New Jersey Resources (NJR) 10-Q 5 May 22 2022 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Mar. 31, 2022	May 02, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
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		96,152,712
Entity Central Index Key	0000356309
Current Fiscal Year End Date	--09-30
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q2
Amendment Flag	false

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
OPERATING REVENUES
Utility	$ 463,474	$ 310,167	$ 737,909	$ 505,896
Nonutility	448,842	492,020	850,249	750,596
Total operating revenues	912,316	802,187	1,588,158	1,256,492
Natural gas purchases:
Gas purchases - Related parties	1,883	1,730	3,729	3,464
Operation and maintenance	85,786	110,265	154,770	183,901
Regulatory rider expenses	30,910	18,413	47,581	29,114
Depreciation and amortization	31,435	26,848	61,828	54,210
Total operating expenses	773,441	600,979	1,292,398	943,804
OPERATING INCOME	138,875	201,208	295,760	312,688
Other income, net	4,127	5,007	8,263	9,124
Interest expense, net of capitalized interest	18,926	20,153	38,403	39,939
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	124,076	186,062	265,620	281,873
Income tax provision	28,810	39,057	59,617	56,498
Equity in earnings of affiliates	769	2,804	1,344	5,479
NET INCOME	$ 96,035	$ 149,809	$ 207,347	$ 230,854
EARNINGS PER COMMON SHARE
Basic (usd per share)	$ 1	$ 1.56	$ 2.16	$ 2.40
Diluted (usd per share)	$ 1	$ 1.55	$ 2.15	$ 2.39
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic (in shares)	96,068	96,248	96,006	96,181
Diluted (in shares)	96,516	96,618	96,480	96,598
Regulated
Natural gas purchases:
Gas purchases - Utility and Nonutility	$ 212,892	$ 113,235	$ 335,161	$ 169,380
Unregulated
Natural gas purchases:
Gas purchases - Utility and Nonutility	$ 410,535	$ 330,488	$ 689,329	$ 503,735

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Net income	$ 96,035	$ 149,809	$ 207,347	$ 230,854
Other comprehensive income, net of tax
Reclassifications of losses to net income on derivatives designated as hedging instruments, net of tax of $(80), $(79), $(159) and $(191), respectively	263	263	527	494
Adjustment to postemployment benefit obligation, net of tax of $(232), $(244), $(465) and $(489), respectively	768	813	1,534	1,625
Other comprehensive income	1,031	1,076	2,061	2,119
Comprehensive income	$ 97,066	$ 150,885	$ 209,408	$ 232,973

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Tax on reclassifications of losses to net income on derivatives	$ (80)	$ (79)	$ (159)	$ (191)
Tax on adjustment to postemployment benefit obligation	$ (232)	$ (244)	$ (465)	$ (489)

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 207,347	$ 230,854
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) on derivative instruments	(40,169)	(8,235)
Depreciation and amortization	61,828	54,210
Amortization of acquired wholesale energy contracts	1,464	3,401
Allowance for equity used during construction	(6,133)	(10,603)
Allowance for doubtful accounts	1,139	10,607
Non cash lease expense	2,559	1,957
Deferred income taxes	16,912	20,909
Equivalent value of ITCs recognized on equipment financing	(727)	0
Manufactured gas plant remediation costs	(14,677)	(6,284)
Equity in earnings, net of distributions received from equity investees	968	(3,543)
Cost of removal - asset retirement obligations	(565)	(512)
Contributions to postemployment benefit plans	(2,324)	(2,018)
Taxes related to stock-based compensation	(166)	(145)
Changes in:
Components of working capital	74,290	6,846
Other noncurrent assets	4,870	18,854
Other noncurrent liabilities	23,836	39,993
Cash flows from operating activities	330,452	356,291
Expenditures for:
Cost of removal	(17,030)	(23,989)
Distribution from equity investees in excess of equity in earnings	478	871
Investments in equity investees, net of return of capital	4,000
Investments in equity investees, net of return of capital		(482)
Cash flows used in investing activities	(296,832)	(245,498)
CASH FLOWS USED IN FINANCING ACTIVITIES
Proceeds from long-term debt	100,000	0
Payments of long-term debt	(10,032)	(11,001)
Proceeds from term loan	150,000	0
Payments of short-term debt, net	(225,090)	(116,850)
Proceeds from sale leaseback transactions - solar	3,300	12,124
Proceeds from sale leaseback transactions	17,300	0
Payments of common stock dividends	(63,725)	(60,894)
Cash settlement of equity forward agreement	0	(388)
Proceeds from issuance of common stock - DRP	7,521	7,540
Tax withholding payments related to net settled stock compensation	(3,737)	(1,772)
Cash flows used in financing activities	(24,463)	(171,241)
Change in cash, cash equivalents and restricted cash	9,157	(60,448)
Cash, cash equivalents and restricted cash at beginning of period	6,043	119,423
Cash, cash equivalents and restricted cash at end of period	15,200	58,975
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	(107,479)	(136,295)
Inventories	125,012	94,233
Recovery of natural gas costs	8,465	(20,279)
Natural gas purchases payable	(25,964)	33,191
Natural gas purchases payable - related parties	(6)	62
Deferred revenue	52,368	(970)
Accounts payable and other	(88,866)	(18,651)
Prepaid expenses	(5,548)	(8,170)
Prepaid and accrued taxes	75,921	59,614
Restricted broker margin accounts	53,708	7,644
Customers' credit balances and deposits	(12,302)	(5,171)
Other current assets	(1,019)	1,638
Total	74,290	6,846
Cash paid for:
Interest (net of amounts capitalized)	42,754	40,465
Income taxes	1,263	3,733
Accrued capital expenditures	53,245	22,840
Utility plant
Expenditures for:
Payments to acquire PP&E	(108,434)	(152,496)
Solar equipment
Expenditures for:
Payments to acquire PP&E	(66,556)	(40,884)
Storage and Transportation and other
Expenditures for:
Payments to acquire PP&E	$ (109,290)	$ (28,518)

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 3,451,038	$ 3,324,611
Construction work in progress	154,978	182,196
Nonutility plant and equipment, at cost	1,154,104	1,124,896
Construction work in progress	511,351	365,346
Total property, plant and equipment	5,271,471	4,997,049
Accumulated depreciation and amortization, utility plant	(637,491)	(611,827)
Accumulated depreciation and amortization, nonutility plant and equipment	(187,141)	(171,709)
Property, plant and equipment, net	4,446,839	4,213,513
CURRENT ASSETS
Cash and cash equivalents	13,906	4,749
Customer accounts receivable
Billed	273,313	212,838
Unbilled revenues	56,270	10,351
Allowance for doubtful accounts	(21,470)	(24,652)
Regulatory assets	33,717	30,118
Natural gas in storage, at average cost	66,300	193,606
Materials and supplies, at average cost	21,855	19,561
Prepaid expenses	13,714	8,166
Prepaid and accrued taxes	4,087	51,211
Derivatives, at fair value	21,586	35,251
Restricted broker margin accounts	49,901	72,840
Other current assets	22,857	20,235
Total current assets	556,036	634,274
NONCURRENT ASSETS
Investments in equity method investees	109,980	114,529
Regulatory assets	513,006	522,099
Operating lease assets	171,207	173,928
Derivatives, at fair value	4,140	3,403
Intangible assets, net	3,445	5,029
Software costs	5,714	5,582
Other noncurrent assets	59,637	49,921
Total noncurrent assets	867,129	874,491
Total assets	5,870,004	5,722,278
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding March 31, 2022 — 96,081,796; September 30, 2021 — 95,709,662	241,593	240,644
Premium on common stock	517,843	502,584
Accumulated other comprehensive loss, net of tax	(32,467)	(34,528)
Treasury stock at cost and other; shares March 31, 2022 — 769,835; September 30, 2021 — 762,313	(15,025)	(12,448)
Retained earnings	1,072,343	934,610
Common stock equity	1,784,287	1,630,862
Long-term debt	2,319,434	2,162,164
Total capitalization	4,103,721	3,793,026
CURRENT LIABILITIES
Current maturities of long-term debt	24,539	72,840
Short-term debt	302,210	377,300
Natural gas purchases payable	142,733	168,697
Natural gas purchases payable to related parties	855	861
Deferred revenue	54,113	1,745
Accounts payable and other	123,190	223,497
Dividends payable	34,830	34,768
Accrued taxes	32,153	3,356
Regulatory liabilities	88,064	28,007
New Jersey Clean Energy Program	6,608	16,308
Derivatives, at fair value	45,216	87,145
Operating lease liabilities	4,878	4,300
Restricted broker margin accounts	2,464	0
Customers' credit balances and deposits	20,284	32,586
Total current liabilities	882,137	1,051,410
NONCURRENT LIABILITIES
Deferred income taxes	181,875	163,530
Deferred investment tax credits	2,849	3,010
Deferred revenue	5,088	847
Derivatives, at fair value	19,632	13,497
Manufactured gas plant remediation	121,605	135,012
Postemployment employee benefit liability	166,887	169,267
Regulatory liabilities	191,450	193,051
Operating lease liabilities	140,036	141,363
Asset retirement obligation	46,753	46,306
Other noncurrent liabilities	7,971	11,959
Total noncurrent liabilities	884,146	877,842
Commitments and contingent liabilities (Note 13)
Total capitalization and liabilities	$ 5,870,004	$ 5,722,278

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Mar. 31, 2022	Sep. 30, 2021
Statement of Financial Position [Abstract]
Common stock, par value (usd per share)	$ 2.50	$ 2.50
Common stock, shares authorized (in shares)	150,000,000	150,000,000
Common stock, shares outstanding (in shares)	96,081,796	95,709,662
Treasury stock at cost and other, shares (in shares)	769,835	762,313

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Unaudited) - USD ($) $ in Thousands		Total	Common Stock	Premium on Common Stock	Accumulated Other Comprehensive (Loss) Income	Treasury Stock and Other	Retained Earnings
Balance as of beginning of period (in shares) at Sep. 30, 2020			95,949,000
Balance as of beginning of period at Sep. 30, 2020		$ 1,643,896	$ 240,243	$ 491,982	$ (44,315)	$ 8,485	$ 947,501
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		81,045					81,045
Other comprehensive income		1,043			1,043
Common stock issued:
Incentive compensation plan (in shares)			50,000
Incentive compensation plan		5,534	$ 124	5,410
Dividend reinvestment plan (in shares)	[1]		140,000
Dividend reinvestment plan	[1]	1,091		(4,502)		5,593
Cash dividend declared		(31,966)					(31,966)
Treasury stock and other		(2,429)				(2,429)
Balance as of end of period (in shares) at Dec. 31, 2020			96,139,000
Balance as of end of period at Dec. 31, 2020		1,698,214	$ 240,367	492,890	(43,272)	11,649	996,580
Balance as of beginning of period (in shares) at Sep. 30, 2020			95,949,000
Balance as of beginning of period at Sep. 30, 2020		1,643,896	$ 240,243	491,982	(44,315)	8,485	947,501
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		230,854
Other comprehensive income		2,119
Balance as of end of period (in shares) at Mar. 31, 2021			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:
Incentive compensation plan (in shares)			28,000
Incentive compensation plan		1,216	$ 72	1,144
Dividend reinvestment plan (in shares)	[1]		103,000
Dividend reinvestment plan	[1]	3,579	$ 58	3,521
Common stock offering		(388)		(388)
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			96,262,000
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 Sep. 30, 2021		95,709,662	95,710,000
Balance as of beginning of period at Sep. 30, 2021		$ 1,630,862	$ 240,644	502,584	(34,528)	(12,448)	934,610
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		111,312					111,312
Other comprehensive income		1,030			1,030
Common stock issued:
Incentive compensation plan (in shares)			147,000
Incentive compensation plan		7,502	$ 367	7,135
Dividend reinvestment plan (in shares)			105,000
Dividend reinvestment plan		3,678	$ 263	3,415
Cash dividend declared		(34,787)					(34,787)
Treasury stock and other		(2,619)				(2,619)
Balance as of end of period (in shares) at Dec. 31, 2021			95,962,000
Balance as of end of period at Dec. 31, 2021		$ 1,716,978	$ 241,274	513,134	(33,498)	(15,067)	1,011,135
Balance as of beginning of period (in shares) at Sep. 30, 2021		95,709,662	95,710,000
Balance as of beginning of period at Sep. 30, 2021		$ 1,630,862	$ 240,644	502,584	(34,528)	(12,448)	934,610
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		207,347
Other comprehensive income		$ 2,061
Balance as of end of period (in shares) at Mar. 31, 2022		96,081,796	96,082,000
Balance as of end of period at Mar. 31, 2022		$ 1,784,287	$ 241,593	517,843	(32,467)	(15,025)	1,072,343
Balance as of beginning of period (in shares) at Dec. 31, 2021			95,962,000
Balance as of beginning of period at Dec. 31, 2021		1,716,978	$ 241,274	513,134	(33,498)	(15,067)	1,011,135
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		96,035					96,035
Other comprehensive income		1,031			1,031
Common stock issued:
Incentive compensation plan (in shares)			36,000
Incentive compensation plan		1,307	$ 91	1,216
Dividend reinvestment plan (in shares)			91,000
Dividend reinvestment plan		3,721	$ 228	3,493
Cash dividend declared		(34,827)					(34,827)
Treasury stock and other (in shares)			(7,000)
Treasury stock and other		$ 42				42
Balance as of end of period (in shares) at Mar. 31, 2022		96,081,796	96,082,000
Balance as of end of period at Mar. 31, 2022		$ 1,784,287	$ 241,593	$ 517,843	$ (32,467)	$ (15,025)	$ 1,072,343
[1]	Shares sold through the DRP issued from treasury stock at average cost, which may differ from the actual market price paid.

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Cash dividend declared per share (usd per share)	$ 0.3625	$ 0.3625	$ 0.3325	$ 0.3325

NATURE OF THE BUSINESS

NATURE OF THE BUSINESS	6 Months Ended
	Mar. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
NATURE OF THE BUSINESS	1. NATURE OF THE BUSINESS The Company provides regulated natural gas distribution services, transmission and storage services and operates certain unregulated businesses primarily through the following: NJNG provides natural gas utility service to approximately 568,100 customers throughout Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex counties in New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment. NJRCEV, the Company's clean energy subsidiary, comprises the Clean Energy Ventures segment and invests in, owns and operates clean energy projects, including commercial and residential solar installations located in New Jersey, Connecticut, Rhode Island and New York. NJRES comprises the Energy Services segment. Energy Services maintains and transacts around a portfolio of natural gas transportation and storage capacity contracts and provides physical wholesale energy, retail energy and energy management services in the U.S. and Canada. NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, invests in energy-related ventures through its subsidiaries. The Company operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River and Adelphia Gateway, and is subject to rate regulation by FERC. The Company holds a 50 percent combined ownership interest in Steckman Ridge, located in Pennsylvania and 20 percent ownership interest in PennEast, which are accounted for under the equity method of accounting. NJR Retail Holdings Corporation has two principal subsidiaries, NJRHS, which provides heating, central air conditioning, standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey, and CR&R, which owns commercial real estate. NJRHS and CR&R are included in Home Services and Other operations.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by the Company in accordance with the rules and regulations of the U.S. Securities and Exchange Commission and GAAP. The September 30, 2021 Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in the Company's 2021 Annual Report on Form 10-K. The Unaudited Condensed Consolidated Financial Statements include the accounts of NJR and its subsidiaries. In the opinion of management, the accompanying Unaudited Condensed Consolidated Financial Statements reflect all adjustments necessary for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of the Company's utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ending September 30, 2022. Intercompany transactions and accounts have been eliminated. Use of Estimates The preparation of financial statements in conformity with GAAP requires the Company to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosure of contingencies during the reporting period. On a quarterly basis or more frequently whenever events or changes in circumstances indicate a need, the Company evaluates its estimates, including those related to the calculation of the fair value of derivative instruments, debt, equity method investments, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, long-lived assets, regulatory assets and liabilities, income taxes, pensions and other postemployment benefits, contingencies related to environmental matters and litigation. Asset retirement obligations are evaluated as often as needed. The Company’s estimates are based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates. In March 2020, COVID-19 was declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention and has spread globally, including throughout the U.S. The Company’s Unaudited Condensed Consolidated Financial Statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the balance sheet date and reported amounts of revenue and expenses during the reporting periods presented. The Company continues to closely monitor developments related to the COVID-19 pandemic and has, when appropriate, taken steps to ensure business continuity in the safe operation of its business. These steps include working from home for office-based employees utilizing a newly implemented hybrid schedule, limiting direct contact with customers and suspending late payment fees for utility customers. While the Company and many businesses are beginning to return to normal operating practices, this remains an evolving situation. The timing for recovery of businesses and local economies, resurgences or mutations of the virus, and any potential future shutdowns remains unknown. Throughout the COVID-19 pandemic, the Company has continued to provide essential services to our customers. Both the Company and NJNG continue to have sufficient liquidity to meet their current obligations and business operations remain fundamentally unchanged at this time. The Company will continue to monitor developments affecting its employees, customers, and operations and take additional steps to address the COVID-19 pandemic and its impacts, as necessary. The Company considered the impacts of COVID-19 on the assumptions and estimates used and determined that there have been no material adverse impacts on the Company’s results of operations as of March 31, 2022. 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. TREC revenue is recognized when TRECs are generated and are transferred monthly based upon metered solar electricity activity. Revenues for Energy Services are recognized when the natural gas is physically delivered to the customer. In addition, changes in the fair value of derivatives that economically hedge the forecasted sales of the natural gas are recognized in operating revenues as they occur, as noted above. Energy Services also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues. During December 2020, Energy Services entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts, which commenced on November 1, 2021. The AMAs include a series of temporary and permanent releases and revenue under these agreements is recognized as the performance obligations are satisfied. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed upon term. For permanent releases of pipeline capacity, which represent a transfer of contractual rights for such capacity, revenue is recognized upon the transfer of the underlying contractual rights. Energy Services recognized $10.3 million and $32.4 million of operating revenue on the Unaudited Condensed Consolidated Statements of Operations during the three and six months ended March 31, 2022, respectively. Amounts received in excess of revenue totaling $54.4 million are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets as of March 31, 2022. The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, related usage fees and hub services for the use of storage space, injections and withdrawals from their natural gas storage facility and the delivery of natural gas to customers. Demand fees are recognized as revenue over the term of the related agreement while usage fees and hub services revenues are recognized as services are performed. Revenues from all other activities are recorded in the period during which products or services are delivered and accepted by customers, or over the related contractual term. See Note 3. Revenue for further information. Cash and Cash Equivalents Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to irrevocable letters of credit at Leaf River and escrow balances for utility plant projects at NJNG, which are recorded in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets, respectively. The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Unaudited Condensed Consolidated Balance Sheets to the total amounts in the Unaudited Condensed Consolidated Statements of Cash Flows as follows: (Thousands) March 31, 2022 September 30, March 31, Balance Sheet Cash and cash equivalents $ 13,906 $ 4,749 $ 57,654 Restricted cash in other noncurrent assets $ 1,294 $ 1,294 $ 1,321 Statements of Cash Flow Cash, cash equivalents and restricted cash $ 15,200 $ 6,043 $ 58,975 Allowance for Doubtful Accounts The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations, and macroeconomic factors, such as unemployment rates among others, including the estimated impact of the ongoing pandemic on the outstanding balances. In December 2021, the Company deferred a portion of costs incurred related to bad debt for NJNG associated with customer accounts receivable as a regulatory asset resulting from the impacts of the ongoing COVID-19 pandemic. See Note 4. Regulation for additional information. Loans Receivable NJNG currently provides loans, with terms ranging from two Natural Gas in Storage The following table summarizes natural gas in storage, at average cost by segment as of: March 31, 2022 September 30, 2021 ($ in thousands) Natural Gas in Storage Bcf Natural Gas in Storage Bcf Natural Gas Distribution $ 31,066 4.9 $ 115,824 27.6 Energy Services 35,234 7.4 77,782 18.8 Total $ 66,300 12.3 $ 193,606 46.4 Software Costs The Company capitalizes certain costs, such as software design and configuration, coding, testing and installation, that are incurred to purchase or create and implement computer software for internal use. Capitalized costs include external costs of materials and services utilized in developing or obtaining internal-use software and payroll and payroll-related costs for employees who are directly associated with and devote time to the internal-use software project. Maintenance costs are expensed as incurred. Upgrades and enhancements are capitalized if it is probable that such expenditures will result in additional functionality. Amortization is recorded on the straight-line basis over the estimated useful lives. The following tables present the software costs included in the Unaudited Condensed Consolidated Financial Statements: (Thousands) March 31, 2022 September 30, Balance Sheets Utility plant, at cost $ 16,959 $ 16,543 Construction work in progress $ 20,752 $ 7,801 Nonutility plant and equipment, at cost $ 344 $ 338 Construction work in progress $ — $ 8 Accumulated depreciation and amortization, utility plant $ (1,944) $ (1,333) Accumulated depreciation and amortization, nonutility plant and equipment $ (19) $ (29) Software costs $ 5,714 $ 5,582 Three Months Ended Six Months Ended March 31, March 31, Statements of Operations 2022 2021 2022 2021 Operation and maintenance (1) $ 2,828 $ 2,847 $ 5,351 $ 4,770 Depreciation and amortization $ 303 $ 270 $ 602 $ 523 (1) During the three and six months ended March 31, 2022, approximately $113,000 and $225,000, respectively, was amortized from software costs into O&M. During the three and six months ended March 31, 2021, approximately $111,000 and $188,000, respectively, was amortized from software costs into O&M. Sale Leasebacks NJNG utilizes sale leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease or repurchase the asset at the end of the term. Proceeds from sale leaseback transactions are accounted for as financing arrangements and are included in long-term debt on the Unaudited Condensed Consolidated Balance Sheets. NJNG received $17.3 million during the six months ended March 31, 2022, 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 arrangement does not qualify as a sale as the Company retains control of the underlying assets and, as such, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the buyer-lessor that constitute a payment to acquire the solar energy asset as a financing arrangement, which is recorded as a component of debt on the Unaudited Condensed Consolidated Balance Sheets. The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from RECs and energy sales. The ITCs and other tax benefits associated with these solar projects transfer to the buyer; however, the payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax attributes. Accordingly, Clean Energy Ventures recognizes the equivalent value of the tax attributes in other income on the Unaudited Condensed Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. Clean Energy Ventures received proceeds of $3.3 million and $12.1 million during the six months ended March 31, 2022 and 2021, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets. Accumulated Other Comprehensive (Loss) Income The following table presents the changes in the components of accumulated other comprehensive (loss) income, net of related tax effects during the three months ended March 31, 2022 and 2021: (Thousands) Cash Flow Hedges Postemployment Benefit Obligation Total Balance at December 31, 2021 $ (9,112) $ (24,386) $ (33,498) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(80), $(232), $(312), respectively 263 768 (1) 1,031 Balance at March 31, 2022 $ (8,849) $ (23,618) $ (32,467) Balance at December 31, 2020 $ (10,166) $ (33,106) $ (43,272) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(79), $(244), $(323) 263 813 (1) 1,076 Balance at March 31, 2021 $ (9,903) $ (32,293) $ (42,196) 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, 2022 and 2021: (Thousands) Cash Flow Hedges Postemployment Benefit Obligation Total Balance at September 30, 2021 $ (9,376) $ (25,152) $ (34,528) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(159), $(465), $(624), respectively 527 1,534 (1) 2,061 Balance at March 31, 2022 $ (8,849) $ (23,618) $ (32,467) Balance at September 30, 2020 $ (10,397) $ (33,918) $ (44,315) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(191), $(489) and $(680) 494 1,625 (1) 2,119 Balance at March 31, 2021 $ (9,903) $ (32,293) $ (42,196) (1) Included in the computation of net periodic pension cost, a component of operations and maintenance expense on the Unaudited Condensed Consolidated Statements of Operations. Reclassification Certain prior period amounts related to deferred revenue within current liabilities on the Unaudited Condensed Consolidated Balance Sheets and Unaudited Consolidated Condensed Statements of Cash Flows have been reclassified to conform to the current period presentation. Recently Adopted Updates to the Accounting Standards Codification Income Taxes In December 2019, the FASB issued ASU No. 2019-12, an amendment to ASC 740, Income Taxes , which simplifies the accounting for income taxes and changes the accounting for certain income tax transactions, among other minor improvements. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. The amendments in this update were either not applicable, currently applied, or did not have a material impact on the Company's financial position, results of operations, cash flows or disclosures. Investments - Equity Securities, Investments - Equity Method and Joint Ventures and Derivatives and Hedging In January 2020, the FASB issued ASU No. 2020-01, an amendment to ASC 321, Investments - Equity Securities, ASC 323 , Investments - Equity Method and Joint Ventures, and ASC 815 , Derivatives and Hedging, which clarifies the interactions between the three ASU topics. The update requires an entity to evaluate observable transactions that necessitate applying or discontinuing the equity method of accounting when applying the measurement alternative in Topic 321. This evaluation occurs prior to applying or upon ceasing the equity method. The update also states that when applying paragraph 815-10-15-141(a) for forward contracts and purchased options, an entity is not required to assess whether the underlying securities will be accounted for under the equity method in accordance with Topic 323 or fair value method under Topic 825 upon settlement or exercise. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures. Other In October 2020, the FASB issued ASU No. 2020-10, Codification Improvements , which clarifies application of various provisions in the ASC by amending and adding new headings, cross referencing to other guidance, and refining or correcting terminology. It also improves the consistency by amending the ASC to include all disclosure guidance in the appropriate section. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures. Other Recent Updates to the Accounting Standards Codification Debt and Other In August 2020, the FASB issued ASU No. 2020-06, an amendment to ASC 470, Debt , and ASC 815, Derivatives and Hedging , which changes the accounting for convertible instruments by reducing the number of acceptable accounting models to three models including, the embedded derivative, substantial premium, and traditional no proceeds allocated models. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it on either a modified or a full retrospective basis. The Company does not currently have convertible debt instruments and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption. In May 2021, the FASB issued ASU No. 2021-04, an amendment to ASC 470, Debt , ASC 260, Earnings per Share , ASC 718, Stock Compensation , and ASC 815, Derivatives and Hedging. The update impacts equity-classified written call options that remain equity-classified after a modification or exchange. The guidance is effective for the Company beginning October 1, 2022, and will be applied on a prospective basis. The Company does not currently have equity-classified written call options and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption. Leases In July 2021, the FASB issued ASU No. 2021-05, an amendment to ASC 842, Leases , which requires a lessor to classify a lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another classification, including sales-type or direct financing would trigger a loss at the lease commencement date. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it either on a retrospective basis to leases that have commenced or have been modified under ASC 842 or on a prospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption. Business Combinations In October 2021, the FASB issued ASU No. 2021-08, an amendment to ASC 805, Business Combinations , which requires that an acquirer recognize, and measure contract assets and contract liabilities acquired in a business combination in accordance with Topic 606, Revenue from Contracts with Customers . The guidance is effective for the Company beginning October 1, 2023, and will be applied on a prospective basis to new acquisitions following the date of adoption. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption. Derivatives and Hedging In March 2022, the FASB issued ASU No. 2022-01, an amendment to ASC 815, Derivatives and Hedging , which addresses fair value hedge accounting of interest rate risk for portfolios of financial assets. This update further clarifies guidance previously released in ASU 2017-12 which established the "last-of-layer" method and this update renames that method to the “portfolio layer” method. The guidance is effective for the Company beginning October 1, 2023, and the transition method can be on a prospective basis for a multiple-layer hedging strategy or a modified retrospective basis for a portfolio layer method. The Company does not currently apply hedge accounting to any of its risk management activities and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption. Financial Instruments In March 2022, the FASB issued ASU No. 2022-02, an amendment to ASC 326, Financial Instruments-Credit Losses , which eliminates the accounting guidance for creditors in troubled debt restructuring. It also aligns conflicting disclosure requirement guidance in ASC 326 by requiring disclosure of current-period gross write-offs by year of origination. The amendment also adds new disclosures for creditors with loan refinancing and restructuring for borrowers experiencing financial difficulty. The guidance is effective for the Company beginning October 1, 2023, and the Company can elect to apply it either on a modified retrospective or prospective basis. At this time, the Company has not experienced a troubled debt restructuring and thus does not expect the amendments to have an impact on its financial position, results of operations and cash flows upon adoption. The Company is currently evaluating the amendments to understand the impact on its disclosures upon adoption.

