954)		897		1,958	10,828
Effects of economic hedging related to natural gas inventory	(7,209)		14,622		(14,741)	5,735
Tax effect	1,713		(3,475)		3,503	(1,363)
NFE tax adjustment	3,990		2,174		1,922	(37)
NET INCOME	$ 149,809	$ 81,045	$ 73,846	$ 75,752	$ 230,854	$ 149,598

XML

REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Sep. 30, 2020
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	$ 5,425,134	$ 5,316,477
Operating Segments
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	5,540,965	5,435,389
Operating Segments | Natural Gas Distribution
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	3,593,630	3,531,477
Operating Segments | Clean Energy Ventures
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	848,290	814,277
Operating Segments | Energy Services
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	224,069	244,836
Operating Segments | Storage and Transportation
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	874,976	844,799
Home Services and Other
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	136,531	138,375
Intercompany Assets
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	$ (252,362)	$ (257,287)

XML

RELATED PARTY TRANSACTIONS (Details) $ in Thousands				3 Months Ended		6 Months Ended
	Feb. 19, 2021 DTH	Apr. 01, 2020 USD ($) Bcf	Apr. 01, 2010	Mar. 31, 2021 USD ($)	Mar. 31, 2020 USD ($)	Mar. 31, 2021 USD ($) DTH lease Bcf	Mar. 31, 2020 USD ($)	Sep. 30, 2020 USD ($)
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement				$ 1,731	$ 1,506	$ 3,464	$ 3,030
Demand fees payable				853		$ 853		$ 791
Number of asset management agreements | lease						3
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				1,505	1,477	$ 3,073	2,971
Demand fees payable				775		775		775
NJRES to Steckman Ridge Affiliate
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement				226	$ 29	391	$ 59
Demand fees payable				$ 78		$ 78		$ 16
NJNG to PennEast Affiliate
Related Party Transaction [Line Items]
Natural gas transportation capacity agreement, period						15 years
Transportation capacity under precedent agreement with PennEast (in bcf per day) | DTH						180,000
NJRES to PennEast Affiliate
Related Party Transaction [Line Items]
Natural gas transportation capacity agreement, period						5 years
Transportation capacity under precedent agreement with PennEast (in bcf per day) | DTH						50,000
NJN G to Adelphia Affiliate
Related Party Transaction [Line Items]
Transportation capacity under precedent agreement with PennEast (in bcf per day) | DTH						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
Storage capacity park and loan agreement | DTH	330,000

XML

ACQUISITIONS AND DISPOSITIONS - ADDITIONAL INFORMATION (Details) $ in Thousands, DTH in Millions				1 Months Ended	6 Months Ended
	Jan. 13, 2020 USD ($) mi	Dec. 19, 2019	Oct. 11, 2019 USD ($) DTH	Nov. 30, 2017 USD ($)	Mar. 31, 2021 USD ($)	Mar. 31, 2020 USD ($)
Business Acquisition [Line Items]
Payments for asset acquisitions					$ 0	$ 523,647
Talen's Membership Interests In IEC | Talen Generation, LLC
Business Acquisition [Line Items]
Pipeline length owned | mi	84
Consideration to be transferred	$ 166,000
Cash paid related to acquisition	156,000			$ 10,000
Contingent consideration arrangements, range of outcomes, value, high	$ 23,000
Natural gas transportation capacity agreement, period		10 years
Leaf River Energy Center LLC | NJR Pipeline
Business Acquisition [Line Items]
Percentage of voting interests acquired			100.00%
Payments for asset acquisitions			$ 367,500
Natural gas capacity of acquiree | DTH			32.2
Minimum | Talen's Membership Interests In IEC | Talen Generation, LLC
Business Acquisition [Line Items]
PP&E useful life					5 years
Minimum | Leaf River Energy Center LLC | NJR Pipeline
Business Acquisition [Line Items]
PP&E useful life					5 years
Maximum | Talen's Membership Interests In IEC | Talen Generation, LLC
Business Acquisition [Line Items]
PP&E useful life					30 years
Maximum | Leaf River Energy Center LLC | NJR Pipeline
Business Acquisition [Line Items]
PP&E useful life					50 years

XML

ACQUISITIONS AND DISPOSITIONS - NET ASSETS ACQUIRED (Details) - USD ($) $ in Thousands			6 Months Ended
	Jan. 13, 2020	Oct. 11, 2019	Mar. 31, 2021	Mar. 31, 2020
Business Acquisition [Line Items]
Purchase price			$ 0	$ 523,647
NJR Pipeline | Leaf River Energy Center LLC
Business Acquisition [Line Items]
Purchase price		$ 367,500
Net working capital adjustment		4,111
Transaction costs		1,664
Total costs capitalized		373,275
Identifiable assets acquired
Property, plant and equipment		365,715
Base gas		3,445
Other assets, net		4
Net working capital		4,111
Net assets acquired		$ 373,275
Talen Generation, LLC | Adelphia | Talen's Membership Interests In IEC
Business Acquisition [Line Items]
Purchase price	$ 166,000
Net working capital adjustment	(449)
Transaction costs	9,456
Total costs capitalized	175,007
Identifiable assets acquired
Property, plant and equipment	174,438
Other assets, net	1,018
Net working capital	(449)
Net assets acquired	$ 175,007