8-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 8-K

CURRENT REPORT

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

Date of Report (Date of earliest event reported): September 24, 2021

NEW JERSEY RESOURCES CORPORATION

(Exact Name of registrant as specified in its charter)

New Jersey		001-08359		22-2376465
(State or other jurisdiction of incorporation or organization)		(Commission File Number)		(I.R.S. Employer Identification Number)
	1415 Wyckoff Road,	Wall,	New Jersey	07719
	(Address of Principal Executive Offices)

(732) 938-1480
(Registrant’s telephone number, including area code)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

[ ]    Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

[ ]    Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

[ ]    Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

[ ]    Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:
Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock - $2.50 par value	NJR	New York Stock Exchange

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

Emerging growth company     [ ]

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

Item 8.01    Other Events

New Jersey Resources Corp. (“NJR”) is filing this Current Report on Form 8-K to retrospectively revise certain financial information and related disclosures included in its Annual Report on Form 10-K for the fiscal year ended September 30, 2020 (“2020 Form 10-K”), which was filed with the U.S. Securities and Exchange Commission (“SEC”) on November 30, 2020.

As previously disclosed in NJR’s Quarterly Report on Form 10-Q for the quarter ended December 31, 2020, NJR changed its method of accounting for federal investment tax credits (“ITCs”) at Clean Energy Ventures from the flow through method to the deferral method, effective October 1, 2020. NJRCEV, which is NJR’s clean energy subsidiary, comprises the Clean Energy Ventures segment and consists of NJR’s capital investments in commercial and residential solar projects.

Prior to the change, NJR recognized ITCs as a reduction of income tax expense in the period that the qualified solar energy property, to which it relates, was placed in service. Effective with the accounting change, NJR records ITCs as a reduction to the carrying value of the related asset when placed in service and recognizes ITCs in earnings as a reduction to depreciation expense over the productive life of the related property.

The deferral method is considered the preferred method per the authoritative guidance as described in ASC 740 – Income Taxes. The change to the deferral method is also consistent with the application of authoritative accounting guidance throughout other reporting segments and promotes proper matching of the benefits of the recognition of the ITC with the expected use of the asset.

To reflect the change in the method of accounting for ITCs from the flow through method to the deferral method, the following Items of the 2020 Form 10-K have been revised retrospectively (which Items are revised as presented in Exhibit 99.1 hereto and incorporated by reference herein):

•Part I, Item 1. Business

•Part II, Item 6. Selected Financial Data

•Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

•Part II, Item 8. Financial Statements and Supplementary Data.

The information included in this Form 8-K is presented for information purposes only in connection with the reporting changes described above and does not amend or restate other information within NJR’s audited consolidated financial statements, which were included in the 2020 Form 10-K. This Form 8-K does not reflect events occurring after NJR filed the 2020 Form 10-K and does not in any way modify or update the disclosures therein, other than to illustrate the changes made based on the changes in accounting for ITCs from the flow through method to the deferral method as described above. For developments subsequent to the filing of the 2020 Form 10-K, refer to NJR’s Quarterly Reports on Form 10-Q for the quarterly periods ended December 31, 2020, March 31, 2021 and June 30, 2021, as well as other filings NJR files with the SEC. The information in this Current Report on Form 8-K should be read in conjunction with the 2020 Form 10-K and such subsequent filings. All other information in the 2020 Form 10-K remains unchanged.

Cautionary Statements Regarding Forward-Looking Statements

Certain statements contained in this Current Report on Form 8-K, including, without limitation, statements as to management expectations, assumptions and beliefs presented in Part I, Item 1. “Business,” Part II, Item 7. “Management's Discussion and Analysis of Financial Condition and Results of Operations” and in the notes to the financial statements in Part II, Item 8. “Financial Statements and Supplementary Data” are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995. Forward-looking statements can also be identified by the use of forward-looking terminology such as “anticipate,” “estimate,” “may,” “could,” “might,” “intend,” “expect,” “believe,” “will” “plan,” or “should,” or comparable terminology and are made based upon management's current expectations, assumptions and beliefs as of this date concerning future developments and their potential effect on us. There can be no assurance that future developments will be in accordance with management's

expectations, assumptions or beliefs, or that the effect of future developments on us will be those anticipated by management.

We caution readers that the expectations, assumptions and beliefs that form the basis for forward-looking statements regarding customer growth, customer usage, qualifications for ITCs, RECs, future rate case proceedings, financial condition, results of operations, cash flows, capital requirements, future capital expenditures, market risk, effective tax rate and other matters for fiscal 2021 and thereafter include many factors that are beyond our ability to control or estimate precisely, such as estimates of future market conditions, the behavior of other market participants and changes in the debt and equity capital markets.

Additional information and factors that could cause actual results to differ materially from NJR’s expectations are contained in NJR’s filings with the SEC, including NJR’s Annual Reports on Form 10-K and subsequent Quarterly Reports on Form 10-Q, recent Current Reports on Form 8-K, and other SEC filings, which are available at the SEC’s web site, http://www.sec.gov. Information included in this filing is representative as of today only and while NJR periodically reassesses material trends and uncertainties affecting NJR’s results of operations and financial condition in connection with its preparation of management’s discussion and analysis of results of operations and financial condition contained in its Quarterly and Annual Reports filed with the SEC, NJR does not, by including this statement, assume any obligation to review or revise any particular forward-looking statement referenced herein in light of future events. The factors that could cause actual results to differ materially from our expectations, assumptions and beliefs include, but are not limited to, those discussed in Item 1A. Risk Factors of our 2020 Form 10-K, as well as the following:

•risks related to the impact of COVID-19 on business operations, financial performance and condition and cash flows;

•our ability to obtain governmental and regulatory approvals, land-use rights, electric grid connection (in the case of clean energy projects) and/or financing for the construction, development and operation of our unregulated energy investments, pipeline transportation systems and NJNG and Storage and Transportation infrastructure projects, including PennEast and Adelphia Gateway, in a timely manner;

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

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

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

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

•the performance of our subsidiaries;

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

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

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

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

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

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

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

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

•our ability to comply with debt covenants;

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

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

•the impact to the asset values and resulting higher costs and funding obligations of our pension and postemployment benefit plans as a result of potential downturns in the financial markets, lower

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

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

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

•our ability to optimize our physical assets;

•weather and economic conditions;

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

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

•changes to tax laws and regulations;

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

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

•risks related to our employee workforce and succession planning;

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

•risks associated with keeping pace with technological change.