REVENUE

REVENUE	6 Months Ended
	Mar. 31, 2022
Revenue from Contract with Customer [Abstract]
REVENUE	3. REVENUE Revenue is recognized when a performance obligation is satisfied by transferring control of a product or service to a customer. Revenue is measured based on consideration specified in a contract with a customer using the output method of progress. The Company elected to apply the invoice practical expedient for recognizing revenue, whereby the amounts invoiced to customers represent the value to the customer and the Company’s performance completion as of the invoice date. Therefore, the Company does not disclose related unsatisfied performance obligations. The Company also elected the practical expedient to exclude from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales tax net in operating revenues on the Unaudited Condensed Consolidated Statements of Operations. Below is a listing of performance obligations that arise from contracts with customers, along with details on the satisfaction of each performance obligation, the significant payment terms and the nature of the goods and services being transferred, by reporting segment and other business operations: Revenue Recognized Over Time: Segment Performance Obligation Description Natural Gas Distribution Natural gas utility sales NJNG's performance obligation is to provide natural gas to residential, commercial and industrial customers as demanded, based on regulated tariff rates, which are established by the BPU. Revenues from the sale of natural gas are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for quantities consumed but not billed during the period. Payment is due each month for the previous month's deliveries. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the billing period. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects and the most current tariff rates. NJNG is entitled to be compensated for performance completed until service is terminated. Customers may elect to purchase the natural gas commodity from NJNG or may contract separately to purchase natural gas directly from third-party suppliers. As NJNG is acting as an agent on behalf of the third-party supplier, revenue is recorded for the delivery of natural gas to the customer. Clean Energy Ventures Commercial solar electricity Clean Energy Ventures operates wholly-owned solar projects that recognize revenue as electricity is generated and transferred to the customer. The performance obligation is to provide electricity to the customer in accordance with contract terms or the interconnection agreement and is satisfied upon transfer of electricity generated. Revenue is recognized as invoiced and the payment is due each month for the previous month's services. Clean Energy Ventures Residential solar electricity Clean Energy Ventures provides access to residential rooftop and ground-mount solar equipment to customers who then pay the Company a monthly fee. The performance obligation is to provide electricity to the customer based on generation from the underlying residential solar asset and is satisfied upon transfer of electricity generated. Revenue is derived from the contract terms and is recognized as invoiced, with the payment due each month for the previous month's services. Clean Energy Ventures Transition renewable energy certificates Clean Energy Ventures generates TRECs, which are created for every MWh of electricity produced by a solar generator. The performance obligation of Clean Energy Ventures is to generate electricity and TRECs, which are purchased monthly by a REC Administrator. Revenue is recognized upon generation. Energy Services Natural gas services The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers in line with the terms of the contract and based on the services provided. Payment is due upon receipt of the invoice. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed upon term. Storage and Transportation Natural gas services The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as customers receive the benefits of its service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement. Home Services and Other Service contracts Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice. Revenue Recognized at a Point in Time: Energy Services Natural gas services For a permanent release of pipeline capacity, the performance obligation of NJRES is the release of the pipeline capacity associated with certain natural gas transportation contracts and the transfer of the underlying contractual rights to the counterparty. Revenue is recognized upon the transfer of the underlying contractual rights. Storage and Transportation Natural gas services The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from usage fees and hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Usage fees and hub services revenues are recognized as services are performed. Home Services and Other Installations Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators to customers. The distinct performance obligation is the installation of the contracted appliance, which is satisfied at the point in time the item is installed. The transaction price for each installation differs accordingly. Revenue is recognized at a point in time upon completion of the installation, which is when the customer is billed. Disaggregated revenues from contracts with customers by product line and by reporting segment and other business operations during the three months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Natural gas utility sales $ 381,861 — — — — $ 381,861 Natural gas services — — 17,309 13,342 — 30,651 Service contracts — — — — 8,492 8,492 Installations and maintenance — — — — 4,730 4,730 Renewable energy certificates — 1,019 — — — 1,019 Electricity sales — 6,846 — — — 6,846 Eliminations (1) (338) — — (537) (81) (956) Revenues from contracts with customers 381,523 7,865 17,309 12,805 13,141 432,643 Alternative revenue programs (2) 2,504 — — — — 2,504 Derivative instruments 79,447 3,962 (3) 395,336 — — 478,745 Eliminations (1) — — (1,576) — — (1,576) Revenues out of scope 81,951 3,962 393,760 — — 479,673 Total operating revenues $ 463,474 11,827 411,069 12,805 13,141 $ 912,316 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 (1) Includes building rent related to the Wall headquarters, which is eliminated in consolidation. (2) Consists of transactions between subsidiaries that are eliminated in consolidation. (3) Includes CIP revenue. (4) Includes SREC revenue. Disaggregated revenues from contracts with customers by product line and by reporting segment and other business operations during the six months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Natural gas utility sales (1) $ 605,657 — — — — $ 605,657 Natural gas services — — 45,188 25,485 — 70,673 Service contracts — — — — 16,959 16,959 Installations and maintenance — — — — 10,214 10,214 Renewable energy certificates — 1,865 — — — 1,865 Electricity sales — 13,316 — — — 13,316 Eliminations (2) (675) — — (1,096) (180) (1,951) Revenues from contracts with customers 604,982 15,181 45,188 24,389 26,993 716,733 Alternative revenue programs (3) 13,158 — — — — 13,158 Derivative instruments 119,769 6,829 (4) 736,701 — — 863,299 Eliminations (2) — — (5,032) — — (5,032) Revenues out of scope 132,927 6,829 731,669 — — 871,425 Total operating revenues $ 737,909 22,010 776,857 24,389 26,993 $ 1,588,158 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 (3) (5,096) — — — — (5,096) Derivative instruments 24,740 2,069 (4) 674,607 — — 24,740 Eliminations (2) — — (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 (1) Includes building rent related to the Wall headquarters, which is eliminated in consolidation. (2) Consists of transactions between subsidiaries that are eliminated in consolidation. (3) Includes CIP revenue. (4) Includes SREC revenue. Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the three months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Residential $ 286,205 2,991 — — 13,105 $ 302,301 Commercial and industrial 60,106 4,874 17,309 12,805 36 95,130 Firm transportation 34,636 — — — — 34,636 Interruptible and off-tariff 576 — — — — 576 Revenues out of scope 81,951 3,962 393,760 — — 479,673 Total operating revenues $ 463,474 11,827 411,069 12,805 13,141 $ 912,316 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 Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the six months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Residential $ 437,513 5,963 — — 26,880 $ 470,356 Commercial and industrial 107,290 9,218 45,188 24,389 113 186,198 Firm transportation 57,311 — — — — 57,311 Interruptible and off-tariff 2,868 — — — — 2,868 Revenues out of scope 132,927 6,829 731,669 — — 871,425 Total operating revenues $ 737,909 22,010 776,857 24,389 26,993 $ 1,588,158 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 Customer Accounts Receivable/Credit Balances and Deposits The timing of revenue recognition, customer billings and cash collections resulting in accounts receivables, billed and unbilled, and customers’ credit balances and deposits on the Unaudited Condensed Consolidated Balance Sheets during the six months ended March 31, 2022 and 2021, are as follows: Customer Accounts Receivable Customers' Credit (Thousands) Billed Unbilled Balances and Deposits Balance as of September 30, 2021 $ 212,838 $ 10,351 $ 32,586 Increase (Decrease) 60,475 45,919 (12,302) Balance as of March 31, 2022 $ 273,313 $ 56,270 $ 20,284 Balance as of September 30, 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, 2022 and September 30, 2021: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total March 31, 2022 Customer accounts receivable Billed $ 154,380 5,239 107,262 4,385 2,047 $ 273,313 Unbilled 54,675 1,595 — — — 56,270 Customers' credit balances and deposits (20,284) — — — — (20,284) Total $ 188,771 6,834 107,262 4,385 2,047 $ 309,299 September 30, 2021 Customer accounts receivable Billed $ 54,514 5,534 147,087 3,956 1,747 $ 212,838 Unbilled 8,427 1,924 — — — 10,351 Customers' credit balances and deposits (32,586) — — — — (32,586) Total $ 30,355 7,458 147,087 3,956 1,747 $ 190,603

REGULATION

REGULATION	6 Months Ended
	Mar. 31, 2022
Regulated Operations [Abstract]
REGULATION	4. REGULATION NJNG is subject to cost-based regulation, therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility capital investments based on the BPU's approval. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations. NJNG's recovery of costs is facilitated through its base rates, BGSS and other regulatory tariff riders. NJNG is required to make filings to the BPU for review of its BGSS, CIP and other programs and related rates. Annual rate changes are typically requested to be effective at the beginning of the following fiscal year. The current base rates include a weighted average cost of capital of 6.84 percent and a return on common equity of 9.6 percent. All rate and program changes are subject to proper notification and BPU review and approval. In addition, NJNG is permitted to implement certain BGSS rate changes on a provisional basis with proper notification to the BPU. Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets for NJNG are comprised of the following: (Thousands) March 31, 2022 September 30, Regulatory assets-current New Jersey Clean Energy Program $ 6,608 $ 16,308 Conservation Incentive Program 24,997 11,839 Other current regulatory assets 1,241 1,554 Total current regulatory assets $ 32,846 $ 29,701 Regulatory assets-noncurrent Environmental remediation costs: Expended, net of recoveries $ 65,523 $ 58,483 Liability for future expenditures 121,615 135,012 Deferred income taxes 39,857 39,694 SAVEGREEN 33,917 32,941 Postemployment and other benefit costs 111,918 117,194 Deferred storm damage costs 3,257 4,343 Cost of removal 100,423 99,238 Other noncurrent regulatory assets 32,040 32,695 Total noncurrent regulatory assets $ 508,550 $ 519,600 Regulatory liability-current Overrecovered natural gas costs $ 27,133 $ 5,510 Derivatives at fair value, net 60,931 22,497 Total current regulatory liabilities $ 88,064 $ 28,007 Regulatory liabilities-noncurrent Tax Act impact (1) $ 187,876 $ 190,386 Derivatives at fair value, net — 1,166 Other noncurrent regulatory liabilities 590 336 Total noncurrent regulatory liabilities $ 188,466 $ 191,888 (1) Reflects the re-measurement and subsequent amortization of NJNG's net deferred tax liabilities as a result of the change in federal tax rates enacted in the Tax Act, 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. As of March 31, 2022, other noncurrent regulatory assets include deferred pandemic costs of $7.5 million primarily related to a portion of bad debt associated with customer accounts receivable resulting from the impacts of the ongoing COVID-19 pandemic. These costs are eligible for future regulatory recovery. There were no deferred pandemic costs as of September 30, 2021. Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets for Adelphia Gateway are comprised of the following: (Thousands) March 31, September 30, Total current regulatory assets $ 871 $ 417 Total noncurrent regulatory assets $ 4,456 $ 2,499 Total noncurrent regulatory liabilities $ 2,984 $ 1,163 The assets are comprised primarily of the tax benefit associated with the equity component of AFUDC and the liability consists primarily of scheduling penalties. Recovery of regulatory assets is subject to FERC approval. Regulatory filings and/or actions that occurred during the current fiscal year include the following: • On November 17, 2021, the BPU issued an order adopting a stipulation of settlement approving a $79.0 million increase to base rates, effective December 1, 2021. In addition, the order also included approval for the final increase for the NJ RISE/SAFE II programs, which totaled $269,000. The increase includes an overall rate of return on rate base of 6.84 percent, return on common equity of 9.6 percent, a common equity ratio of 54.0 percent and a depreciation rate of 2.78 percent. • On November 17, 2021, the BPU approved a $2.9 million increase to the annual revenues credited to BGSS, a $13.0 million annual increase related to its balancing charge, as well as changes to CIP rates, which will result in a $6.3 million decrease to the annual recovery, effective December 1, 2021. On April 6, 2022, the BPU and Rate Counsel executed a Stipulation for final BGSS/CIP rates. The BGSS, CIP, and balancing charge rates are currently in effect, on an interim basis, so there is no further rate impact to customers with this filing. • On November 19, 2021, NJNG submitted notification of its intent to self-implement an increase to its BGSS rate which will result in an approximately $24.2 million increase to annual revenues credited to BGSS, effective December 1, 2021. • On January 26, 2022, the BPU approved a stipulation to resolve the current EE annual cost recovery filing, which will increase annual recoveries by $2.2 million, effective February 1, 2022. • On March 23, 2022, the BPU approved NJNG's annual filing to increase the RAC by $600,000 and decrease the NJCEP by $2.9 million, effective April 1, 2022. • On March 31, 2022, NJNG filed its first rate recovery request for its BPU approved IIP with capital expenditures estimated at $25.6 million, including AFUDC through June 30, 2022. • On April 22, 2022, NJNG filed a petition with the BPU seeking authority to issue up to $500 million in Medium Term Notes over a 3-year period.

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS	6 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVE INSTRUMENTS	5. DERIVATIVE INSTRUMENTS The Company is subject primarily to commodity price risk due to fluctuations in the market price of natural gas, SRECs and electricity. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs and electricity. In addition, the Company is exposed to foreign currency and interest rate risk and may utilize foreign currency derivatives to hedge Canadian dollar denominated natural gas purchases and/or sales and interest rate derivatives to reduce exposure to fluctuations in interest rates. All of these types of contracts are accounted for as derivatives, unless the Company elects NPNS, which is done on a contract-by-contract election. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company’s fair value measurement policies and level disclosures associated with the Company’s derivative instruments, see Note 6. Fair Value . Energy Services Energy Services chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS. The changes in the fair value of these derivatives are recorded as a component of natural gas purchases or operating revenues, as appropriate for Energy Services, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of natural gas purchases and realized gains and losses on all physical derivatives follow the presentation of the related unrealized gains and losses as a component of either natural gas purchases or operating revenues. Energy Services also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the U.S. dollar. Energy Services may utilize foreign currency derivatives to lock in the exchange rates associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are typically used to hedge demand fee payments on pipeline capacity, storage and natural gas purchase agreements. As a result of Energy Services entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed natural gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings. Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. Energy Services recognizes changes in the fair value of these derivatives as a component of operating revenues. Upon settlement of the contract, the related revenue is recognized when the SREC is transferred to the counterparty. Natural Gas Distribution Changes in fair value of NJNG's financial commodity derivatives are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis. Accordingly, physical natural gas purchases are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered. The average cost of natural gas is charged to expense in the current period earnings based on the BGSS factor times the therm sales. Effective for contracts executed on or after January 1, 2016, NJNG no longer elects NPNS accounting treatment on a portfolio basis. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as normal. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for natural gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. Clean Energy Ventures The Company elects NPNS accounting treatment on PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to do so, the Company can and may elect to treat certain contracts as normal. Fair Value of Derivatives The following table presents the fair value of the Company's derivative assets and liabilities recognized on the Unaudited Condensed Consolidated Balance Sheets as of: Derivatives at Fair Value March 31, 2022 September 30, 2021 (Thousands) Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives not designated as hedging instruments: Natural Gas Distribution: Physical commodity contracts Derivatives - current $ 101 $ 16 $ 36 $ 16 Financial commodity contracts Derivatives - current 111 1,887 2,046 13 Energy Services: Physical commodity contracts Derivatives - current 1,853 21,594 2,818 24,592 Derivatives - noncurrent 131 19,632 333 13,237 Financial commodity contracts Derivatives - current 19,483 21,701 30,226 62,521 Derivatives - noncurrent 4,009 — 3,068 260 Foreign currency contracts Derivatives - current 38 18 125 3 Derivatives - noncurrent — — 2 — Total fair value of derivatives $ 25,726 $ 64,848 $ 38,654 $ 100,642 Offsetting of Derivatives The Company transacts under master netting arrangements or equivalent agreements that allow it to offset derivative assets and liabilities with the same counterparty. However, the Company’s policy is to present its derivative assets and liabilities on a gross basis at the contract level unit of account on the Unaudited Condensed Consolidated Balance Sheets. The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral, as well as the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to. (Thousands) Amounts Presented on Balance Sheets (1) Offsetting Derivative Instruments (2) Financial Collateral Received/Pledged (3) Net Amounts (4) As of March 31, 2022: Derivative assets: Energy Services Physical commodity contracts $ 1,984 $ (480) $ (200) $ 1,304 Financial commodity contracts 23,492 (18,300) — 5,192 Foreign currency contracts 38 (18) — 20 Total Energy Services $ 25,514 $ (18,798) $ (200) $ 6,516 Natural Gas Distribution Physical commodity contracts $ 101 $ (8) $ — $ 93 Financial commodity contracts 111 (111) — — Total Natural Gas Distribution $ 212 $ (119) $ — $ 93 Derivative liabilities: Energy Services Physical commodity contracts $ 41,226 $ (480) $ — $ 40,746 Financial commodity contracts 21,701 (18,300) — 3,401 Foreign currency contracts 18 (18) — — Total Energy Services $ 62,945 $ (18,798) $ — $ 44,147 Natural Gas Distribution Physical commodity contracts $ 16 $ (8) $ — $ 8 Financial commodity contracts 1,887 (111) — 1,776 Total Natural Gas Distribution $ 1,903 $ (119) $ — $ 1,784 As of September 30, 2021: Derivative assets: Energy Services Physical commodity contracts $ 3,151 $ (894) $ (700) $ 1,557 Financial commodity contracts 33,294 (33,294) 20,532 20,532 Foreign currency contracts 127 (3) — 124 Total Energy Services $ 36,572 $ (34,191) $ 19,832 $ 22,213 Natural Gas Distribution Physical commodity contracts $ 36 $ (8) $ — $ 28 Financial commodity contracts 2,046 (13) — 2,033 Total Natural Gas Distribution $ 2,082 $ (21) $ — $ 2,061 Derivative liabilities: Energy Services Physical commodity contracts $ 37,829 $ (894) $ — $ 36,935 Financial commodity contracts 62,781 (33,294) — 29,487 Foreign currency contracts 3 (3) — — Total Energy Services $ 100,613 $ (34,191) $ — $ 66,422 Natural Gas Distribution Physical commodity contracts $ 16 $ (8) $ — $ 8 Financial commodity contracts 13 (13) — — Total Natural Gas Distribution $ 29 $ (21) $ — $ 8 (1) Derivative assets and liabilities are presented on a gross basis on the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20. (2) Includes transactions with NAESB netting election, transactions held by FCMs with net margining and transactions with ISDA netting. (3) Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties. (4) Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20. Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical natural gas to be used for storage injection and its subsequent sale at a later date. The gains or (losses) on the financial transactions that are economic hedges of the cost of the purchased natural gas are recognized prior to the gains or (losses) on the physical transaction, which are recognized in earnings when the natural gas is delivered. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments, creates volatility in the results of Energy Services, although the Company's intended economic results relating to the entire transaction are unaffected. The following table presents the effect of derivative instruments recognized on the Unaudited Condensed Consolidated Statements of Operations for the periods set forth below: (Thousands) Location of gain (loss) recognized in income on derivatives Amount of gain (loss) recognized Three Months Ended Six Months Ended March 31, March 31, Derivatives not designated as hedging instruments: 2022 2021 2022 2021 Energy Services: Physical commodity contracts Operating revenues $ (11,582) $ 36,419 $ (11,432) $ 41,671 Physical commodity contracts Natural gas purchases (875) 2,650 630 (2,404) Financial commodity contracts Natural gas purchases (31,223) (27,315) 29,966 20,440 Foreign currency contracts Natural gas purchases (14) 27 (14) 227 Total unrealized and realized (gain) loss $ (43,694) $ 11,781 $ 19,150 $ 59,934 NJNG’s derivative contracts are part of the Company's risk management activities that relate to its natural gas purchases and BGSS incentive programs. At settlement, the resulting gains and/or losses are payable to or recoverable from utility customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings. The following table reflects the gains (losses) associated with NJNG's derivative instruments for the periods set forth below: Three Months Ended Six Months Ended March 31, March 31, (Thousands) 2022 2021 2022 2021 Natural Gas Distribution: Physical commodity contracts $ 4,538 $ 1,091 $ 6,234 $ 1,433 Financial commodity contracts 61,485 645 46,838 (3,627) Total unrealized and realized gain (loss) $ 66,023 $ 1,736 $ 53,072 $ (2,194) During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with debt issuances that were finalized in 2020. NJR designates its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges are recorded in OCI and upon settlement of the contracts, realized gains and (losses) are reclassified from OCI to interest expense on the Consolidated Statements of Operations. Pre-tax losses of $343,000 and $342,000 were reclassified from OCI into income during the three months ended March 31, 2022 and 2021, respectively, and pre-tax losses of $686,000 and $685,000 were reclassified during the six months ended March 31, 2022 and 2021, respectively. NJNG and Energy Services had the following outstanding long (short) derivatives as of: Volume (Bcf) Transaction Type March 31, 2022 September 30, Natural Gas Distribution Futures 29.6 22.2 Physical Commodity 12.8 7.6 Energy Services Futures (0.7) (13.4) Swaps (0.2) (0.3) Physical Commodity 7.5 0.6 Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $(20,000) as of March 31, 2022 and $(123,000) as of September 30, 2021, and 1.5 million and 1.4 million SRECs that were open as of March 31, 2022 and September 30, 2021, 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, 2022 September 30, Natural Gas Distribution Restricted broker margin accounts-current assets $ 11,617 $ 2,790 Energy Services Restricted broker margin accounts-current assets $ 38,284 $ 70,050 Restricted broker margin accounts-current liabilities $ (2,464) $ — 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, 2022. 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 $ 128,926 Noninvestment grade 9,601 Internally rated investment grade 20,566 Internally rated noninvestment grade 22,225 Total $ 181,318 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.

FAIR VALUE

FAIR VALUE	6 Months Ended
	Mar. 31, 2022
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, 2022 September 30, Carrying value (1) (2) (3) $ 2,202,845 $ 2,102,845 Fair market value $ 2,137,966 $ 2,288,544 (1) Excludes finance leases of $33.5 million and $20.1 million as of March 31, 2022 and September 30, 2021, respectively. (2) Excludes NJNG's debt issuance costs of $10.1 million and $9.1 million as of March 31, 2022 and September 30, 2021, respectively. (3) Excludes NJR's debt issuance costs of $3.6 million and $3.3 million as of March 31, 2022 and September 30, 2021, respectively. Clean Energy Ventures enters into transactions to sell certain commercial solar assets and lease the assets back for a term specified in the lease. These transactions are considered financing obligations for accounting purposes and are recorded within long-term debt on the Unaudited Condensed Consolidated Balance Sheets. The estimated fair value of solar asset financing obligations as of March 31, 2022 and September 30, 2021 was $121.8 million and $132.5 million, respectively. The Company utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific issue and the Company's credit rating. As of March 31, 2022, the Company discloses its debt within Level 2 of the fair value hierarchy. Fair Value Hierarchy The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, investments in equity securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following: Level 1 Unadjusted quoted prices for identical assets or liabilities in active markets. The Company's Level 1 assets and liabilities include exchange traded natural gas futures and options contracts, listed equities and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX, CME and ICE that the Company refers to internally as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM. Level 2 Other significant observable inputs such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is: • widely accepted and public; • non-proprietary and sourced from an independent third party; and • observable and published. These additional adjustments are generally not considered to be significant to the ultimate recognized values. Level 3 Inputs derived from a significant amount of unobservable market data. These include the Company's best estimate of fair value and are derived primarily through the use of internal valuation methodologies. Assets and liabilities measured at fair value on a recurring basis are summarized as follows: Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs (Thousands) (Level 1) (Level 2) (Level 3) Total As of March 31, 2022: Assets: Physical commodity contracts $ — $ 2,085 $ — $ 2,085 Financial commodity contracts 23,603 — — 23,603 Financial commodity contracts - foreign exchange — 38 — 38 Money market funds 39 — — 39 Other 1,998 — — 1,998 Total assets at fair value $ 25,640 $ 2,123 $ — $ 27,763 Liabilities: Physical commodity contracts $ — $ 41,242 $ — $ 41,242 Financial commodity contracts 23,050 538 — 23,588 Financial commodity contracts - foreign exchange — 18 — 18 Total liabilities at fair value $ 23,050 $ 41,798 $ — $ 64,848 Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs (Thousands) (Level 1) (Level 2) (Level 3) Total As of September 30, 2021: Assets: Physical commodity contracts $ — $ 3,187 $ — $ 3,187 Financial commodity contracts 35,340 — — 35,340 Financial commodity contracts - foreign exchange — 127 — 127 Money market funds 41 — — 41 Other 1,815 — — 1,815 Total assets at fair value $ 37,196 $ 3,314 $ — $ 40,510 Liabilities: Physical commodity contracts $ — $ 37,845 $ — $ 37,845 Financial commodity contracts 62,188 606 — 62,794 Financial commodity contracts - foreign exchange — 3 — 3 Total liabilities at fair value $ 62,188 $ 38,454 $ — $ 100,642

INVESTMENTS IN EQUITY INVESTEES

INVESTMENTS IN EQUITY INVESTEES	6 Months Ended
	Mar. 31, 2022
Investments, All Other Investments [Abstract]
INVESTMENTS IN EQUITY INVESTEES	7. INVESTMENTS IN EQUITY INVESTEES The Company's investments in equity method investees include the following as of: (Thousands) March 31, 2022 September 30, Steckman Ridge (1) $ 108,501 $ 109,050 PennEast 1,479 5,479 Total $ 109,980 $ 114,529 (1) Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2022 and September 30, 2021, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023. Steckman Ridge The Company holds a 50 percent equity method investment in Steckman Ridge, a jointly owned and controlled natural gas storage facility located in Bedford County, Pennsylvania. NJNG and Energy Services have entered into storage and park and loan agreements with Steckman Ridge. See Note 15. Related Party Transactions for more information on these intercompany transactions. PennEast The Company, through its subsidiary NJR Midstream Company, is a 20 percent investor in PennEast, a partnership whose purpose was to construct and operate a 120-mile natural gas pipeline that would have extended from northeast Pennsylvania to western New Jersey. During the third quarter of fiscal 2021, the PennEast partnership determined that this project was no longer supported, and all further development ceased. The Company recognized an other-than-temporary impairment charge of $92.0 million, or approximately $74.5 million, net of income taxes, which represents the best estimate of the salvage value of the remaining assets of the project. Other-than-temporary impairments are recorded in equity in earnings (losses) of affiliates in the Unaudited Condensed Consolidated Statements of Operations. On December 16, 2021, the FERC dismissed PennEast’s pending applications. The order vacates the certificate authorization for the PennEast pipeline project in light of PennEast’s response to FERC staff’s November 23, 2021 request for a status update, in which PennEast informed the Commission it is no longer developing the project. On March 10, 2022, following the sale of certain project related assets and refunds of interconnection fees received from interstate pipelines, the PennEast board of managers approved a cash distribution to members of the partnership totaling $4.0 million per partner. The return of capital was received by the Company on March 31, 2022, and reduced the remaining carrying value of its equity method investment in PennEast to $1.5 million in the Unaudited Condensed Consolidated Balance Sheet.

EARNINGS PER SHARE

EARNINGS PER SHARE	6 Months Ended
	Mar. 31, 2022
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) 2022 2021 2022 2021 Net income, as reported $ 96,035 $ 149,809 $ 207,347 $ 230,854 Basic earnings per share Weighted average shares of common stock outstanding-basic 96,068 96,248 96,006 96,181 Basic earnings per common share $1.00 $1.56 $2.16 $2.40 Diluted earnings per share Weighted average shares of common stock outstanding-basic 96,068 96,248 96,006 96,181 Incremental shares (1) 448 370 474 417 Weighted average shares of common stock outstanding-diluted 96,516 96,618 96,480 96,598 Diluted earnings per common share (2) $1.00 $1.55 $2.15 $2.39 (1) Incremental shares consist primarily of unvested stock awards and performance shares. (2) There were anti-dilutive shares of 24,101 and 65,334 excluded from the calculation of diluted earnings per share related to an equity forward sale agreement during the three and six months ended March 31, 2021, respectively.

DEBT

DEBT	6 Months Ended
	Mar. 31, 2022
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 and Short-term Debt On February 8, 2022, NJR entered into a 364-day $150 million term loan credit agreement with an interest rate based on SOFR plus 0.85 percent and expires on February 7, 2023. The Company borrowed $50 million on February 9, 2022 and $100 million on February 14, 2022. A summary of NJR's credit facility and term loan credit agreement and NJNG's commercial paper program and credit facility are as follows: (Thousands) March 31, 2022 September 30, Expiration Dates NJR Bank revolving credit facility (1) $ 500,000 $ 500,000 September 2026 Notes outstanding at end of period $ 152,210 $ 219,100 Weighted average interest rate at end of period 2.02 % 1.05 % Amount available at end of period (2) $ 334,325 $ 270,312 Bank term loan credit agreement $ 150,000 $ — February 2023 Loans outstanding at end of period $ 150,000 $ — Weighted average interest rate at end of period 1.04 % — % Amount available at end of period $ — $ — NJNG Bank revolving credit facility (3) $ 250,000 $ 250,000 September 2026 Commercial paper and notes outstanding at end of period $ — $ 158,200 Weighted average interest rate at end of period — % 0.17 % Amount available at end of period (4) $ 249,269 $ 91,069 (1) Committed credit facilities, which require commitment fees of 0.10 percent on the unused amounts. (2) Letters of credit outstanding total $13.5 million at March 31, 2022 and $10.6 million at September 30, 2021, which reduces the amount available by the same amount. (3) Committed credit facilities, which require commitment fees of 0.075 percent on the unused amounts. (4) Letters of credit outstanding total $731,000 at both March 31, 2022 and September 30, 2021, which reduces the amount available by the same amount. Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit. Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit facility or term loan. Long-term Debt NJR On February 16, 2022, NJR signed a commitment letter with a financial institution to refinance $50 million of its Senior Unsecured Notes that are currently scheduled to mature in September 2022. The new Senior Unsecured Note will be financed over a 12-year term with an interest rate of 3.64 percent maturing in September 2034. NJNG On October 28, 2021, NJNG entered into a Note Purchase Agreement for $100 million of its senior notes, of which $50 million were issued at an interest rate of 2.97 percent, maturing in 2051, and $50 million were issued at an interest rate of 3.07 percent, maturing in 2061. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture. NJNG received $17.3 million during the six months ended March 31, 2022, in connection with the sale leaseback of its natural gas meters. NJNG records a financing lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease. There were no natural gas meter sale leasebacks recorded during the six months ended March 31, 2021. NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1.1 million and $1.2 million during the six months ended March 31, 2022 and 2021, respectively. 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

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	6 Months Ended
	Mar. 31, 2022
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) 2022 2021 2022 2021 2022 2021 2022 2021 Service cost $ 2,073 $ 2,183 $ 4,146 $ 4,365 $ 1,076 $ 1,211 $ 2,152 $ 2,422 Interest cost 2,408 2,278 4,816 4,556 1,589 1,517 3,178 3,035 Expected return on plan assets (5,318) (4,851) (10,637) (10,075) (1,894) (1,565) (3,788) (3,248) Recognized actuarial loss 2,186 2,861 4,372 5,723 1,421 1,978 2,842 3,955 Prior service cost (credit) amortization 26 26 51 51 (36) (45) (72) (90) Net periodic benefit cost $ 1,375 $ 2,497 $ 2,748 $ 4,620 $ 2,156 $ 3,096 $ 4,312 $ 6,074 The Company does not expect to be required to make additional contributions to fund the pension plans during fiscal 2022 based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents. In addition, as in the past, the Company may elect to make contributions in excess of the minimum required amount to the plans. There were no discretionary contributions made during the six months ended March 31, 2022 and 2021. 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.

INCOME TAXES

INCOME TAXES	6 Months Ended
	Mar. 31, 2022
Income Tax Disclosure [Abstract]
INCOME TAXES	11. INCOME TAXES ASC Topic 740, Income Taxes requires the use of an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating its estimated annual effective tax rate, the Company considers forecasted annual pre-tax income and estimated permanent book versus tax differences. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change. Changes in tax laws or tax rates are recognized in the financial reporting period that includes the enactment date, the date in which the act is signed into law. The Company evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with unrecognized tax benefits. A tax benefit claimed, or expected to be claimed, on a tax return may be recognized if it is more likely than not that the position will be upheld upon examination by the applicable taxing authority. Interest and penalties related to unrecognized tax benefits, if any, are recognized within income tax expense and accrued interest, and penalties are recognized within other noncurrent liabilities on the Unaudited Condensed Consolidated Balance Sheets. Effective Tax Rate The forecasted effective tax rates were 22.3 percent and 19.9 percent, for the six months ended March 31, 2022 and 2021, 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, 2022 and 2021, discrete items totaled approximately $(166,000) and $(145,000), respectively, related to excess tax expense (benefits) associated with the vesting of share-based awards. NJR’s actual effective tax rate was 22.3 percent and 19.7 percent during the six months ended March 31, 2022 and 2021, respectively. Other Tax Items As of March 31, 2022 and September 30, 2021, the Company has tax credit carryforwards of approximately $227.1 million and $224.2 million, respectively, which each have a life of 20 years. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2035. As of March 31, 2022 and September 30, 2021, the Company has state income tax net operating losses of approximately $404.8 million and $554.6 million, respectively. These state net operating losses have varying carry-forward periods dictated by the state in which they were incurred; these state carry-forward periods range from seven The impairment of the equity method investment in PennEast created potential net capital loss attributes totaling approximately $61.8 million, which can only be utilized to offset capital gains income, and can be carried back three years and forward five years prior to expiration. As of March 31, 2022, the Company has a valuation allowance totaling $23.7 million comprised of approximately $17.3 million related to the recognition of state net operating loss carryforwards, which primarily relate to New Jersey and approximately $6.4 million related to potential capital loss carryforwards resulting from the impairment of the equity method investment in PennEast, which the Company believes may not be fully utilized prior to expiration. As of September 30, 2021, the Company had a valuation allowance totaling $23.6 million related to the state net operating loss carryforwards and the potential capital loss carryforwards resulting from the impairment of the equity method investment, as previously discussed. The Consolidated Appropriations Act extended the 30 percent ITC for solar property that is under construction on or before December 31, 2019. Projects placed in service after December 31, 2019, may also qualify for a 30 percent federal ITC if five percent or more of the total costs of a solar property are incurred before the end of the applicable year and there are continuous efforts to advance towards completion of the project, based on the IRS guidance around ITC safe harbor determination. The credit declined to 26 percent for property under construction before the end of 2020. The Consolidated Appropriations Act, 2021 extended the 26 percent tax credit for property under construction during 2021 and 2022. The credit will drop to 22 percent for property under construction before the end of 2023. After 2023 the ITC will be reduced to 10 percent.

LEASES

LEASES	6 Months Ended
	Mar. 31, 2022
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. After the criteria is satisfied, the Company accounts for these arrangements as leases in accordance with ASC 842, Leases . Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases. The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of its natural gas meters. Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns. Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five two seven 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. In July 2021, NJNG entered into 16-year lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation. 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 2022 2021 2022 2021 Operating lease cost (1) Operation and maintenance $ 2,915 1,356 $ 5,034 $ 3,445 Finance lease cost Amortization of right-of-use assets Depreciation and amortization $ 457 $ 1,191 853 2,437 Interest on lease liabilities Interest expense, net of capitalized interest 104 113 184 334 Total finance lease cost 561 1,304 1,037 2,771 Short-term lease cost Operation and maintenance 12 127 23 254 Variable lease cost Operation and maintenance 172 549 363 702 Total lease cost $ 3,660 $ 3,336 $ 6,457 $ 7,172 (1) Net of capitalized costs. The following table presents supplemental cash flow information related to leases: Six Months Ended March 31, (Thousands) 2022 2021 Cash paid for amounts included in the measurement of lease liabilities Operating cash flows for operating leases $ 3,557 $ 2,932 Operating cash flows for finance leases $ 404 $ 791 Financing cash flows for finance leases $ 3,947 $ 5,690 Assets obtained or modified for operating lease liabilities totaled approximately $17,000 and $5.7 million during the three months ended March 31, 2022 and 2021, respectively, and totaled $825,000 and $13.3 million during the six months ended March 31, 2022 and 2021, respectively. Assets obtained or modified through finance lease liabilities totaled $17.3 million during the six months ended March 31, 2022. There were no assets obtained or modified through finance lease liabilities during the three months ended March 31, 2022 and 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, 2022 September 30, Assets Noncurrent Operating lease assets Operating lease assets $ 171,207 $ 173,928 Finance lease assets Utility plant 22,828 13,489 Total lease assets $ 194,035 $ 187,417 Liabilities Current Operating lease liabilities Operating lease liabilities $ 4,878 $ 4,300 Finance lease liabilities Current maturities of long-term debt 6,443 5,393 Noncurrent Operating lease liabilities Operating lease liabilities 140,036 141,363 Finance lease liabilities Long-term debt 27,045 14,742 Total lease liabilities $ 178,402 $ 165,798 For operating lease assets and liabilities, the weighted average remaining lease term was 29.6 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.2 percent for both March 31, 2022 and September 30, 2021. For finance lease assets and liabilities as of March 31, 2022 and September 30, 2021, the weighted average remaining lease term was 4.5 years and 3.4 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.7 percent and 3.5 percent as of March 31, 2022 and September 30, 2021, respectively.
LEASES	12. LEASES Lessee Accounting The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset. After the criteria is satisfied, the Company accounts for these arrangements as leases in accordance with ASC 842, Leases . Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases. The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of its natural gas meters. Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns. Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five two seven 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. In July 2021, NJNG entered into 16-year lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation. 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 2022 2021 2022 2021 Operating lease cost (1) Operation and maintenance $ 2,915 1,356 $ 5,034 $ 3,445 Finance lease cost Amortization of right-of-use assets Depreciation and amortization $ 457 $ 1,191 853 2,437 Interest on lease liabilities Interest expense, net of capitalized interest 104 113 184 334 Total finance lease cost 561 1,304 1,037 2,771 Short-term lease cost Operation and maintenance 12 127 23 254 Variable lease cost Operation and maintenance 172 549 363 702 Total lease cost $ 3,660 $ 3,336 $ 6,457 $ 7,172 (1) Net of capitalized costs. The following table presents supplemental cash flow information related to leases: Six Months Ended March 31, (Thousands) 2022 2021 Cash paid for amounts included in the measurement of lease liabilities Operating cash flows for operating leases $ 3,557 $ 2,932 Operating cash flows for finance leases $ 404 $ 791 Financing cash flows for finance leases $ 3,947 $ 5,690 Assets obtained or modified for operating lease liabilities totaled approximately $17,000 and $5.7 million during the three months ended March 31, 2022 and 2021, respectively, and totaled $825,000 and $13.3 million during the six months ended March 31, 2022 and 2021, respectively. Assets obtained or modified through finance lease liabilities totaled $17.3 million during the six months ended March 31, 2022. There were no assets obtained or modified through finance lease liabilities during the three months ended March 31, 2022 and 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, 2022 September 30, Assets Noncurrent Operating lease assets Operating lease assets $ 171,207 $ 173,928 Finance lease assets Utility plant 22,828 13,489 Total lease assets $ 194,035 $ 187,417 Liabilities Current Operating lease liabilities Operating lease liabilities $ 4,878 $ 4,300 Finance lease liabilities Current maturities of long-term debt 6,443 5,393 Noncurrent Operating lease liabilities Operating lease liabilities 140,036 141,363 Finance lease liabilities Long-term debt 27,045 14,742 Total lease liabilities $ 178,402 $ 165,798 For operating lease assets and liabilities, the weighted average remaining lease term was 29.6 years and the weighted average discount rate used in the valuation over the remaining lease term was 3.2 percent for both March 31, 2022 and September 30, 2021. For finance lease assets and liabilities as of March 31, 2022 and September 30, 2021, the weighted average remaining lease term was 4.5 years and 3.4 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term is 2.7 percent and 3.5 percent as of March 31, 2022 and September 30, 2021, respectively.

COMMITMENTS AND CONTINGENT LIAB

COMMITMENTS AND CONTINGENT LIABILITIES	6 Months Ended
	Mar. 31, 2022
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 September 2039, for the supply, transportation and storage of natural gas. These contracts include annual fixed charges of approximately $199.5 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 Commitments as of March 31, 2022, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows: (Thousands) 2022 2023 2024 2025 2026 Thereafter Energy Services: Natural gas purchases $ 110,029 $ 17,096 $ — $ — $ — $ — Storage demand fees 11,881 20,416 12,256 6,434 3,789 3,027 Pipeline demand fees 36,564 59,876 41,802 27,037 26,359 32,082 Sub-total Energy Services $ 158,474 $ 97,388 $ 54,058 $ 33,471 $ 30,148 $ 35,109 NJNG: Natural gas purchases $ 55,151 $ 5,361 $ — $ — $ — $ — Storage demand fees 25,167 41,758 27,318 17,362 10,266 14,320 Pipeline demand fees 72,067 147,689 91,216 136,515 127,692 1,179,683 Sub-total NJNG $ 152,385 $ 194,808 $ 118,534 $ 153,877 $ 137,958 $ 1,194,003 Total $ 310,859 $ 292,196 $ 172,592 $ 187,348 $ 168,106 $ 1,229,112 Certain pipeline demand fees totaling approximately $4.0 million per year, for which Energy Services is the responsible party, are being paid for by the counterparty to a capacity release transaction beginning November 1, 2021 for a period of 10 years. Legal Proceedings Manufactured Gas Plant Remediation NJNG is responsible for the remedial cleanup of certain former MGP sites, dating back to gas operations in the late 1800s and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the NJDEP and participating in various studies and investigations by outside consultants, to determine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action, where warranted, under NJDEP regulations. NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester, Toms River, Freehold and Aberdeen, New Jersey, including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future expenditures at the former MGP sites for which it is responsible, including potential liabilities for natural resource damages that might be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites will range from approximately $115.7 million to $178.7 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of March 31, 2022, NJNG recorded a MGP remediation liability and a corresponding regulatory asset of approximately $121.6 million on the Unaudited Condensed Consolidated Balance Sheets based on the most likely amount. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and insurance recoveries, if any. In June 2019, NJNG initiated a preliminary assessment of a site in Aberdeen, New Jersey to determine prior ownership and if former MGP operations were active at the location. The preliminary assessment and site investigation activities are ongoing at the Aberdeen, NJ site location. The estimated costs to complete the preliminary assessment and site investigation phase are included in the MGP remediation liability and corresponding regulatory asset on the Unaudited Condensed Consolidated Balance Sheets at March 31, 2022 and September 30, 2021. NJNG will continue to gather information to determine whether the obligation exists to undertake remedial action, if any, and refine its estimate of potential costs for this site as more information becomes available. NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. On March 23, 2022, the BPU approved an increase in the RAC, which increased the pre-tax annual recovery from $11.1 million to $11.7 million, effective April 1, 2022. As of March 31, 2022, $65.5 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, the Company establishes accruals for litigation for those matters that present loss contingencies as to which it is both probable that a loss will be incurred and the amount of such loss can be reasonably estimated. The Company also discloses contingent matters for which there is a reasonable possibility of a loss. Based upon currently available information, the Company believes that the results of litigation that are currently pending, taken together, will not have a materially adverse effect on the Company’s financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts accrued. The foregoing statements about the Company’s litigation are based upon the Company’s judgments, assumptions and estimates and are necessarily subjective and uncertain. The Company has a number of threatened and pending litigation matters at various stages.

REPORTING SEGMENT AND OTHER OPE

REPORTING SEGMENT AND OTHER OPERATIONS DATA	6 Months Ended
	Mar. 31, 2022
Segment Reporting [Abstract]
REPORTING SEGMENT AND OTHER OPERATIONS DATA	14. REPORTING SEGMENT AND OTHER OPERATIONS DATA The Company organizes its businesses based on a combination of factors, including its products and its regulatory environment. As a result, the Company manages its businesses through the following reporting segments and other operations: the Natural Gas Distribution segment consists of regulated energy and off-system, capacity and storage management operations; the Clean Energy Ventures segment consists of capital investments in clean energy projects; the Energy Services segment consists of unregulated wholesale and retail energy operations; the Storage and Transportation segment consists of the Company’s investments in natural gas transportation and storage facilities; the Home Services and Other operations consist of heating, cooling and water appliance sales, installations and services, other investments and general corporate activities. Information related to the Company's various reporting segments and other operations is detailed below: Three Months Ended Six Months Ended March 31, March 31, (Thousands) 2022 2021 2022 2021 Operating revenues Natural Gas Distribution External customers $ 463,474 $ 310,167 $ 737,909 $ 505,896 Intercompany 338 — 675 — Clean Energy Ventures External customers 11,827 6,476 22,010 12,846 Energy Services External customers (1) 411,069 459,766 776,857 687,115 Intercompany 1,576 2,803 5,032 4,931 Storage and Transportation External customers 12,805 13,257 24,389 25,704 Intercompany 537 669 1,096 1,326 Subtotal 901,626 793,138 1,567,968 1,237,818 Home Services and Other External customers 13,141 12,521 26,993 24,931 Intercompany 81 252 180 419 Eliminations (2,532) (3,724) (6,983) (6,676) Total $ 912,316 $ 802,187 $ 1,588,158 $ 1,256,492 Depreciation and amortization Natural Gas Distribution $ 23,344 $ 19,475 $ 46,237 $ 38,644 Clean Energy Ventures 5,311 4,685 10,544 10,118 Energy Services (2) 32 13 60 55 Storage and Transportation 2,571 2,364 4,704 5,004 Subtotal 31,258 26,537 61,545 53,821 Home Services and Other 203 227 407 487 Eliminations (26) 84 (124) (98) Total $ 31,435 $ 26,848 $ 61,828 $ 54,210 Interest income (3) Natural Gas Distribution $ 191 $ 76 $ 384 $ 158 Clean Energy Ventures — 240 — 240 Storage and Transportation 381 851 758 1,545 Subtotal 572 1,167 1,142 1,943 Home Services and Other 147 127 302 259 Eliminations (231) (237) (455) (476) Total $ 488 $ 1,057 $ 989 $ 1,726 (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) 2022 2021 2022 2021 Interest expense, net of capitalized interest Natural Gas Distribution $ 10,764 $ 9,006 $ 21,759 $ 17,980 Clean Energy Ventures 5,395 5,266 10,822 10,300 Energy Services 795 575 1,470 1,255 Storage and Transportation 1,847 3,578 3,983 7,560 Subtotal 18,801 18,425 38,034 37,095 Home Services and Other 125 1,728 369 2,844 Total $ 18,926 $ 20,153 $ 38,403 $ 39,939 Income tax provision (benefit) Natural Gas Distribution $ 29,689 $ 15,622 $ 42,893 $ 23,989 Clean Energy Ventures (1,952) (2,714) (3,998) (5,800) Energy Services (790) 23,128 19,715 35,250 Storage and Transportation 714 873 1,057 1,519 Subtotal 27,661 36,909 59,667 54,958 Home Services and Other 256 (59) 502 59 Eliminations 893 2,207 (552) 1,481 Total $ 28,810 $ 39,057 $ 59,617 $ 56,498 Equity in earnings of affiliates Storage and Transportation $ 1,256 $ 3,386 $ 2,312 $ 6,579 Eliminations (487) (582) (968) (1,100) Total $ 769 $ 2,804 $ 1,344 $ 5,479 Net financial earnings (loss) Natural Gas Distribution $ 102,783 $ 80,541 $ 153,863 $ 130,008 Clean Energy Ventures (6,491) (8,872) (13,312) (19,146) Energy Services 29,940 96,528 47,507 98,028 Storage and Transportation 4,625 4,711 7,587 8,219 Subtotal 130,857 172,908 195,645 217,109 Home Services and Other 451 747 898 685 Eliminations (1,102) (3,051) (567) (2,533) Total $ 130,206 $ 170,604 $ 195,976 $ 215,261 Capital expenditures Natural Gas Distribution $ 52,000 $ 97,239 $ 125,464 $ 176,485 Clean Energy Ventures 41,176 18,549 66,556 40,884 Storage and Transportation 43,673 20,094 109,048 27,707 Subtotal 136,849 135,882 301,068 245,076 Home Services and Other 163 125 242 811 Total $ 137,012 $ 136,007 $ 301,310 $ 245,887 Investments in (return of capital from) equity investees Storage and Transportation $ (4,000) $ 196 $ (4,000) $ 482 Total $ (4,000) $ 196 $ (4,000) $ 482 The Company's assets for the various reporting segments and business operations are detailed below: (Thousands) March 31, September 30, Assets at end of period: Natural Gas Distribution $ 3,844,036 $ 3,707,461 Clean Energy Ventures 970,599 914,788 Energy Services 248,112 365,423 Storage and Transportation 965,615 862,407 Subtotal 6,028,362 5,850,079 Home Services and Other 136,300 162,134 Intercompany assets (1) (294,658) (289,935) Total $ 5,870,004 $ 5,722,278 (1) Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation. The Chief Executive Officer, who uses NFE as a measure of profit or loss in measuring the results of the Company's reporting segments and operations, is the chief operating decision maker of the Company. A reconciliation of consolidated NFE to consolidated net income is as follows: Three Months Ended Six Months Ended March 31, March 31, (Thousands) 2022 2021 2022 2021 Net financial earnings $ 130,206 $ 170,604 $ 195,976 $ 215,261 Less: Unrealized loss (gain) on derivative instruments and related transactions 42,022 29,255 (40,169) (8,235) Tax effect (9,980) (6,954) 9,556 1,958 Effects of economic hedging related to natural gas inventory 1,155 (7,209) 24,732 (14,741) Tax effect (274) 1,713 (5,877) 3,503 NFE tax adjustment 1,248 3,990 387 1,922 Net income $ 96,035 $ 149,809 $ 207,347 $ 230,854 The Company uses derivative instruments as economic hedges of purchases and sales of physical natural gas inventory. For GAAP purposes, these derivatives are recorded at fair value and related changes in fair value are included in reported earnings. Revenues and cost of natural gas related to physical natural gas flow are recognized when the natural gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical natural gas flows. Timing differences occur in two ways: • unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical natural gas inventory flows; and • unrealized gains and losses of prior periods are reclassified as realized gains and losses when derivatives are settled in the same period as physical natural gas inventory movements occur. NFE is a measure of the earnings based on eliminating these timing differences, to effectively match the earnings effects of the economic hedges with the physical sale of natural gas, SRECs and foreign currency contracts. Consequently, to reconcile between net income and NFE, current period unrealized gains and losses on the derivatives are excluded from NFE as a reconciling item. Realized derivative gains and losses are also included in current period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical natural gas flows. NFE also excludes impairment charges associated with equity method investments, which are non-cash charges considered unusual in nature that occur infrequently and are not indicative of the Company's performance for its ongoing operations. Included in the tax effects are current and deferred income tax expense corresponding with the components of NFE. The Company also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	6 Months Ended
	Mar. 31, 2022
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	15. RELATED PARTY TRANSACTIONS Effective April 1, 2020, NJNG entered into a 5-year agreement for 3 Bcf of firm storage capacity with Steckman Ridge, which expires on March 31, 2025. Under the terms of the agreement, NJNG incurs demand fees, at market rates, of approximately $9.3 million annually, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG’s BGSS mechanism and are included as a component of regulatory assets. Energy Services may periodically enter into storage or park and loan agreements with its affiliated FERC-jurisdictional natural gas storage facility, Steckman Ridge. As of March 31, 2022, Energy Services entered into transactions with Steckman Ridge for varying terms, all of which expire by March 31, 2024. Demand fees, net of eliminations, associated with Steckman Ridge were as follows: Three Months Ended Six Months Ended March 31, March 31, (Thousands) 2022 2021 2022 2021 Natural Gas Distribution $ 1,546 $ 1,505 $ 3,104 $ 3,073 Energy Services 337 226 625 391 Total $ 1,883 $ 1,731 $ 3,729 $ 3,464 The following table summarizes demand fees payable to Steckman Ridge as of: (Thousands) March 31, 2022 September 30, Natural Gas Distribution $ 779 $ 778 Energy Services 76 83 Total $ 855 $ 861 NJNG and Energy Services have entered into various AMAs, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. As of March 31, 2022, NJNG and Energy Services had one AMA with an expiration date of March 31, 2023. NJNG has entered into a 5-year transportation precedent agreement with Adelphia Gateway for committed capacity of 130,000 Dekatherms per day, which is expected to begin during the 2nd half of fiscal 2022. Energy Services has a 5-year agreement for 3 Bcf of firm storage capacity with Leaf River, which is eliminated in consolidation and expires in March 2024. In March 2021, NJNG and Clean Energy Ventures entered into a 15-year sublease and PPA agreement related to an onsite solar array and the related energy output at the Company’s headquarters in Wall, New Jersey, the effects of which are immaterial to the consolidated financial statements. In July 2021, NJNG entered into 16-year lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation.

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
Consolidation	The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by the Company in accordance with the rules and regulations of the U.S. Securities and Exchange Commission and GAAP. The September 30, 2021 Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in the Company's 2021 Annual Report on Form 10-K. The Unaudited Condensed Consolidated Financial Statements include the accounts of NJR and its subsidiaries. In the opinion of management, the accompanying Unaudited Condensed Consolidated Financial Statements reflect all adjustments necessary for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of the Company's utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ending September 30, 2022. Intercompany transactions and accounts have been eliminated.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires the Company to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosure of contingencies during the reporting period. On a quarterly basis or more frequently whenever events or changes in circumstances indicate a need, the Company evaluates its estimates, including those related to the calculation of the fair value of derivative instruments, debt, equity method investments, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, long-lived assets, regulatory assets and liabilities, income taxes, pensions and other postemployment benefits, contingencies related to environmental matters and litigation. Asset retirement obligations are evaluated as often as needed. The Company’s estimates are based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.
Revenues	Revenues Revenues from the sale of natural gas to NJNG customers are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for unbilled revenue. NJNG records unbilled revenue for natural gas services. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the month. At the end of each month, the amount of natural gas delivered to each customer after the last meter reading through the end of the respective accounting period is estimated, and recognizes unbilled revenues related to these amounts. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects, unaccounted-for natural gas and the most current tariff rates. Clean Energy Ventures recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the transfer of certificates as per contractual settlement schedules. The Clean Energy Act of 2018 established guidelines for the closure of the SREC registration program to new applicants in New Jersey. The SREC program officially closed to new qualified solar projects on April 30, 2020. In December 2019, the BPU established the TREC as the successor to the SREC program. TRECs provide a fixed compensation base multiplied by an assigned project factor in order to determine their value. The project factor is determined by the type and location of the project, as defined. All TRECs generated are required to be purchased monthly by a TREC program administrator as appointed by the BPU. TREC revenue is recognized when TRECs are generated and are transferred monthly based upon metered solar electricity activity. Revenues for Energy Services are recognized when the natural gas is physically delivered to the customer. In addition, changes in the fair value of derivatives that economically hedge the forecasted sales of the natural gas are recognized in operating revenues as they occur, as noted above. Energy Services also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues. During December 2020, Energy Services entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts, which commenced on November 1, 2021. The AMAs include a series of temporary and permanent releases and revenue under these agreements is recognized as the performance obligations are satisfied. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed upon term. For permanent releases of pipeline capacity, which represent a transfer of contractual rights for such capacity, revenue is recognized upon the transfer of the underlying contractual rights. Energy Services recognized $10.3 million and $32.4 million of operating revenue on the Unaudited Condensed Consolidated Statements of Operations during the three and six months ended March 31, 2022, respectively. Amounts received in excess of revenue totaling $54.4 million are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets as of March 31, 2022. The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, related usage fees and hub services for the use of storage space, injections and withdrawals from their natural gas storage facility and the delivery of natural gas to customers. Demand fees are recognized as revenue over the term of the related agreement while usage fees and hub services revenues are recognized as services are performed. Revenues from all other activities are recorded in the period during which products or services are delivered and accepted by customers, or over the related contractual term. See Note 3. Revenue for further information.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to irrevocable letters of credit at Leaf River and escrow balances for utility plant projects at NJNG, which are recorded in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets, respectively.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations, and macroeconomic factors, such as unemployment rates among others, including the estimated impact of the ongoing pandemic on the outstanding balances. In December 2021, the Company deferred a portion of costs incurred related to bad debt for NJNG associated with customer accounts receivable as a regulatory asset resulting from the impacts of the ongoing COVID-19 pandemic. See Note 4. Regulation for additional information.
Loans Receivable	Loans ReceivableNJNG currently provides loans, with terms ranging from two
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 $17.3 million during the six months ended March 31, 2022, 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 arrangement does not qualify as a sale as the Company retains control of the underlying assets and, as such, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the buyer-lessor that constitute a payment to acquire the solar energy asset as a financing arrangement, which is recorded as a component of debt on the Unaudited Condensed Consolidated Balance Sheets. The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from RECs and energy sales. The ITCs and other tax benefits associated with these solar projects transfer to the buyer; however, the payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax attributes. Accordingly, Clean Energy Ventures recognizes the equivalent value of the tax attributes in other income on the Unaudited Condensed Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. Clean Energy Ventures received proceeds of $3.3 million and $12.1 million during the six months ended March 31, 2022 and 2021, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Unaudited Condensed Consolidated Balance Sheets.
Recently Adopted Updates to the Accounting Standards Codification	Recently Adopted Updates to the Accounting Standards Codification Income Taxes In December 2019, the FASB issued ASU No. 2019-12, an amendment to ASC 740, Income Taxes , which simplifies the accounting for income taxes and changes the accounting for certain income tax transactions, among other minor improvements. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. The amendments in this update were either not applicable, currently applied, or did not have a material impact on the Company's financial position, results of operations, cash flows or disclosures. Investments - Equity Securities, Investments - Equity Method and Joint Ventures and Derivatives and Hedging In January 2020, the FASB issued ASU No. 2020-01, an amendment to ASC 321, Investments - Equity Securities, ASC 323 , Investments - Equity Method and Joint Ventures, and ASC 815 , Derivatives and Hedging, which clarifies the interactions between the three ASU topics. The update requires an entity to evaluate observable transactions that necessitate applying or discontinuing the equity method of accounting when applying the measurement alternative in Topic 321. This evaluation occurs prior to applying or upon ceasing the equity method. The update also states that when applying paragraph 815-10-15-141(a) for forward contracts and purchased options, an entity is not required to assess whether the underlying securities will be accounted for under the equity method in accordance with Topic 323 or fair value method under Topic 825 upon settlement or exercise. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures. Other In October 2020, the FASB issued ASU No. 2020-10, Codification Improvements , which clarifies application of various provisions in the ASC by amending and adding new headings, cross referencing to other guidance, and refining or correcting terminology. It also improves the consistency by amending the ASC to include all disclosure guidance in the appropriate section. The Company adopted this guidance on October 1, 2021, and applied it on a prospective basis. There was no material impact on the Company's financial position, results of operations, cash flows or disclosures. Other Recent Updates to the Accounting Standards Codification Debt and Other In August 2020, the FASB issued ASU No. 2020-06, an amendment to ASC 470, Debt , and ASC 815, Derivatives and Hedging , which changes the accounting for convertible instruments by reducing the number of acceptable accounting models to three models including, the embedded derivative, substantial premium, and traditional no proceeds allocated models. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it on either a modified or a full retrospective basis. The Company does not currently have convertible debt instruments and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption. In May 2021, the FASB issued ASU No. 2021-04, an amendment to ASC 470, Debt , ASC 260, Earnings per Share , ASC 718, Stock Compensation , and ASC 815, Derivatives and Hedging. The update impacts equity-classified written call options that remain equity-classified after a modification or exchange. The guidance is effective for the Company beginning October 1, 2022, and will be applied on a prospective basis. The Company does not currently have equity-classified written call options and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption. Leases In July 2021, the FASB issued ASU No. 2021-05, an amendment to ASC 842, Leases , which requires a lessor to classify a lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another classification, including sales-type or direct financing would trigger a loss at the lease commencement date. The guidance is effective for the Company beginning October 1, 2022, and the Company can elect to apply it either on a retrospective basis to leases that have commenced or have been modified under ASC 842 or on a prospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption. Business Combinations In October 2021, the FASB issued ASU No. 2021-08, an amendment to ASC 805, Business Combinations , which requires that an acquirer recognize, and measure contract assets and contract liabilities acquired in a business combination in accordance with Topic 606, Revenue from Contracts with Customers . The guidance is effective for the Company beginning October 1, 2023, and will be applied on a prospective basis to new acquisitions following the date of adoption. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption. Derivatives and Hedging In March 2022, the FASB issued ASU No. 2022-01, an amendment to ASC 815, Derivatives and Hedging , which addresses fair value hedge accounting of interest rate risk for portfolios of financial assets. This update further clarifies guidance previously released in ASU 2017-12 which established the "last-of-layer" method and this update renames that method to the “portfolio layer” method. The guidance is effective for the Company beginning October 1, 2023, and the transition method can be on a prospective basis for a multiple-layer hedging strategy or a modified retrospective basis for a portfolio layer method. The Company does not currently apply hedge accounting to any of its risk management activities and thus does not expect the amendments to have an impact on its financial position, results of operations, cash flows and disclosures upon adoption. Financial Instruments In March 2022, the FASB issued ASU No. 2022-02, an amendment to ASC 326, Financial Instruments-Credit Losses , which eliminates the accounting guidance for creditors in troubled debt restructuring. It also aligns conflicting disclosure requirement guidance in ASC 326 by requiring disclosure of current-period gross write-offs by year of origination. The amendment also adds new disclosures for creditors with loan refinancing and restructuring for borrowers experiencing financial difficulty. The guidance is effective for the Company beginning October 1, 2023, and the Company can elect to apply it either on a modified retrospective or prospective basis. At this time, the Company has not experienced a troubled debt restructuring and thus does not expect the amendments to have an impact on its financial position, results of operations and cash flows upon adoption. The Company is currently evaluating the amendments to understand the impact on its disclosures upon adoption.
Derivative Instruments	The Company is subject primarily to commodity price risk due to fluctuations in the market price of natural gas, SRECs and electricity. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs and electricity. In addition, the Company is exposed to foreign currency and interest rate risk and may utilize foreign currency derivatives to hedge Canadian dollar denominated natural gas purchases and/or sales and interest rate derivatives to reduce exposure to fluctuations in interest rates. All of these types of contracts are accounted for as derivatives, unless the Company elects NPNS, which is done on a contract-by-contract election. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company’s fair value measurement policies and level disclosures associated with the Company’s derivative instruments, see Note 6. Fair Value . Energy Services Energy Services chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS. The changes in the fair value of these derivatives are recorded as a component of natural gas purchases or operating revenues, as appropriate for Energy Services, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of natural gas purchases and realized gains and losses on all physical derivatives follow the presentation of the related unrealized gains and losses as a component of either natural gas purchases or operating revenues. Energy Services also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the U.S. dollar. Energy Services may utilize foreign currency derivatives to lock in the exchange rates associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are typically used to hedge demand fee payments on pipeline capacity, storage and natural gas purchase agreements. As a result of Energy Services entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed natural gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings. Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. Energy Services recognizes changes in the fair value of these derivatives as a component of operating revenues. Upon settlement of the contract, the related revenue is recognized when the SREC is transferred to the counterparty. Natural Gas Distribution Changes in fair value of NJNG's financial commodity derivatives are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis. Accordingly, physical natural gas purchases are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered. The average cost of natural gas is charged to expense in the current period earnings based on the BGSS factor times the therm sales. Effective for contracts executed on or after January 1, 2016, NJNG no longer elects NPNS accounting treatment on a portfolio basis. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as normal. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for natural gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. Clean Energy Ventures The Company elects NPNS accounting treatment on PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to do so, the Company can and may elect to treat certain contracts as normal.
Fair Value Hierarchy	Fair Value Hierarchy The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, investments in equity securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following: Level 1 Unadjusted quoted prices for identical assets or liabilities in active markets. The Company's Level 1 assets and liabilities include exchange traded natural gas futures and options contracts, listed equities and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX, CME and ICE that the Company refers to internally as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM. Level 2 Other significant observable inputs such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company's Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is: • widely accepted and public; • non-proprietary and sourced from an independent third party; and • observable and published. These additional adjustments are generally not considered to be significant to the ultimate recognized values. Level 3 Inputs derived from a significant amount of unobservable market data. These include the Company's best estimate of fair value and are derived primarily through the use of internal valuation methodologies.
Lessee Accounting	Lessee Accounting The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset. After the criteria is satisfied, the Company accounts for these arrangements as leases in accordance with ASC 842, Leases . Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases. The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of its natural gas meters. Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns. Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five two seven 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. In July 2021, NJNG entered into 16-year lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	6 Months Ended
	Mar. 31, 2022
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, 2022 September 30, March 31, Balance Sheet Cash and cash equivalents $ 13,906 $ 4,749 $ 57,654 Restricted cash in other noncurrent assets $ 1,294 $ 1,294 $ 1,321 Statements of Cash Flow Cash, cash equivalents and restricted cash $ 15,200 $ 6,043 $ 58,975
Summary of Natural Gas in Storage	The following table summarizes natural gas in storage, at average cost by segment as of: March 31, 2022 September 30, 2021 ($ in thousands) Natural Gas in Storage Bcf Natural Gas in Storage Bcf Natural Gas Distribution $ 31,066 4.9 $ 115,824 27.6 Energy Services 35,234 7.4 77,782 18.8 Total $ 66,300 12.3 $ 193,606 46.4
Schedule of Software Costs Included in the Consolidated Financial Statements	The following tables present the software costs included in the Unaudited Condensed Consolidated Financial Statements: (Thousands) March 31, 2022 September 30, Balance Sheets Utility plant, at cost $ 16,959 $ 16,543 Construction work in progress $ 20,752 $ 7,801 Nonutility plant and equipment, at cost $ 344 $ 338 Construction work in progress $ — $ 8 Accumulated depreciation and amortization, utility plant $ (1,944) $ (1,333) Accumulated depreciation and amortization, nonutility plant and equipment $ (19) $ (29) Software costs $ 5,714 $ 5,582 Three Months Ended Six Months Ended March 31, March 31, Statements of Operations 2022 2021 2022 2021 Operation and maintenance (1) $ 2,828 $ 2,847 $ 5,351 $ 4,770 Depreciation and amortization $ 303 $ 270 $ 602 $ 523 (1) During the three and six months ended March 31, 2022, approximately $113,000 and $225,000, respectively, was amortized from software costs into O&M. During the three and six months ended March 31, 2021, approximately $111,000 and $188,000, respectively, was amortized from software costs into O&M.
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents the changes in the components of accumulated other comprehensive (loss) income, net of related tax effects during the three months ended March 31, 2022 and 2021: (Thousands) Cash Flow Hedges Postemployment Benefit Obligation Total Balance at December 31, 2021 $ (9,112) $ (24,386) $ (33,498) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(80), $(232), $(312), respectively 263 768 (1) 1,031 Balance at March 31, 2022 $ (8,849) $ (23,618) $ (32,467) Balance at December 31, 2020 $ (10,166) $ (33,106) $ (43,272) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(79), $(244), $(323) 263 813 (1) 1,076 Balance at March 31, 2021 $ (9,903) $ (32,293) $ (42,196) 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, 2022 and 2021: (Thousands) Cash Flow Hedges Postemployment Benefit Obligation Total Balance at September 30, 2021 $ (9,376) $ (25,152) $ (34,528) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(159), $(465), $(624), respectively 527 1,534 (1) 2,061 Balance at March 31, 2022 $ (8,849) $ (23,618) $ (32,467) Balance at September 30, 2020 $ (10,397) $ (33,918) $ (44,315) Other comprehensive income, net of tax Amounts reclassified from accumulated other comprehensive loss, net of tax of $(191), $(489) and $(680) 494 1,625 (1) 2,119 Balance at March 31, 2021 $ (9,903) $ (32,293) $ (42,196) (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.

REVENUE (Tables)

REVENUE (Tables)	6 Months Ended
	Mar. 31, 2022
Revenue from Contract with Customer [Abstract]
Performance Obligation, Recognition Period	Below is a listing of performance obligations that arise from contracts with customers, along with details on the satisfaction of each performance obligation, the significant payment terms and the nature of the goods and services being transferred, by reporting segment and other business operations: Revenue Recognized Over Time: Segment Performance Obligation Description Natural Gas Distribution Natural gas utility sales NJNG's performance obligation is to provide natural gas to residential, commercial and industrial customers as demanded, based on regulated tariff rates, which are established by the BPU. Revenues from the sale of natural gas are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for quantities consumed but not billed during the period. Payment is due each month for the previous month's deliveries. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the billing period. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects and the most current tariff rates. NJNG is entitled to be compensated for performance completed until service is terminated. Customers may elect to purchase the natural gas commodity from NJNG or may contract separately to purchase natural gas directly from third-party suppliers. As NJNG is acting as an agent on behalf of the third-party supplier, revenue is recorded for the delivery of natural gas to the customer. Clean Energy Ventures Commercial solar electricity Clean Energy Ventures operates wholly-owned solar projects that recognize revenue as electricity is generated and transferred to the customer. The performance obligation is to provide electricity to the customer in accordance with contract terms or the interconnection agreement and is satisfied upon transfer of electricity generated. Revenue is recognized as invoiced and the payment is due each month for the previous month's services. Clean Energy Ventures Residential solar electricity Clean Energy Ventures provides access to residential rooftop and ground-mount solar equipment to customers who then pay the Company a monthly fee. The performance obligation is to provide electricity to the customer based on generation from the underlying residential solar asset and is satisfied upon transfer of electricity generated. Revenue is derived from the contract terms and is recognized as invoiced, with the payment due each month for the previous month's services. Clean Energy Ventures Transition renewable energy certificates Clean Energy Ventures generates TRECs, which are created for every MWh of electricity produced by a solar generator. The performance obligation of Clean Energy Ventures is to generate electricity and TRECs, which are purchased monthly by a REC Administrator. Revenue is recognized upon generation. Energy Services Natural gas services The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers in line with the terms of the contract and based on the services provided. Payment is due upon receipt of the invoice. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed upon term. Storage and Transportation Natural gas services The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from firm storage contracts and transportation contracts, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as customers receive the benefits of its service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement. Home Services and Other Service contracts Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice. Revenue Recognized at a Point in Time: Energy Services Natural gas services For a permanent release of pipeline capacity, the performance obligation of NJRES is the release of the pipeline capacity associated with certain natural gas transportation contracts and the transfer of the underlying contractual rights to the counterparty. Revenue is recognized upon the transfer of the underlying contractual rights. Storage and Transportation Natural gas services The performance obligation of the Storage and Transportation segment is to provide the customer with storage and transportation services. The Storage and Transportation segment generates revenues from usage fees and hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Usage fees and hub services revenues are recognized as services are performed. Home Services and Other Installations Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators to customers. The distinct performance obligation is the installation of the contracted appliance, which is satisfied at the point in time the item is installed. The transaction price for each installation differs accordingly. Revenue is recognized at a point in time upon completion of the installation, which is when the customer is billed.
Disaggregation of Revenue	Disaggregated revenues from contracts with customers by product line and by reporting segment and other business operations during the three months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Natural gas utility sales $ 381,861 — — — — $ 381,861 Natural gas services — — 17,309 13,342 — 30,651 Service contracts — — — — 8,492 8,492 Installations and maintenance — — — — 4,730 4,730 Renewable energy certificates — 1,019 — — — 1,019 Electricity sales — 6,846 — — — 6,846 Eliminations (1) (338) — — (537) (81) (956) Revenues from contracts with customers 381,523 7,865 17,309 12,805 13,141 432,643 Alternative revenue programs (2) 2,504 — — — — 2,504 Derivative instruments 79,447 3,962 (3) 395,336 — — 478,745 Eliminations (1) — — (1,576) — — (1,576) Revenues out of scope 81,951 3,962 393,760 — — 479,673 Total operating revenues $ 463,474 11,827 411,069 12,805 13,141 $ 912,316 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 (1) Includes building rent related to the Wall headquarters, which is eliminated in consolidation. (2) Consists of transactions between subsidiaries that are eliminated in consolidation. (3) Includes CIP revenue. (4) Includes SREC revenue. Disaggregated revenues from contracts with customers by product line and by reporting segment and other business operations during the six months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Natural gas utility sales (1) $ 605,657 — — — — $ 605,657 Natural gas services — — 45,188 25,485 — 70,673 Service contracts — — — — 16,959 16,959 Installations and maintenance — — — — 10,214 10,214 Renewable energy certificates — 1,865 — — — 1,865 Electricity sales — 13,316 — — — 13,316 Eliminations (2) (675) — — (1,096) (180) (1,951) Revenues from contracts with customers 604,982 15,181 45,188 24,389 26,993 716,733 Alternative revenue programs (3) 13,158 — — — — 13,158 Derivative instruments 119,769 6,829 (4) 736,701 — — 863,299 Eliminations (2) — — (5,032) — — (5,032) Revenues out of scope 132,927 6,829 731,669 — — 871,425 Total operating revenues $ 737,909 22,010 776,857 24,389 26,993 $ 1,588,158 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 (3) (5,096) — — — — (5,096) Derivative instruments 24,740 2,069 (4) 674,607 — — 24,740 Eliminations (2) — — (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 (1) Includes building rent related to the Wall headquarters, which is eliminated in consolidation. (2) Consists of transactions between subsidiaries that are eliminated in consolidation. (3) Includes CIP revenue. (4) Includes SREC revenue. Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the three months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Residential $ 286,205 2,991 — — 13,105 $ 302,301 Commercial and industrial 60,106 4,874 17,309 12,805 36 95,130 Firm transportation 34,636 — — — — 34,636 Interruptible and off-tariff 576 — — — — 576 Revenues out of scope 81,951 3,962 393,760 — — 479,673 Total operating revenues $ 463,474 11,827 411,069 12,805 13,141 $ 912,316 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 Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the six months ended March 31, 2022 and 2021, are as follows: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total 2022 Residential $ 437,513 5,963 — — 26,880 $ 470,356 Commercial and industrial 107,290 9,218 45,188 24,389 113 186,198 Firm transportation 57,311 — — — — 57,311 Interruptible and off-tariff 2,868 — — — — 2,868 Revenues out of scope 132,927 6,829 731,669 — — 871,425 Total operating revenues $ 737,909 22,010 776,857 24,389 26,993 $ 1,588,158 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
Expected Timing of Performance	The timing of revenue recognition, customer billings and cash collections resulting in accounts receivables, billed and unbilled, and customers’ credit balances and deposits on the Unaudited Condensed Consolidated Balance Sheets during the six months ended March 31, 2022 and 2021, are as follows: Customer Accounts Receivable Customers' Credit (Thousands) Billed Unbilled Balances and Deposits Balance as of September 30, 2021 $ 212,838 $ 10,351 $ 32,586 Increase (Decrease) 60,475 45,919 (12,302) Balance as of March 31, 2022 $ 273,313 $ 56,270 $ 20,284 Balance as of September 30, 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, 2022 and September 30, 2021: (Thousands) Natural Gas Distribution Clean Energy Ventures Energy Services Storage and Transportation Home Services Total March 31, 2022 Customer accounts receivable Billed $ 154,380 5,239 107,262 4,385 2,047 $ 273,313 Unbilled 54,675 1,595 — — — 56,270 Customers' credit balances and deposits (20,284) — — — — (20,284) Total $ 188,771 6,834 107,262 4,385 2,047 $ 309,299 September 30, 2021 Customer accounts receivable Billed $ 54,514 5,534 147,087 3,956 1,747 $ 212,838 Unbilled 8,427 1,924 — — — 10,351 Customers' credit balances and deposits (32,586) — — — — (32,586) Total $ 30,355 7,458 147,087 3,956 1,747 $ 190,603

REGULATION (Tables)

REGULATION (Tables)	6 Months Ended
	Mar. 31, 2022
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, 2022 September 30, Regulatory assets-current New Jersey Clean Energy Program $ 6,608 $ 16,308 Conservation Incentive Program 24,997 11,839 Other current regulatory assets 1,241 1,554 Total current regulatory assets $ 32,846 $ 29,701 Regulatory assets-noncurrent Environmental remediation costs: Expended, net of recoveries $ 65,523 $ 58,483 Liability for future expenditures 121,615 135,012 Deferred income taxes 39,857 39,694 SAVEGREEN 33,917 32,941 Postemployment and other benefit costs 111,918 117,194 Deferred storm damage costs 3,257 4,343 Cost of removal 100,423 99,238 Other noncurrent regulatory assets 32,040 32,695 Total noncurrent regulatory assets $ 508,550 $ 519,600 Regulatory liability-current Overrecovered natural gas costs $ 27,133 $ 5,510 Derivatives at fair value, net 60,931 22,497 Total current regulatory liabilities $ 88,064 $ 28,007 Regulatory liabilities-noncurrent Tax Act impact (1) $ 187,876 $ 190,386 Derivatives at fair value, net — 1,166 Other noncurrent regulatory liabilities 590 336 Total noncurrent regulatory liabilities $ 188,466 $ 191,888 (1) Reflects the re-measurement and subsequent amortization of NJNG's net deferred tax liabilities as a result of the change in federal tax rates enacted in the Tax Act, 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. Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets for Adelphia Gateway are comprised of the following: (Thousands) March 31, September 30, Total current regulatory assets $ 871 $ 417 Total noncurrent regulatory assets $ 4,456 $ 2,499 Total noncurrent regulatory liabilities $ 2,984 $ 1,163
Schedule of Regulatory Assets	Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets for NJNG are comprised of the following: (Thousands) March 31, 2022 September 30, Regulatory assets-current New Jersey Clean Energy Program $ 6,608 $ 16,308 Conservation Incentive Program 24,997 11,839 Other current regulatory assets 1,241 1,554 Total current regulatory assets $ 32,846 $ 29,701 Regulatory assets-noncurrent Environmental remediation costs: Expended, net of recoveries $ 65,523 $ 58,483 Liability for future expenditures 121,615 135,012 Deferred income taxes 39,857 39,694 SAVEGREEN 33,917 32,941 Postemployment and other benefit costs 111,918 117,194 Deferred storm damage costs 3,257 4,343 Cost of removal 100,423 99,238 Other noncurrent regulatory assets 32,040 32,695 Total noncurrent regulatory assets $ 508,550 $ 519,600 Regulatory liability-current Overrecovered natural gas costs $ 27,133 $ 5,510 Derivatives at fair value, net 60,931 22,497 Total current regulatory liabilities $ 88,064 $ 28,007 Regulatory liabilities-noncurrent Tax Act impact (1) $ 187,876 $ 190,386 Derivatives at fair value, net — 1,166 Other noncurrent regulatory liabilities 590 336 Total noncurrent regulatory liabilities $ 188,466 $ 191,888 (1) Reflects the re-measurement and subsequent amortization of NJNG's net deferred tax liabilities as a result of the change in federal tax rates enacted in the Tax Act, 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. Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets for Adelphia Gateway are comprised of the following: (Thousands) March 31, September 30, Total current regulatory assets $ 871 $ 417 Total noncurrent regulatory assets $ 4,456 $ 2,499 Total noncurrent regulatory liabilities $ 2,984 $ 1,163

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	6 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair Value of Derivative Assets and Liabilities	The following table presents the fair value of the Company's derivative assets and liabilities recognized on the Unaudited Condensed Consolidated Balance Sheets as of: Derivatives at Fair Value March 31, 2022 September 30, 2021 (Thousands) Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives not designated as hedging instruments: Natural Gas Distribution: Physical commodity contracts Derivatives - current $ 101 $ 16 $ 36 $ 16 Financial commodity contracts Derivatives - current 111 1,887 2,046 13 Energy Services: Physical commodity contracts Derivatives - current 1,853 21,594 2,818 24,592 Derivatives - noncurrent 131 19,632 333 13,237 Financial commodity contracts Derivatives - current 19,483 21,701 30,226 62,521 Derivatives - noncurrent 4,009 — 3,068 260 Foreign currency contracts Derivatives - current 38 18 125 3 Derivatives - noncurrent — — 2 — Total fair value of derivatives $ 25,726 $ 64,848 $ 38,654 $ 100,642
Offsetting Assets	The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral, as well as the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to. (Thousands) Amounts Presented on Balance Sheets (1) Offsetting Derivative Instruments (2) Financial Collateral Received/Pledged (3) Net Amounts (4) As of March 31, 2022: Derivative assets: Energy Services Physical commodity contracts $ 1,984 $ (480) $ (200) $ 1,304 Financial commodity contracts 23,492 (18,300) — 5,192 Foreign currency contracts 38 (18) — 20 Total Energy Services $ 25,514 $ (18,798) $ (200) $ 6,516 Natural Gas Distribution Physical commodity contracts $ 101 $ (8) $ — $ 93 Financial commodity contracts 111 (111) — — Total Natural Gas Distribution $ 212 $ (119) $ — $ 93 Derivative liabilities: Energy Services Physical commodity contracts $ 41,226 $ (480) $ — $ 40,746 Financial commodity contracts 21,701 (18,300) — 3,401 Foreign currency contracts 18 (18) — — Total Energy Services $ 62,945 $ (18,798) $ — $ 44,147 Natural Gas Distribution Physical commodity contracts $ 16 $ (8) $ — $ 8 Financial commodity contracts 1,887 (111) — 1,776 Total Natural Gas Distribution $ 1,903 $ (119) $ — $ 1,784 As of September 30, 2021: Derivative assets: Energy Services Physical commodity contracts $ 3,151 $ (894) $ (700) $ 1,557 Financial commodity contracts 33,294 (33,294) 20,532 20,532 Foreign currency contracts 127 (3) — 124 Total Energy Services $ 36,572 $ (34,191) $ 19,832 $ 22,213 Natural Gas Distribution Physical commodity contracts $ 36 $ (8) $ — $ 28 Financial commodity contracts 2,046 (13) — 2,033 Total Natural Gas Distribution $ 2,082 $ (21) $ — $ 2,061 Derivative liabilities: Energy Services Physical commodity contracts $ 37,829 $ (894) $ — $ 36,935 Financial commodity contracts 62,781 (33,294) — 29,487 Foreign currency contracts 3 (3) — — Total Energy Services $ 100,613 $ (34,191) $ — $ 66,422 Natural Gas Distribution Physical commodity contracts $ 16 $ (8) $ — $ 8 Financial commodity contracts 13 (13) — — Total Natural Gas Distribution $ 29 $ (21) $ — $ 8 (1) Derivative assets and liabilities are presented on a gross basis on the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20. (2) Includes transactions with NAESB netting election, transactions held by FCMs with net margining and transactions with ISDA netting. (3) Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties. (4) Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.
Offsetting Liabilities	The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral, as well as the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to. (Thousands) Amounts Presented on Balance Sheets (1) Offsetting Derivative Instruments (2) Financial Collateral Received/Pledged (3) Net Amounts (4) As of March 31, 2022: Derivative assets: Energy Services Physical commodity contracts $ 1,984 $ (480) $ (200) $ 1,304 Financial commodity contracts 23,492 (18,300) — 5,192 Foreign currency contracts 38 (18) — 20 Total Energy Services $ 25,514 $ (18,798) $ (200) $ 6,516 Natural Gas Distribution Physical commodity contracts $ 101 $ (8) $ — $ 93 Financial commodity contracts 111 (111) — — Total Natural Gas Distribution $ 212 $ (119) $ — $ 93 Derivative liabilities: Energy Services Physical commodity contracts $ 41,226 $ (480) $ — $ 40,746 Financial commodity contracts 21,701 (18,300) — 3,401 Foreign currency contracts 18 (18) — — Total Energy Services $ 62,945 $ (18,798) $ — $ 44,147 Natural Gas Distribution Physical commodity contracts $ 16 $ (8) $ — $ 8 Financial commodity contracts 1,887 (111) — 1,776 Total Natural Gas Distribution $ 1,903 $ (119) $ — $ 1,784 As of September 30, 2021: Derivative assets: Energy Services Physical commodity contracts $ 3,151 $ (894) $ (700) $ 1,557 Financial commodity contracts 33,294 (33,294) 20,532 20,532 Foreign currency contracts 127 (3) — 124 Total Energy Services $ 36,572 $ (34,191) $ 19,832 $ 22,213 Natural Gas Distribution Physical commodity contracts $ 36 $ (8) $ — $ 28 Financial commodity contracts 2,046 (13) — 2,033 Total Natural Gas Distribution $ 2,082 $ (21) $ — $ 2,061 Derivative liabilities: Energy Services Physical commodity contracts $ 37,829 $ (894) $ — $ 36,935 Financial commodity contracts 62,781 (33,294) — 29,487 Foreign currency contracts 3 (3) — — Total Energy Services $ 100,613 $ (34,191) $ — $ 66,422 Natural Gas Distribution Physical commodity contracts $ 16 $ (8) $ — $ 8 Financial commodity contracts 13 (13) — — Total Natural Gas Distribution $ 29 $ (21) $ — $ 8 (1) Derivative assets and liabilities are presented on a gross basis on the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20. (2) Includes transactions with NAESB netting election, transactions held by FCMs with net margining and transactions with ISDA netting. (3) Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties. (4) Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.
Effect of Derivative Instruments on Consolidated Statements of Operations	The following table presents the effect of derivative instruments recognized on the Unaudited Condensed Consolidated Statements of Operations for the periods set forth below: (Thousands) Location of gain (loss) recognized in income on derivatives Amount of gain (loss) recognized Three Months Ended Six Months Ended March 31, March 31, Derivatives not designated as hedging instruments: 2022 2021 2022 2021 Energy Services: Physical commodity contracts Operating revenues $ (11,582) $ 36,419 $ (11,432) $ 41,671 Physical commodity contracts Natural gas purchases (875) 2,650 630 (2,404) Financial commodity contracts Natural gas purchases (31,223) (27,315) 29,966 20,440 Foreign currency contracts Natural gas purchases (14) 27 (14) 227 Total unrealized and realized (gain) loss $ (43,694) $ 11,781 $ 19,150 $ 59,934
Effect of Derivative Instruments Designated as Cash Flow Hedges on OCI	The following table reflects the gains (losses) associated with NJNG's derivative instruments for the periods set forth below: Three Months Ended Six Months Ended March 31, March 31, (Thousands) 2022 2021 2022 2021 Natural Gas Distribution: Physical commodity contracts $ 4,538 $ 1,091 $ 6,234 $ 1,433 Financial commodity contracts 61,485 645 46,838 (3,627) Total unrealized and realized gain (loss) $ 66,023 $ 1,736 $ 53,072 $ (2,194)
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, 2022 September 30, Natural Gas Distribution Futures 29.6 22.2 Physical Commodity 12.8 7.6 Energy Services Futures (0.7) (13.4) Swaps (0.2) (0.3) Physical Commodity 7.5 0.6
Schedule of Broker Margin Accounts by Company	The balances are as follows: (Thousands) Balance Sheet Location March 31, 2022 September 30, Natural Gas Distribution Restricted broker margin accounts-current assets $ 11,617 $ 2,790 Energy Services Restricted broker margin accounts-current assets $ 38,284 $ 70,050 Restricted broker margin accounts-current liabilities $ (2,464) $ —
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, 2022. 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 $ 128,926 Noninvestment grade 9,601 Internally rated investment grade 20,566 Internally rated noninvestment grade 22,225 Total $ 181,318

FAIR VALUE (Tables)

FAIR VALUE (Tables)	6 Months Ended
	Mar. 31, 2022
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, 2022 September 30, Carrying value (1) (2) (3) $ 2,202,845 $ 2,102,845 Fair market value $ 2,137,966 $ 2,288,544 (1) Excludes finance leases of $33.5 million and $20.1 million as of March 31, 2022 and September 30, 2021, respectively. (2) Excludes NJNG's debt issuance costs of $10.1 million and $9.1 million as of March 31, 2022 and September 30, 2021, respectively. (3) Excludes NJR's debt issuance costs of $3.6 million and $3.3 million as of March 31, 2022 and September 30, 2021, respectively.
Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis	Assets and liabilities measured at fair value on a recurring basis are summarized as follows: Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs (Thousands) (Level 1) (Level 2) (Level 3) Total As of March 31, 2022: Assets: Physical commodity contracts $ — $ 2,085 $ — $ 2,085 Financial commodity contracts 23,603 — — 23,603 Financial commodity contracts - foreign exchange — 38 — 38 Money market funds 39 — — 39 Other 1,998 — — 1,998 Total assets at fair value $ 25,640 $ 2,123 $ — $ 27,763 Liabilities: Physical commodity contracts $ — $ 41,242 $ — $ 41,242 Financial commodity contracts 23,050 538 — 23,588 Financial commodity contracts - foreign exchange — 18 — 18 Total liabilities at fair value $ 23,050 $ 41,798 $ — $ 64,848 Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs (Thousands) (Level 1) (Level 2) (Level 3) Total As of September 30, 2021: Assets: Physical commodity contracts $ — $ 3,187 $ — $ 3,187 Financial commodity contracts 35,340 — — 35,340 Financial commodity contracts - foreign exchange — 127 — 127 Money market funds 41 — — 41 Other 1,815 — — 1,815 Total assets at fair value $ 37,196 $ 3,314 $ — $ 40,510 Liabilities: Physical commodity contracts $ — $ 37,845 $ — $ 37,845 Financial commodity contracts 62,188 606 — 62,794 Financial commodity contracts - foreign exchange — 3 — 3 Total liabilities at fair value $ 62,188 $ 38,454 $ — $ 100,642

INVESTMENTS IN EQUITY INVESTE_2

INVESTMENTS IN EQUITY INVESTEES (Tables)	6 Months Ended
	Mar. 31, 2022
Investments, All Other Investments [Abstract]
Schedule of Equity Method Investments	The Company's investments in equity method investees include the following as of: (Thousands) March 31, 2022 September 30, Steckman Ridge (1) $ 108,501 $ 109,050 PennEast 1,479 5,479 Total $ 109,980 $ 114,529 (1) Includes loans with a total outstanding principal balance of $70.4 million for both March 31, 2022 and September 30, 2021, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	6 Months Ended
	Mar. 31, 2022
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) 2022 2021 2022 2021 Net income, as reported $ 96,035 $ 149,809 $ 207,347 $ 230,854 Basic earnings per share Weighted average shares of common stock outstanding-basic 96,068 96,248 96,006 96,181 Basic earnings per common share $1.00 $1.56 $2.16 $2.40 Diluted earnings per share Weighted average shares of common stock outstanding-basic 96,068 96,248 96,006 96,181 Incremental shares (1) 448 370 474 417 Weighted average shares of common stock outstanding-diluted 96,516 96,618 96,480 96,598 Diluted earnings per common share (2) $1.00 $1.55 $2.15 $2.39 (1) Incremental shares consist primarily of unvested stock awards and performance shares. (2) There were anti-dilutive shares of 24,101 and 65,334 excluded from the calculation of diluted earnings per share related to an equity forward sale agreement during the three and six months ended March 31, 2021, respectively.

DEBT (Tables)

DEBT (Tables)	6 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	A summary of NJR's credit facility and term loan credit agreement and NJNG's commercial paper program and credit facility are as follows: (Thousands) March 31, 2022 September 30, Expiration Dates NJR Bank revolving credit facility (1) $ 500,000 $ 500,000 September 2026 Notes outstanding at end of period $ 152,210 $ 219,100 Weighted average interest rate at end of period 2.02 % 1.05 % Amount available at end of period (2) $ 334,325 $ 270,312 Bank term loan credit agreement $ 150,000 $ — February 2023 Loans outstanding at end of period $ 150,000 $ — Weighted average interest rate at end of period 1.04 % — % Amount available at end of period $ — $ — NJNG Bank revolving credit facility (3) $ 250,000 $ 250,000 September 2026 Commercial paper and notes outstanding at end of period $ — $ 158,200 Weighted average interest rate at end of period — % 0.17 % Amount available at end of period (4) $ 249,269 $ 91,069 (1) Committed credit facilities, which require commitment fees of 0.10 percent on the unused amounts. (2) Letters of credit outstanding total $13.5 million at March 31, 2022 and $10.6 million at September 30, 2021, which reduces the amount available by the same amount. (3) Committed credit facilities, which require commitment fees of 0.075 percent on the unused amounts. (4) Letters of credit outstanding total $731,000 at both March 31, 2022 and September 30, 2021, which reduces the amount available by the same amount.

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	6 Months Ended
	Mar. 31, 2022
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) 2022 2021 2022 2021 2022 2021 2022 2021 Service cost $ 2,073 $ 2,183 $ 4,146 $ 4,365 $ 1,076 $ 1,211 $ 2,152 $ 2,422 Interest cost 2,408 2,278 4,816 4,556 1,589 1,517 3,178 3,035 Expected return on plan assets (5,318) (4,851) (10,637) (10,075) (1,894) (1,565) (3,788) (3,248) Recognized actuarial loss 2,186 2,861 4,372 5,723 1,421 1,978 2,842 3,955 Prior service cost (credit) amortization 26 26 51 51 (36) (45) (72) (90) Net periodic benefit cost $ 1,375 $ 2,497 $ 2,748 $ 4,620 $ 2,156 $ 3,096 $ 4,312 $ 6,074

LEASES (Tables)

LEASES (Tables)	6 Months Ended
	Mar. 31, 2022
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 2022 2021 2022 2021 Operating lease cost (1) Operation and maintenance $ 2,915 1,356 $ 5,034 $ 3,445 Finance lease cost Amortization of right-of-use assets Depreciation and amortization $ 457 $ 1,191 853 2,437 Interest on lease liabilities Interest expense, net of capitalized interest 104 113 184 334 Total finance lease cost 561 1,304 1,037 2,771 Short-term lease cost Operation and maintenance 12 127 23 254 Variable lease cost Operation and maintenance 172 549 363 702 Total lease cost $ 3,660 $ 3,336 $ 6,457 $ 7,172 (1) Net of capitalized costs. The following table presents supplemental cash flow information related to leases: Six Months Ended March 31, (Thousands) 2022 2021 Cash paid for amounts included in the measurement of lease liabilities Operating cash flows for operating leases $ 3,557 $ 2,932 Operating cash flows for finance leases $ 404 $ 791 Financing cash flows for finance leases $ 3,947 $ 5,690
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, 2022 September 30, Assets Noncurrent Operating lease assets Operating lease assets $ 171,207 $ 173,928 Finance lease assets Utility plant 22,828 13,489 Total lease assets $ 194,035 $ 187,417 Liabilities Current Operating lease liabilities Operating lease liabilities $ 4,878 $ 4,300 Finance lease liabilities Current maturities of long-term debt 6,443 5,393 Noncurrent Operating lease liabilities Operating lease liabilities 140,036 141,363 Finance lease liabilities Long-term debt 27,045 14,742 Total lease liabilities $ 178,402 $ 165,798

COMMITMENTS AND CONTINGENT LI_2

COMMITMENTS AND CONTINGENT LIABILITIES (Tables)	6 Months Ended
	Mar. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Long-term Purchase Commitment	Commitments as of March 31, 2022, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows: (Thousands) 2022 2023 2024 2025 2026 Thereafter Energy Services: Natural gas purchases $ 110,029 $ 17,096 $ — $ — $ — $ — Storage demand fees 11,881 20,416 12,256 6,434 3,789 3,027 Pipeline demand fees 36,564 59,876 41,802 27,037 26,359 32,082 Sub-total Energy Services $ 158,474 $ 97,388 $ 54,058 $ 33,471 $ 30,148 $ 35,109 NJNG: Natural gas purchases $ 55,151 $ 5,361 $ — $ — $ — $ — Storage demand fees 25,167 41,758 27,318 17,362 10,266 14,320 Pipeline demand fees 72,067 147,689 91,216 136,515 127,692 1,179,683 Sub-total NJNG $ 152,385 $ 194,808 $ 118,534 $ 153,877 $ 137,958 $ 1,194,003 Total $ 310,859 $ 292,196 $ 172,592 $ 187,348 $ 168,106 $ 1,229,112

REPORTING SEGMENT AND OTHER O_2

REPORTING SEGMENT AND OTHER OPERATIONS DATA (Tables)	6 Months Ended
	Mar. 31, 2022
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) 2022 2021 2022 2021 Operating revenues Natural Gas Distribution External customers $ 463,474 $ 310,167 $ 737,909 $ 505,896 Intercompany 338 — 675 — Clean Energy Ventures External customers 11,827 6,476 22,010 12,846 Energy Services External customers (1) 411,069 459,766 776,857 687,115 Intercompany 1,576 2,803 5,032 4,931 Storage and Transportation External customers 12,805 13,257 24,389 25,704 Intercompany 537 669 1,096 1,326 Subtotal 901,626 793,138 1,567,968 1,237,818 Home Services and Other External customers 13,141 12,521 26,993 24,931 Intercompany 81 252 180 419 Eliminations (2,532) (3,724) (6,983) (6,676) Total $ 912,316 $ 802,187 $ 1,588,158 $ 1,256,492 Depreciation and amortization Natural Gas Distribution $ 23,344 $ 19,475 $ 46,237 $ 38,644 Clean Energy Ventures 5,311 4,685 10,544 10,118 Energy Services (2) 32 13 60 55 Storage and Transportation 2,571 2,364 4,704 5,004 Subtotal 31,258 26,537 61,545 53,821 Home Services and Other 203 227 407 487 Eliminations (26) 84 (124) (98) Total $ 31,435 $ 26,848 $ 61,828 $ 54,210 Interest income (3) Natural Gas Distribution $ 191 $ 76 $ 384 $ 158 Clean Energy Ventures — 240 — 240 Storage and Transportation 381 851 758 1,545 Subtotal 572 1,167 1,142 1,943 Home Services and Other 147 127 302 259 Eliminations (231) (237) (455) (476) Total $ 488 $ 1,057 $ 989 $ 1,726 (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) 2022 2021 2022 2021 Interest expense, net of capitalized interest Natural Gas Distribution $ 10,764 $ 9,006 $ 21,759 $ 17,980 Clean Energy Ventures 5,395 5,266 10,822 10,300 Energy Services 795 575 1,470 1,255 Storage and Transportation 1,847 3,578 3,983 7,560 Subtotal 18,801 18,425 38,034 37,095 Home Services and Other 125 1,728 369 2,844 Total $ 18,926 $ 20,153 $ 38,403 $ 39,939 Income tax provision (benefit) Natural Gas Distribution $ 29,689 $ 15,622 $ 42,893 $ 23,989 Clean Energy Ventures (1,952) (2,714) (3,998) (5,800) Energy Services (790) 23,128 19,715 35,250 Storage and Transportation 714 873 1,057 1,519 Subtotal 27,661 36,909 59,667 54,958 Home Services and Other 256 (59) 502 59 Eliminations 893 2,207 (552) 1,481 Total $ 28,810 $ 39,057 $ 59,617 $ 56,498 Equity in earnings of affiliates Storage and Transportation $ 1,256 $ 3,386 $ 2,312 $ 6,579 Eliminations (487) (582) (968) (1,100) Total $ 769 $ 2,804 $ 1,344 $ 5,479 Net financial earnings (loss) Natural Gas Distribution $ 102,783 $ 80,541 $ 153,863 $ 130,008 Clean Energy Ventures (6,491) (8,872) (13,312) (19,146) Energy Services 29,940 96,528 47,507 98,028 Storage and Transportation 4,625 4,711 7,587 8,219 Subtotal 130,857 172,908 195,645 217,109 Home Services and Other 451 747 898 685 Eliminations (1,102) (3,051) (567) (2,533) Total $ 130,206 $ 170,604 $ 195,976 $ 215,261 Capital expenditures Natural Gas Distribution $ 52,000 $ 97,239 $ 125,464 $ 176,485 Clean Energy Ventures 41,176 18,549 66,556 40,884 Storage and Transportation 43,673 20,094 109,048 27,707 Subtotal 136,849 135,882 301,068 245,076 Home Services and Other 163 125 242 811 Total $ 137,012 $ 136,007 $ 301,310 $ 245,887 Investments in (return of capital from) equity investees Storage and Transportation $ (4,000) $ 196 $ (4,000) $ 482 Total $ (4,000) $ 196 $ (4,000) $ 482
Schedule of Assets for Business Segments and Business Operations	The Company's assets for the various reporting segments and business operations are detailed below: (Thousands) March 31, September 30, Assets at end of period: Natural Gas Distribution $ 3,844,036 $ 3,707,461 Clean Energy Ventures 970,599 914,788 Energy Services 248,112 365,423 Storage and Transportation 965,615 862,407 Subtotal 6,028,362 5,850,079 Home Services and Other 136,300 162,134 Intercompany assets (1) (294,658) (289,935) Total $ 5,870,004 $ 5,722,278 (1) Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.
Reconciliation of Consolidated NFE to Consolidated Net Income	A reconciliation of consolidated NFE to consolidated net income is as follows: Three Months Ended Six Months Ended March 31, March 31, (Thousands) 2022 2021 2022 2021 Net financial earnings $ 130,206 $ 170,604 $ 195,976 $ 215,261 Less: Unrealized loss (gain) on derivative instruments and related transactions 42,022 29,255 (40,169) (8,235) Tax effect (9,980) (6,954) 9,556 1,958 Effects of economic hedging related to natural gas inventory 1,155 (7,209) 24,732 (14,741) Tax effect (274) 1,713 (5,877) 3,503 NFE tax adjustment 1,248 3,990 387 1,922 Net income $ 96,035 $ 149,809 $ 207,347 $ 230,854

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	6 Months Ended
	Mar. 31, 2022
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) 2022 2021 2022 2021 Natural Gas Distribution $ 1,546 $ 1,505 $ 3,104 $ 3,073 Energy Services 337 226 625 391 Total $ 1,883 $ 1,731 $ 3,729 $ 3,464 The following table summarizes demand fees payable to Steckman Ridge as of: (Thousands) March 31, 2022 September 30, Natural Gas Distribution $ 779 $ 778 Energy Services 76 83 Total $ 855 $ 861

NATURE OF THE BUSINESS (Details

NATURE OF THE BUSINESS (Details)	6 Months Ended
	Mar. 31, 2022subsidiarycustomer
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	568,100
NJR Retail Holdings Corporation
Nature of Business [Line Items]
Number of principal subsidiaries | subsidiary	2

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021	Sep. 30, 2021
Finite-Lived Intangible Assets [Line Items]
Operating revenues	$ 912,316	$ 802,187	$ 1,588,158	$ 1,256,492
Loans receivable in other noncurrent assets	33,700		33,700		$ 32,300
Proceeds from sale leaseback transactions			17,300	0
Proceeds from sale leaseback transactions - solar			3,300	12,124
Financial Asset, Not Past Due
Finite-Lived Intangible Assets [Line Items]
Loans receivable in other current assets	14,500		14,500		$ 14,200
Energy Services
Finite-Lived Intangible Assets [Line Items]
Operating revenues	10,300		32,400
Deferred revenue	$ 54,400		54,400
Natural Gas Distribution
Finite-Lived Intangible Assets [Line Items]
Proceeds from sale leaseback transactions			$ 17,300	$ 0
Minimum
Finite-Lived Intangible Assets [Line Items]
Loans receivable, term			2 years
Maximum
Finite-Lived Intangible Assets [Line Items]
Loans receivable, term			10 years

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021	Mar. 31, 2021	Sep. 30, 2020
Accounting Policies [Abstract]
Cash and cash equivalents	$ 13,906	$ 4,749	$ 57,654
Restricted cash in other noncurrent assets	1,294	1,294	1,321
Cash, cash equivalents and restricted cash	$ 15,200	$ 6,043	$ 58,975	$ 119,423

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - NATURAL GAS IN STORAGE (Details) $ in Thousands	Mar. 31, 2022USD ($)Bcf	Sep. 30, 2021USD ($)Bcf
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 66,300	$ 193,606
Natural Gas in Storage, Bcf | Bcf	12,300,000	46,400,000
Natural Gas Distribution
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 31,066	$ 115,824
Natural Gas in Storage, Bcf | Bcf	4,900,000	27,600,000
Energy Services
Inventory [Line Items]
Natural Gas in Storage, value | $	$ 35,234	$ 77,782
Natural Gas in Storage, Bcf | Bcf	7,400,000	18,800,000

SUMMARY OF SIGNIFICANT ACCOUN_7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SOFTWARE COSTS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021	Sep. 30, 2021
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Capitalized software costs	$ 5,714		$ 5,714		$ 5,582
Software amortization	113	$ 111	225	$ 188
Operation and maintenance
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	2,828	2,847	5,351	4,770
Depreciation and amortization
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	303	$ 270	602	$ 523
Utility plant, at cost
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	16,959		16,959		16,543
Construction work in progress | Regulated
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	20,752		20,752		7,801
Construction work in progress | Unregulated
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	0		0		8
Nonutility plant and equipment, at cost
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Software costs	344		344		338
Accumulated depreciation and amortization, utility plant
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Accumulated depreciation and amortization	(1,944)		(1,944)		(1,333)
Accumulated depreciation and amortization, nonutility plant and equipment
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Accumulated depreciation and amortization	$ (19)		$ (19)		$ (29)

SUMMARY OF SIGNIFICANT ACCOUN_8

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	$ 1,716,978	$ 1,698,214	$ 1,630,862	$ 1,643,896
Balance as of end of period	1,784,287	1,821,833	1,784,287	1,821,833
Cash Flow Hedges
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(9,112)	(10,166)	(9,376)	(10,397)
Amounts reclassified from accumulated other comprehensive income, net of tax	263	263	527	494
Balance as of end of period	(8,849)	(9,903)	(8,849)	(9,903)
Tax on amounts reclassified from accumulated other comprehensive income	(80)	(79)	(159)	(191)
Postemployment Benefit Obligation
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(24,386)	(33,106)	(25,152)	(33,918)
Amounts reclassified from accumulated other comprehensive income, net of tax	768	813	1,534	1,625
Balance as of end of period	(23,618)	(32,293)	(23,618)	(32,293)
Tax on amounts reclassified from accumulated other comprehensive income	(232)	(244)	(465)	(489)
Total
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance as of beginning of period	(33,498)	(43,272)	(34,528)	(44,315)
Amounts reclassified from accumulated other comprehensive income, net of tax	1,031	1,076	2,061	2,119
Balance as of end of period	(32,467)	(42,196)	(32,467)	(42,196)
Tax on amounts reclassified from accumulated other comprehensive income	$ (312)	$ (323)	$ (624)	$ (680)

REVENUE - DISAGGREGATED REVENUE

REVENUE - DISAGGREGATED REVENUE - PRODUCT (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 432,643	$ 339,376	$ 716,733	$ 565,103
Alternative revenue programs	2,504	(6,664)	13,158	(5,096)
Derivative instruments	478,745	472,278	863,299	24,740
Revenues out of scope	479,673	462,811	871,425	691,389
Total operating revenues	912,316	802,187	1,588,158	1,256,492
Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	381,861	296,888	605,657	486,252
Natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	30,651	24,937	70,673	44,469
Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,492	8,314	16,959	16,573
Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,730	4,459	10,214	8,777
Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,019	817	1,865	1,507
Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,846	4,882	13,316	9,270
Energy Services
Disaggregation of Revenue [Line Items]
Total operating revenues	10,300		32,400
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues	901,626	793,138	1,567,968	1,237,818
Operating Segments | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	381,523	296,888	604,982	486,252
Alternative revenue programs	2,504	(6,664)	13,158	(5,096)
Derivative instruments	79,447	19,943	119,769	24,740
Revenues out of scope	81,951	13,279	132,927	19,644
Total operating revenues	463,474	310,167	737,909	505,896
Operating Segments | Natural Gas Distribution | Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	381,861	296,888	605,657	486,252
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	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	7,865	5,699	15,181	10,777
Alternative revenue programs	0	0	0	0
Derivative instruments	3,962	777	6,829	2,069
Revenues out of scope	3,962	777	6,829	2,069
Total operating revenues	11,827	6,476	22,010	12,846
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	1,019	817	1,865	1,507
Operating Segments | Clean Energy Ventures | Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,846	4,882	13,316	9,270
Operating Segments | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	17,309	11,011	45,188	17,439
Alternative revenue programs	0	0	0	0
Derivative instruments	395,336	451,558	736,701	674,607
Revenues out of scope	393,760	448,755	731,669	669,676
Total operating revenues	411,069	459,766	776,857	687,115
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	17,309	11,011	45,188	17,439
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	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	12,805	13,257	24,389	25,704
Alternative revenue programs	0	0	0	0
Derivative instruments	0	0	0	0
Revenues out of scope	0	0	0	0
Total operating revenues	12,805	13,257	24,389	25,704
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	13,342	13,926	25,485	27,030
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	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	13,141	12,521	26,993	24,931
Home Services and Other | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,141	12,521	26,993	24,931
Alternative revenue programs	0	0	0	0
Derivative instruments	0	0	0	0
Revenues out of scope	0	0	0	0
Total operating revenues	13,141	12,521	26,993	24,931
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	8,492	8,314	16,959	16,573
Home Services and Other | Home Services and Other | Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,730	4,459	10,214	8,777
Home Services and Other | Home Services and Other | Renewable energy certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	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	(956)	(921)	(1,951)	(1,745)
Revenues out of scope	(1,576)	(2,803)	(5,032)	(4,931)
Eliminations | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(338)	0	(675)	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	(1,576)	(2,803)	(5,032)	(4,931)
Eliminations | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(537)	(669)	(1,096)	(1,326)
Revenues out of scope	0	0	0	0
Eliminations | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(81)	(252)	(180)	(419)
Revenues out of scope	$ 0	$ 0	$ 0	$ 0

REVENUE - DISAGGREGATED REVEN_2

REVENUE - DISAGGREGATED REVENUE - TYPE (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 432,643	$ 339,376	$ 716,733	$ 565,103
Revenues out of scope	479,673	462,811	871,425	691,389
Total operating revenues	912,316	802,187	1,588,158	1,256,492
Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	302,301	240,100	470,356	392,250
Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	95,130	70,386	186,198	121,052
Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	34,636	28,190	57,311	49,294
Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	576	700	2,868	2,507
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues	901,626	793,138	1,567,968	1,237,818
Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues out of scope	0	0	0	0
Total operating revenues	13,141	12,521	26,993	24,931
Home Services and Other | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	13,105	12,234	26,880	24,438
Home Services and Other | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	36	287	113	493
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	381,523	296,888	604,982	486,252
Revenues out of scope	81,951	13,279	132,927	19,644
Total operating revenues	463,474	310,167	737,909	505,896
Natural Gas Distribution | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	286,205	225,174	437,513	362,398
Natural Gas Distribution | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	60,106	42,824	107,290	72,053
Natural Gas Distribution | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	34,636	28,190	57,311	49,294
Natural Gas Distribution | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	576	700	2,868	2,507
Clean Energy Ventures | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	7,865	5,699	15,181	10,777
Revenues out of scope	3,962	777	6,829	2,069
Total operating revenues	11,827	6,476	22,010	12,846
Clean Energy Ventures | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,991	2,692	5,963	5,414
Clean Energy Ventures | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,874	3,007	9,218	5,363
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
Disaggregation of Revenue [Line Items]
Total operating revenues	10,300		32,400
Energy Services | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	17,309	11,011	45,188	17,439
Revenues out of scope	393,760	448,755	731,669	669,676
Total operating revenues	411,069	459,766	776,857	687,115
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	17,309	11,011	45,188	17,439
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	12,805	13,257	24,389	25,704
Revenues out of scope	0	0	0	0
Total operating revenues	12,805	13,257	24,389	25,704
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	12,805	13,257	24,389	25,704
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

REVENUE - TIMING OF REVENUE REC

REVENUE - TIMING OF REVENUE RECOGNITION (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Timing of Revenue Recognition [Roll Forward]
Billed, beginning	$ 212,838	$ 134,173
Unbilled, beginning	10,351	9,226
Customers' credit, beginning	32,586	25,934
Increase (decrease) for accounts receivable, billed	60,475	103,056
Increase (decrease) for unbilled revenue	45,919	32,715
Increase (decrease) for customers' credits	(12,302)	(5,171)
Billed, end	273,313	237,229
Unbilled, end	56,270	41,941
Customers' credit, end	$ 20,284	$ 20,763

REVENUE - TIMING OF REVENUE R_2

REVENUE - TIMING OF REVENUE RECOGNITION - BALANCE SHEET (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021	Mar. 31, 2021	Sep. 30, 2020
Customer accounts receivable
Billed	$ 273,313	$ 212,838	$ 237,229	$ 134,173
Unbilled revenues	56,270	10,351	41,941	9,226
Customers' credit balances and deposits	(20,284)	(32,586)	$ (20,763)	$ (25,934)
Customers accounts receivables & Customers' credit balances and deposits	309,299	190,603
Operating Segments | Natural Gas Distribution
Customer accounts receivable
Billed	154,380	54,514
Unbilled revenues	54,675	8,427
Customers' credit balances and deposits	(20,284)	(32,586)
Customers accounts receivables & Customers' credit balances and deposits	188,771	30,355
Operating Segments | Clean Energy Ventures
Customer accounts receivable
Billed	5,239	5,534
Unbilled revenues	1,595	1,924
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	6,834	7,458
Operating Segments | Energy Services
Customer accounts receivable
Billed	107,262	147,087
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	107,262	147,087
Operating Segments | Storage and Transportation
Customer accounts receivable
Billed	4,385	3,956
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	4,385	3,956
Home Services and Other
Customer accounts receivable
Billed	2,047	1,747
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	$ 2,047	$ 1,747

REGULATION - REGULATORY FILINGS

REGULATION - REGULATORY FILINGS (Details) - USD ($) $ in Thousands	Apr. 22, 2022	Mar. 31, 2022	Mar. 23, 2022	Jan. 26, 2022	Nov. 19, 2021	Nov. 17, 2021	Mar. 31, 2022	Sep. 30, 2021
Schedule of Regulatory Filings [Line Items]
Other noncurrent regulatory assets		$ 513,006					$ 513,006	$ 522,099
Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Other noncurrent regulatory assets		7,500					$ 7,500
Base Rate Stipulation
Schedule of Regulatory Filings [Line Items]
Weighted average cost of capital							6.84%
Approved return on equity							9.60%
Approved equity capital structure, percentage							54.00%
Public utilities, approved depreciation rate, percentage							2.78%
BPU
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount		$ 25,600
BPU | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount						$ 79,000
BPU | Natural Gas Distribution | Subsequent Event
Schedule of Regulatory Filings [Line Items]
Investment	$ 500,000
Program term	3 years
SAFE II and NJ RISE
Schedule of Regulatory Filings [Line Items]
Approved rate increase (decrease), amount							$ 269
BGSS | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount						2,900
BGSS | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount					$ 24,200
BGSS Balancing | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount						13,000
Conservation Incentive Program | Natural Gas Distribution
Schedule of Regulatory Filings [Line Items]
Requested rate increase (decrease), amount						$ (6,300)
SAVEGREEN
Schedule of Regulatory Filings [Line Items]
Annual recovery increase				$ 2,200
RAC
Schedule of Regulatory Filings [Line Items]
Approved rate increase (decrease), amount			$ 600
NJCEP
Schedule of Regulatory Filings [Line Items]
Approved rate increase (decrease), amount			$ (2,900)

REGULATION - REGULATORY ASSETS

REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	$ 33,717	$ 30,118
Overrecovered natural gas costs	88,064	28,007
Regulatory liabilities-noncurrent	191,450	193,051
NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	32,846	29,701
Regulatory assets-noncurrent	508,550	519,600
Overrecovered natural gas costs	88,064	28,007
Regulatory liabilities-noncurrent	188,466	191,888
Adelphia
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	871	417
Regulatory assets-noncurrent	4,456	2,499
Regulatory liabilities-noncurrent	2,984	1,163
Total current regulatory liabilities | NJNG
Regulatory Assets And Liabilities [Line Items]
Overrecovered natural gas costs	27,133	5,510
Derivatives at fair value, net | NJNG
Regulatory Assets And Liabilities [Line Items]
Overrecovered natural gas costs	60,931	22,497
Regulatory liabilities-noncurrent	0	1,166
Tax Act impact | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	187,876	190,386
Other noncurrent regulatory liabilities | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities-noncurrent	590	336
New Jersey Clean Energy Program | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	6,608	16,308
Conservation Incentive Program | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	24,997	11,839
Other current regulatory assets | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-current	1,241	1,554
Regulatory assets-noncurrent	32,040	32,695
Expended, net of recoveries | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	65,523	58,483
Liability for future expenditures | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	121,615	135,012
Deferred income taxes | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	39,857	39,694
SAVEGREEN | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	33,917	32,941
Postemployment and other benefit costs | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	111,918	117,194
Deferred storm damage costs | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	3,257	4,343
Cost of removal | NJNG
Regulatory Assets And Liabilities [Line Items]
Regulatory assets-noncurrent	$ 100,423	$ 99,238

DERIVATIVE INSTRUMENTS - BALANC

DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
Fair Value
Derivative assets, current	$ 21,586	$ 35,251
Derivative liabilities, current	45,216	87,145
Derivative assets, noncurrent	4,140	3,403
Derivative liabilities, noncurrent	19,632	13,497
Not Designated as Hedging Instrument
Fair Value
Derivative assets	25,726	38,654
Derivative liabilities	64,848	100,642
Natural Gas Distribution | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	101	36
Derivative liabilities, current	16	16
Natural Gas Distribution | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	111	2,046
Derivative liabilities, current	1,887	13
Energy Services | Not Designated as Hedging Instrument | Physical commodity contracts
Fair Value
Derivative assets, current	1,853	2,818
Derivative liabilities, current	21,594	24,592
Derivative assets, noncurrent	131	333
Derivative liabilities, noncurrent	19,632	13,237
Energy Services | Not Designated as Hedging Instrument | Financial commodity contracts
Fair Value
Derivative assets, current	19,483	30,226
Derivative liabilities, current	21,701	62,521
Derivative assets, noncurrent	4,009	3,068
Derivative liabilities, noncurrent	0	260
Energy Services | Not Designated as Hedging Instrument | Foreign currency contracts
Fair Value
Derivative assets, current	38	125
Derivative liabilities, current	18	3
Derivative assets, noncurrent	0	2
Derivative liabilities, noncurrent	$ 0	$ 0

DERIVATIVE INSTRUMENTS - OFFSET

DERIVATIVE INSTRUMENTS - OFFSETTING OF ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
Energy Services
Derivative assets:
Amounts Presented in Balance Sheets	$ 25,514	$ 36,572
Offsetting Derivative Instruments	(18,798)	(34,191)
Financial Collateral Received/Pledged	(200)	19,832
Net Amounts	6,516	22,213
Derivative liabilities:
Amounts Presented in Balance Sheets	62,945	100,613
Offsetting Derivative Instruments	(18,798)	(34,191)
Financial Collateral Received/Pledged	0	0
Net Amounts	44,147	66,422
Energy Services | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	1,984	3,151
Offsetting Derivative Instruments	(480)	(894)
Financial Collateral Received/Pledged	(200)	(700)
Net Amounts	1,304	1,557
Derivative liabilities:
Amounts Presented in Balance Sheets	41,226	37,829
Offsetting Derivative Instruments	(480)	(894)
Financial Collateral Received/Pledged	0	0
Net Amounts	40,746	36,935
Energy Services | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	23,492	33,294
Offsetting Derivative Instruments	(18,300)	(33,294)
Financial Collateral Received/Pledged	0	20,532
Net Amounts	5,192	20,532
Derivative liabilities:
Amounts Presented in Balance Sheets	21,701	62,781
Offsetting Derivative Instruments	(18,300)	(33,294)
Financial Collateral Received/Pledged	0	0
Net Amounts	3,401	29,487
Energy Services | Foreign currency contracts
Derivative assets:
Amounts Presented in Balance Sheets	38	127
Offsetting Derivative Instruments	(18)	(3)
Financial Collateral Received/Pledged	0	0
Net Amounts	20	124
Derivative liabilities:
Amounts Presented in Balance Sheets	18	3
Offsetting Derivative Instruments	(18)	(3)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	0
Natural Gas Distribution
Derivative assets:
Amounts Presented in Balance Sheets	212	2,082
Offsetting Derivative Instruments	(119)	(21)
Financial Collateral Received/Pledged	0	0
Net Amounts	93	2,061
Derivative liabilities:
Amounts Presented in Balance Sheets	1,903	29
Offsetting Derivative Instruments	(119)	(21)
Financial Collateral Received/Pledged	0	0
Net Amounts	1,784	8
Natural Gas Distribution | Physical commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	101	36
Offsetting Derivative Instruments	(8)	(8)
Financial Collateral Received/Pledged	0	0
Net Amounts	93	28
Derivative liabilities:
Amounts Presented in Balance Sheets	16	16
Offsetting Derivative Instruments	(8)	(8)
Financial Collateral Received/Pledged	0	0
Net Amounts	8	8
Natural Gas Distribution | Financial commodity contracts
Derivative assets:
Amounts Presented in Balance Sheets	111	2,046
Offsetting Derivative Instruments	(111)	(13)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	2,033
Derivative liabilities:
Amounts Presented in Balance Sheets	1,887	13
Offsetting Derivative Instruments	(111)	(13)
Financial Collateral Received/Pledged	0	0
Net Amounts	$ 1,776	$ 0

DERIVATIVE INSTRUMENTS - INCOME

DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) - Not Designated as Hedging Instrument - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	$ (43,694)	$ 11,781	$ 19,150	$ 59,934
Energy Services | Physical commodity contracts | Operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	(11,582)	36,419	(11,432)	41,671
Energy Services | Physical commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	(875)	2,650	630	(2,404)
Energy Services | Financial commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	(31,223)	(27,315)	29,966	20,440
Energy Services | Foreign currency contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	(14)	27	(14)	227
Natural Gas Distribution
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	66,023	1,736	53,072	(2,194)
Natural Gas Distribution | Physical commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	4,538	1,091	6,234	1,433
Natural Gas Distribution | Financial commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (losses) gains recognized in income on derivatives	$ 61,485	$ 645	$ 46,838	$ (3,627)

DERIVATIVE INSTRUMENTS - ADDITI

DERIVATIVE INSTRUMENTS - ADDITIONAL INFORMATION (Details) certificate in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022USD ($)certificate	Mar. 31, 2021USD ($)	Mar. 31, 2022USD ($)certificate	Mar. 31, 2021USD ($)	Sep. 30, 2021USD ($)certificate
Treasury Lock | Interest expense
Derivative [Line Items]
Amount of pre-tax gain (loss) reclassified from OCI into income	$ (343)	$ (342)	$ (686)	$ (685)
Foreign currency contracts
Derivative [Line Items]
Notional amount	$ (20)		$ (20)		$ (123)
Physical commodity contracts | Energy Services
Derivative [Line Items]
Number of SRECs (in certificates) | certificate	1,500		1,500		1,400

DERIVATIVE INSTRUMENTS - VOLUME

DERIVATIVE INSTRUMENTS - VOLUME (Details) - Bcf	6 Months Ended	12 Months Ended
	Mar. 31, 2022	Sep. 30, 2021
Natural Gas Distribution | Long | Futures
Derivative [Line Items]
Notional amount	29.6	22.2
Natural Gas Distribution | Long | Physical Commodity
Derivative [Line Items]
Notional amount	12.8	7.6
Energy Services | Long | Physical Commodity
Derivative [Line Items]
Notional amount	7.5	0.6
Energy Services | Short | Futures
Derivative [Line Items]
Notional amount	(0.7)	(13.4)
Energy Services | Short | Swaps
Derivative [Line Items]
Notional amount	(0.2)	(0.3)

DERIVATIVE INSTRUMENTS - BROKER

DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
Natural Gas Distribution | Assets, Current
Derivative [Line Items]
Broker margin - Current assets	$ 11,617	$ 2,790
Energy Services | Assets, Current
Derivative [Line Items]
Broker margin - Current assets	38,284	70,050
Energy Services | Liabilities, Current
Derivative [Line Items]
Broker margin - Current liabilities	$ (2,464)	$ 0

DERIVATIVE INSTRUMENTS - CREDIT

DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2022USD ($)
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 181,318
Investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	128,926
Noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	9,601
Internally rated investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	20,566
Internally rated noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 22,225

FAIR VALUE - DEBT (Details)

FAIR VALUE - DEBT (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Finance leases	$ 33,500	$ 20,100
NJR
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	3,600	3,300
Natural Gas Distribution
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	10,100	9,100
Level 2 | Carrying Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	2,202,845	2,102,845
Level 2 | Fair market value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 2,137,966	$ 2,288,544

FAIR VALUE - ADDITIONAL INFORMA

FAIR VALUE - ADDITIONAL INFORMATION (Details) - USD ($) $ in Millions	Mar. 31, 2022	Sep. 30, 2021
Solar Asset Financing | Fair market value | Clean Energy Ventures
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 121.8	$ 132.5

FAIR VALUE - HIERARCHY (Details

FAIR VALUE - HIERARCHY (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	$ 1,998	$ 1,815
Total assets at fair value	27,763	40,510
Total liabilities at fair value	64,848	100,642
Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	2,085	3,187
Liabilities	41,242	37,845
Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	23,603	35,340
Liabilities	23,588	62,794
Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	38	127
Liabilities	18	3
Quoted Prices in Active Markets for Identical Assets, (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	1,998	1,815
Total assets at fair value	25,640	37,196
Total liabilities at fair value	23,050	62,188
Quoted Prices in Active Markets for Identical Assets, (Level 1) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Quoted Prices in Active Markets for Identical Assets, (Level 1) | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	23,603	35,340
Liabilities	23,050	62,188
Quoted Prices in Active Markets for Identical Assets, (Level 1) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	0	0
Total assets at fair value	2,123	3,314
Total liabilities at fair value	41,798	38,454
Significant Other Observable Inputs (Level 2) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	2,085	3,187
Liabilities	41,242	37,845
Significant Other Observable Inputs (Level 2) | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	538	606
Significant Other Observable Inputs (Level 2) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	38	127
Liabilities	18	3
Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other	0	0
Total assets at fair value	0	0
Total liabilities at fair value	0	0
Significant Unobservable Inputs (Level 3) | Physical commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Significant Unobservable Inputs (Level 3) | Financial commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Significant Unobservable Inputs (Level 3) | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	0	0
Money market funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	39	41
Money market funds | Quoted Prices in Active Markets for Identical Assets, (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	39	41
Money market funds | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Money market funds | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 0	$ 0

INVESTMENTS IN EQUITY INVESTE_3

INVESTMENTS IN EQUITY INVESTEES (Details) $ in Thousands	Mar. 31, 2022USD ($)	Jun. 30, 2021USD ($)	Mar. 31, 2022USD ($)mi	Sep. 30, 2021USD ($)
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 109,980		$ 109,980	$ 114,529
Other than temporary impairment		$ 92,000
Other than temporary impairment, net of tax		$ 74,500
PennEast | NJR Pipeline
Schedule of Equity Method Investments [Line Items]
Ownership percentage	20.00%		20.00%
Steckman Ridge
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 108,501		$ 108,501	109,050
Total outstanding principal balance of loans	$ 70,400		$ 70,400	70,400
Ownership percentage	50.00%		50.00%
PennEast
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 1,479		$ 1,479	$ 5,479
Ownership percentage	20.00%		20.00%
Construction plan, project area (in miles) | mi			120
PennEast | PennEast
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 1,500		$ 1,500
Distribution	$ 4,000

EARNINGS PER SHARE (Details)

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended				6 Months Ended
	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2022	Mar. 31, 2021
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income, as reported	$ 96,035	$ 111,312	$ 149,809	$ 81,045	$ 207,347	$ 230,854
Basic earnings per share
Weighted average shares of common stock outstanding-basic (in shares)	96,068,000		96,248,000		96,006,000	96,181,000
Basic earnings per common share (usd per share)	$ 1		$ 1.56		$ 2.16	$ 2.40
Diluted earnings per share
Weighted average shares of common stock outstanding-basic (in shares)	96,068,000		96,248,000		96,006,000	96,181,000
Incremental shares (in shares)	448,000		370,000		474,000	417,000
Weighted average shares of common stock outstanding-diluted (in shares)	96,516,000		96,618,000		96,480,000	96,598,000
Diluted earnings per common share (usd per share)	$ 1		$ 1.55		$ 2.15	$ 2.39
Share-based Payment Arrangement
Diluted earnings per share
Anti-dilutive shares excluded from the calculation of diluted earnings per share (in shares)			24,101			65,334

DEBT - CREDIT FACILITIES AND SH

DEBT - CREDIT FACILITIES AND SHORT-TERM DEBT, ADDITIONAL INFORMATION (Details) - Term Loan - Committed Credit Facilities Due February 2023 - NJR - USD ($)	Feb. 08, 2022	Mar. 31, 2022	Feb. 14, 2022	Feb. 09, 2022	Sep. 30, 2021
Debt Conversion [Line Items]
Bank revolving credit facilities		$ 150,000,000			$ 0
Amount borrowed			$ 100,000,000	$ 50,000,000
SOFR
Debt Conversion [Line Items]
Basis spread on variable rate	0.85%

DEBT - CREDIT FACILITIES AND _2

DEBT - CREDIT FACILITIES AND SHORT-TERM DEBT (Details) - USD ($)	6 Months Ended
	Mar. 31, 2022	Sep. 30, 2021
NJR | Letter of Credit on Behalf of NJRES
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount	$ 13,500,000	$ 10,600,000
NJNG | Letter of Credit
Line of Credit Facility [Line Items]
Letters of credit outstanding, amount	$ 731,000	731,000
Revolving Credit Facility | NJR
Line of Credit Facility [Line Items]
Commitment fee percentage	0.10%
Revolving Credit Facility | NJNG
Line of Credit Facility [Line Items]
Commitment fee percentage	0.075%
Term Loan | Committed Credit Facilities Due February 2023 | NJR
Line of Credit Facility [Line Items]
Bank revolving credit facilities	$ 150,000,000	0
Amount outstanding at end of period	$ 150,000,000	$ 0
Weighted average interest rate at end of period	1.04%	0.00%
Amount available at end of period	$ 0	$ 0
Revolving Credit Facility | Committed Credit Facilities Due September 2026 | NJR
Line of Credit Facility [Line Items]
Bank revolving credit facilities	500,000,000	500,000,000
Amount outstanding at end of period	$ 152,210,000	$ 219,100,000
Weighted average interest rate at end of period	2.02%	1.05%
Amount available at end of period	$ 334,325,000	$ 270,312,000
Revolving Credit Facility | Committed Credit Facilities Due September 2026 | NJNG
Line of Credit Facility [Line Items]
Bank revolving credit facilities	250,000,000	250,000,000
Amount outstanding at end of period	$ 0	$ 158,200,000
Weighted average interest rate at end of period	0.00%	0.17%
Amount available at end of period	$ 249,269,000	$ 91,069,000

DEBT - LONG TERM DEBT (Details)

DEBT - LONG TERM DEBT (Details) - USD ($) $ in Thousands	Feb. 16, 2022	Mar. 31, 2022	Mar. 31, 2021	Oct. 28, 2021
Debt Instrument [Line Items]
Proceeds from sale leaseback transactions		$ 17,300	$ 0
Proceeds from sale leaseback transactions - solar		3,300	12,124
Senior Notes | Natural Gas Distribution
Debt Instrument [Line Items]
Face amount				$ 100,000
Senior Notes | Natural Gas Distribution | Fixed Interest Rate Maturing 2051
Debt Instrument [Line Items]
Face amount				$ 50,000
Stated interest rate				2.97%
Senior Notes | Natural Gas Distribution | Fixed Interest Rate Maturing 2061
Debt Instrument [Line Items]
Face amount				$ 50,000
Stated interest rate				3.07%
Senior Notes | NJR
Debt Instrument [Line Items]
Face amount	$ 50,000
Debt instrument, term	12 years
Stated interest rate	3.64%
Clean Energy Ventures
Debt Instrument [Line Items]
Proceeds from sale leaseback transactions - solar		$ 3,300	12,100
Clean Energy Ventures | Minimum
Debt Instrument [Line Items]
Sale leaseback transaction lease term		5 years
Clean Energy Ventures | Maximum
Debt Instrument [Line Items]
Sale leaseback transaction lease term		15 years
Natural Gas Distribution
Debt Instrument [Line Items]
Proceeds from sale leaseback transactions		$ 17,300	0
Payments for sale leaseback transaction		$ 1,100	$ 1,200

EMPLOYEE BENEFIT PLANS - COMPON

EMPLOYEE BENEFIT PLANS - COMPONENTS OF NET PERIODIC COST (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	$ 2,073	$ 2,183	$ 4,146	$ 4,365
Interest cost	2,408	2,278	4,816	4,556
Expected return on plan assets	(5,318)	(4,851)	(10,637)	(10,075)
Recognized actuarial loss	2,186	2,861	4,372	5,723
Prior service cost (credit) amortization	26	26	51	51
Net periodic benefit cost	1,375	2,497	2,748	4,620
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	1,076	1,211	2,152	2,422
Interest cost	1,589	1,517	3,178	3,035
Expected return on plan assets	(1,894)	(1,565)	(3,788)	(3,248)
Recognized actuarial loss	1,421	1,978	2,842	3,955
Prior service cost (credit) amortization	(36)	(45)	(72)	(90)
Net periodic benefit cost	$ 2,156	$ 3,096	$ 4,312	$ 6,074

EMPLOYEE BENEFIT PLANS - ADDITI

EMPLOYEE BENEFIT PLANS - ADDITIONAL INFORMATION (Details) - USD ($)	6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
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

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Dec. 31, 2021	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2024	Dec. 31, 2023	Sep. 30, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Forecasted effective tax rate		22.30%	19.90%
Revaluation of deferred tax assets and liabilities		$ (166)	$ (145)
Actual effective tax rate		22.30%	19.70%
ITC carryforward		$ 227,100				$ 224,200
Effective term		20 years
Potential net capital loss		$ 61,800
Valuation allowance		23,700				23,600
Operating loss carryforward, valuation allowance		17,300
Investment tax credit, solar property, percentage	26.00%						26.00%	30.00%
Scenario, Forecast
Operating Loss Carryforwards [Line Items]
Investment tax credit, solar property, percentage				10.00%	22.00%
Capital Loss Carryforward
Operating Loss Carryforwards [Line Items]
Tax credit carryforward, valuation allowance		6,400
State
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards		$ 404,800				$ 554,600
State | Minimum
Operating Loss Carryforwards [Line Items]
Effective term	7 years
State | Maximum
Operating Loss Carryforwards [Line Items]
Effective term	20 years

LEASES - ADDITIONAL INFORMATION

LEASES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021	Sep. 30, 2021	Jul. 31, 2021
Lessee, Lease, Description [Line Items]
ROU asset obtained in exchange for operating lease liability	$ 17	$ 5,700	$ 825	$ 13,300
Proceeds from sale leaseback transactions			$ 17,300	0
ROU asset obtained in exchange for finance lease liability	$ 0	$ 0		0
Weighted average remaining lease term, operating lease	29 years 7 months 6 days		29 years 7 months 6 days		29 years 7 months 6 days
Operating lease, discount rate	3.20%		3.20%		3.20%
Weighted average remaining lease term, finance lease	4 years 6 months		4 years 6 months		3 years 4 months 24 days
Finance lease, discount rate	2.70%		2.70%		3.50%
Natural Gas Distribution
Lessee, Lease, Description [Line Items]
Proceeds from sale leaseback transactions			$ 17,300	$ 0
Solar Property | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	20 years		20 years
Renewal term	5 years		5 years
Solar Property | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	50 years		50 years
Renewal term	20 years		20 years
Office Building
Lessee, Lease, Description [Line Items]
Term of contract						16 years
Office Building | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	2 years		2 years
Office Building | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	17 years		17 years
Meter License | Minimum
Lessee, Lease, Description [Line Items]
Term of contract	7 years		7 years
Meter License | Maximum
Lessee, Lease, Description [Line Items]
Term of contract	10 years		10 years
Equipment
Lessee, Lease, Description [Line Items]
Term of contract	6 years		6 years
Storage and Capacity
Lessee, Lease, Description [Line Items]
Term of contract	50 years		50 years

LEASES - LEASE COST (Details)

LEASES - LEASE COST (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Leases [Abstract]
Operating lease cost	$ 2,915	$ 1,356	$ 5,034	$ 3,445
Amortization of right-of-use assets	457	1,191	853	2,437
Interest on lease liabilities	104	113	184	334
Total finance lease cost	561	1,304	1,037	2,771
Short-term lease cost	12	127	23	254
Variable lease cost	172	549	363	702
Total lease cost	$ 3,660	$ 3,336	$ 6,457	$ 7,172

LEASES - SUPPLEMENTAL CASH FLOW

LEASES - SUPPLEMENTAL CASH FLOW INFORMATION (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Leases [Abstract]
Operating cash flows for operating leases	$ 3,557	$ 2,932
Operating cash flows for finance leases	404	791
Financing cash flows for finance leases	$ 3,947	$ 5,690

LEASES - RIGHT-OF-USE ASSETS AN

LEASES - RIGHT-OF-USE ASSETS AND LEASE LIABILITIES (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
NONCURRENT ASSETS
Operating lease assets	$ 171,207	$ 173,928
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Utility plant, at cost	Utility plant, at cost
Finance lease assets	$ 22,828	$ 13,489
Total lease assets	194,035	187,417
Current
Operating lease liabilities	$ 4,878	$ 4,300
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Current maturities of long-term debt	Current maturities of long-term debt
Finance lease liabilities	$ 6,443	$ 5,393
Noncurrent
Operating lease liabilities	$ 140,036	$ 141,363
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Long-term debt	Long-term debt
Finance lease liabilities	$ 27,045	$ 14,742
Total lease liabilities	$ 178,402	$ 165,798

COMMITMENTS AND CONTINGENT LI_3

COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2022USD ($)
Long-term Purchase Commitment [Line Items]
Current charges recoverable through BGSS	$ 199,500
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	310,859
2023	292,196
2024	172,592
2025	187,348
2026	168,106
Thereafter	1,229,112
Energy Services
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	158,474
2023	97,388
2024	54,058
2025	33,471
2026	30,148
Thereafter	35,109
Energy Services | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	110,029
2023	17,096
2024	0
2025	0
2026	0
Thereafter	0
Energy Services | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	11,881
2023	20,416
2024	12,256
2025	6,434
2026	3,789
Thereafter	3,027
Energy Services | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	36,564
2023	59,876
2024	41,802
2025	27,037
2026	26,359
Thereafter	32,082
Annual pipeline obligation to be paid over 10 year period	4,000
Natural Gas Distribution
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	152,385
2023	194,808
2024	118,534
2025	153,877
2026	137,958
Thereafter	1,194,003
Natural Gas Distribution | Natural gas purchases
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	55,151
2023	5,361
2024	0
2025	0
2026	0
Thereafter	0
Natural Gas Distribution | Storage demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	25,167
2023	41,758
2024	27,318
2025	17,362
2026	10,266
Thereafter	14,320
Natural Gas Distribution | Pipeline demand fees
Natural Gas Purchases and Future Demand Fees, Next Five Fiscal Years
2022	72,067
2023	147,689
2024	91,216
2025	136,515
2026	127,692
Thereafter	$ 1,179,683
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

COMMITMENTS AND CONTINGENT LI_4

COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details) - USD ($) $ in Thousands	Mar. 23, 2022	Apr. 07, 2021	Mar. 31, 2022	Sep. 30, 2021
Site Contingency [Line Items]
Manufactured gas plant remediation			$ 121,605	$ 135,012
Recovery from third party of environmental remediation cost, period			7 years
Regulatory assets			$ 513,006	$ 522,099
Expended, net of recoveries
Site Contingency [Line Items]
Regulatory assets			65,500
RAC
Site Contingency [Line Items]
Approved rate, amount	$ 11,700	$ 11,100
Approved rate increase (decrease), amount	$ 600
Minimum
Site Contingency [Line Items]
Product liability contingency, loss exposure in excess of accrual, best estimate			115,700
Maximum
Site Contingency [Line Items]
Product liability contingency, loss exposure in excess of accrual, best estimate			$ 178,700

REPORTING SEGMENT AND OTHER O_3

REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Mar. 31, 2022	Mar. 31, 2021
Segment Reporting Information [Line Items]
Utility	$ 463,474	$ 310,167	$ 737,909	$ 505,896
Nonutility	448,842	492,020	850,249	750,596
Operating revenues	912,316	802,187	1,588,158	1,256,492
Depreciation and amortization	31,435	26,848	61,828	54,210
Interest income	488	1,057	989	1,726
Interest expense, net of capitalized interest	18,926	20,153	38,403	39,939
Income tax provision (benefit)	28,810	39,057	59,617	56,498
Impairment of equity method investment	769	2,804	1,344	5,479
Net financial earnings (loss)	130,206	170,604	195,976	215,261
Capital expenditures	137,012	136,007	301,310	245,887
Investments in (return of capital from) equity investees	(4,000)		(4,000)
Investments in (return of capital from) equity investees		196		482
Energy Services
Segment Reporting Information [Line Items]
Operating revenues	10,300		32,400
Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	901,626	793,138	1,567,968	1,237,818
Depreciation and amortization	31,258	26,537	61,545	53,821
Interest income	572	1,167	1,142	1,943
Interest expense, net of capitalized interest	18,801	18,425	38,034	37,095
Income tax provision (benefit)	27,661	36,909	59,667	54,958
Net financial earnings (loss)	130,857	172,908	195,645	217,109
Capital expenditures	136,849	135,882	301,068	245,076
Operating Segments | Natural Gas Distribution, External Customers
Segment Reporting Information [Line Items]
Utility	463,474	310,167	737,909	505,896
Operating Segments | Clean Energy Ventures, External Customers
Segment Reporting Information [Line Items]
Nonutility	11,827	6,476	22,010	12,846
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Nonutility	411,069	459,766	776,857	687,115
Operating revenues	411,069	459,766	776,857	687,115
Depreciation and amortization	32	13	60	55
Interest expense, net of capitalized interest	795	575	1,470	1,255
Income tax provision (benefit)	(790)	23,128	19,715	35,250
Net financial earnings (loss)	29,940	96,528	47,507	98,028
Operating Segments | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility	12,805	13,257	24,389	25,704
Operating revenues	12,805	13,257	24,389	25,704
Depreciation and amortization	2,571	2,364	4,704	5,004
Interest income	381	851	758	1,545
Interest expense, net of capitalized interest	1,847	3,578	3,983	7,560
Income tax provision (benefit)	714	873	1,057	1,519
Impairment of equity method investment	1,256	3,386	2,312	6,579
Net financial earnings (loss)	4,625	4,711	7,587	8,219
Capital expenditures	43,673	20,094	109,048	27,707
Investments in (return of capital from) equity investees	(4,000)		(4,000)
Investments in (return of capital from) equity investees		196		482
Operating Segments | Natural Gas Distribution
Segment Reporting Information [Line Items]
Operating revenues	463,474	310,167	737,909	505,896
Depreciation and amortization	23,344	19,475	46,237	38,644
Interest income	191	76	384	158
Interest expense, net of capitalized interest	10,764	9,006	21,759	17,980
Income tax provision (benefit)	29,689	15,622	42,893	23,989
Net financial earnings (loss)	102,783	80,541	153,863	130,008
Capital expenditures	52,000	97,239	125,464	176,485
Operating Segments | Clean Energy Ventures
Segment Reporting Information [Line Items]
Operating revenues	11,827	6,476	22,010	12,846
Depreciation and amortization	5,311	4,685	10,544	10,118
Interest income	0	240	0	240
Interest expense, net of capitalized interest	5,395	5,266	10,822	10,300
Income tax provision (benefit)	(1,952)	(2,714)	(3,998)	(5,800)
Net financial earnings (loss)	(6,491)	(8,872)	(13,312)	(19,146)
Capital expenditures	41,176	18,549	66,556	40,884
Intercompany
Segment Reporting Information [Line Items]
Nonutility	81	252	180	419
Intercompany | Natural Gas Distribution, External Customers
Segment Reporting Information [Line Items]
Utility	338	0	675	0
Intercompany | Energy Services
Segment Reporting Information [Line Items]
Nonutility	1,576	2,803	5,032	4,931
Intercompany | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility	537	669	1,096	1,326
Home Services and Other
Segment Reporting Information [Line Items]
Nonutility	13,141	12,521	26,993	24,931
Operating revenues	13,141	12,521	26,993	24,931
Depreciation and amortization	203	227	407	487
Interest income	147	127	302	259
Interest expense, net of capitalized interest	125	1,728	369	2,844
Income tax provision (benefit)	256	(59)	502	59
Net financial earnings (loss)	451	747	898	685
Capital expenditures	163	125	242	811
Eliminations
Segment Reporting Information [Line Items]
Nonutility	(2,532)	(3,724)	(6,983)	(6,676)
Depreciation and amortization	(26)	84	(124)	(98)
Interest income	(231)	(237)	(455)	(476)
Income tax provision (benefit)	893	2,207	(552)	1,481
Impairment of equity method investment	(487)	(582)	(968)	(1,100)
Net financial earnings (loss)	$ (1,102)	$ (3,051)	$ (567)	$ (2,533)

REPORTING SEGMENT AND OTHER O_4

REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Sep. 30, 2021
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ 5,870,004	$ 5,722,278
Operating Segments
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	6,028,362	5,850,079
Operating Segments | Natural Gas Distribution
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	3,844,036	3,707,461
Operating Segments | Clean Energy Ventures
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	970,599	914,788
Operating Segments | Energy Services
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	248,112	365,423
Operating Segments | Storage and Transportation
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	965,615	862,407
Home Services and Other
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	136,300	162,134
Intercompany Assets
Segment Reporting, Asset Reconciling Item [Line Items]
Assets	$ (294,658)	$ (289,935)

REPORTING SEGMENT AND OTHER O_5

REPORTING SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS (LOSS) RECONCILIATION (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2022	Mar. 31, 2021
Segment Reporting [Abstract]
Net financial earnings (loss)	$ 130,206		$ 170,604		$ 195,976	$ 215,261
Less:
Unrealized loss (gain) on derivative instruments and related transactions	42,022		29,255		(40,169)	(8,235)
Tax effect	(9,980)		(6,954)		9,556	1,958
Effects of economic hedging related to natural gas inventory	1,155		(7,209)		24,732	(14,741)
Tax effect	(274)		1,713		(5,877)	3,503
NFE tax adjustment	1,248		3,990		387	1,922
NET INCOME	$ 96,035	$ 111,312	$ 149,809	$ 81,045	$ 207,347	$ 230,854

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) $ in Thousands	Apr. 01, 2020USD ($)Bcf	Mar. 31, 2021	Mar. 31, 2022USD ($)	Mar. 31, 2021USD ($)	Mar. 31, 2022USD ($)dth / dleaseBcf	Mar. 31, 2021USD ($)	Sep. 30, 2021USD ($)	Jul. 31, 2021
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement			$ 1,883	$ 1,731	$ 3,729	$ 3,464
Demand fees payable			855		$ 855		$ 861
Number of asset management agreements | lease					1
NJNG to NJRES Affiliate
Related Party Transaction [Line Items]
Asset management agreement, period	5 years
NJNG to Steckman RIdge Affiliate
Related Party Transaction [Line Items]
Natural gas sold at cost under asset management agreement (in Bcf) | Bcf	3
Approximate annual demand fees under agreement	$ 9,300
Demand fees expense recognized pertaining to related party agreement			1,546	1,505	$ 3,104	3,073
Demand fees payable			779		779		778
NJRES to Steckman Ridge Affiliate
Related Party Transaction [Line Items]
Demand fees expense recognized pertaining to related party agreement			337	$ 226	625	$ 391
Demand fees payable			$ 76		$ 76		$ 83
NJN G to Adelphia Affiliate
Related Party Transaction [Line Items]
Transportation precedent agreement term					5 years
Transportation capacity under precedent agreement with PennEast (in bcf per day) | dth / d					130,000
Leaf River Energy Center LLC
Related Party Transaction [Line Items]
Natural gas sold at cost under asset management agreement (in Bcf) | Bcf					3
Storage capacity agreement term					5 years
NJNG and Clean Energy Ventures to PPA
Related Party Transaction [Line Items]
Sublease agreement term		15 years
NJNG To NJR Subsidiaries
Related Party Transaction [Line Items]
Term of contract								16 years