While we periodically reassess material trends and uncertainties affecting our results of operations and financial condition in connection with the preparation of management's discussion and analysis of results of operations and financial condition contained in our Quarterly and Annual Reports on Form 10-Q and Form 10-K, respectively, we do not, by including this statement, assume any obligation to review or revise any particular forward-looking statement referenced herein in light of future events.

Item 9.01     Financial Statements and Exhibits. 

(d) Exhibits.

Exhibit Number     Exhibit Description

23.1*    Consent of Deloitte & Touche LLP

99.1*    Updates, where applicable, to Part I, Item 1. Business, Part II, Item 6. Selected Financial Data, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and Part II, Item 8. Financial Statements and Supplementary Data from NJR’s Annual Report on Form 10-K for the year ended September 30, 2020, as filed with the U.S. Securities and Exchange Commission on November 30, 2020

101*    Interactive Data File (Financial statements from NJR’s Annual Report on Form 10-K for the year ended September 30, 2020, as retrospectively revised to reflect the change in the method of accounting for ITCs, furnished in iXBRL (Inline eXtensible Business Reporting Language))

104    Cover Page Interactive Data File included in Exhibit 101

    * Filed herewith.

SIGNATURE

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

	NEW JERSEY RESOURCES CORPORATION
Date: September 24, 2021	By:	/s/ Patrick J. Migliaccio
		Patrick J. Migliaccio
		Senior Vice President and Chief Financial Officer

EX-23.1

EXHIBIT 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statement No. 333-164572 and No. 333-215728 on Form S-8 and Registration Statement Nos. 333-227603 and 333-235348 on Form S-3 of our report dated November 30, 2020 (September 24, 2021, as to the effects of the change in accounting policy discussed in Note 2), relating to the financial statements of New Jersey Resources Corporation appearing in the Current Report on Form 8-K of New Jersey Resources Corporation filed September 24, 2021.

/s/ Deloitte & Touche LLP

Parsippany, New Jersey

September 24, 2021

EX-99.1

New Jersey Resources Corporation Exhibit 99.1

Part I

ITEM 1. BUSINESS                                                                                                                                                                         

ORGANIZATIONAL STRUCTURE

New Jersey Resources Corporation is a New Jersey corporation formed in 1981 pursuant to a corporate reorganization. We are a diversified energy services holding company whose principal business is the distribution of natural gas through a regulated utility, providing other retail and wholesale energy services to customers and investing in clean energy projects and natural gas storage and transportation assets. We are an exempt holding company under section 1263 of the Energy Policy Act of 2005.

Our primary subsidiaries include:

New Jersey Natural Gas Company provides regulated retail natural gas utility service to approximately 558,000 residential and commercial customers throughout Monmouth, Ocean, Morris, Middlesex and Burlington counties in New Jersey and participates in the off-system sales and capacity release markets. NJNG, a local natural gas distribution company, is regulated by the BPU and comprises the Company’s Natural Gas Distribution segment and is referred to herein as NJNG or Natural Gas Distribution.

NJR Clean Energy Ventures Corporation includes the results of operations and assets related to the Company’s unregulated capital investments in clean energy projects, including commercial and residential solar projects. NJRCEV comprises the Company’s Clean Energy Ventures segment and is referred to herein as Clean Energy Ventures.

NJR Energy Services Company maintains and transacts around a portfolio of physical assets consisting of natural gas transportation and storage contracts in the U.S. and Canada. NJRES also provides unregulated wholesale energy management services to other energy companies and natural gas producers. NJRES comprises our Energy Services segment and is referred to herein as Energy Services.

NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, formerly known as the Midstream segment, invests in energy-related ventures through its subsidiaries. Investments include NJR Steckman Ridge Storage Company, which holds our 50 percent combined ownership interest in Steckman Ridge, located in Pennsylvania, and NJR Midstream Company, formerly NJR Pipeline Company, which includes our 20 percent ownership interest in PennEast, our wholly-owned subsidiaries of Leaf River, located in southeastern Mississippi, and Adelphia Gateway, located in eastern Pennsylvania, and are subject to FERC regulation. See Note 7. Investments in Equity Investees for more information on Steckman Ridge and PennEast.

NJR Home Services Company provides heating, ventilation and cooling service, sales and installation of appliances to approximately 107,000 service contract customers, as well as solar installation projects, and is the primary contributor to Home Services and Other operations.

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Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

REPORTING SEGMENTS

We operate within four reporting segments: Natural Gas Distribution, Clean Energy Ventures, Energy Services and Storage and Transportation, formerly known as Midstream.

The Natural Gas Distribution segment consists of regulated natural gas services, off-system sales, capacity and storage management operations. The Energy Services segment consists of unregulated wholesale and retail energy operations, as well as energy management services. The Clean Energy Ventures segment consists of capital investments in clean energy projects. The Storage and Transportation segment consists of investments in the natural gas storage and transportation market, such as natural gas storage and transportation facilities.

Net income by reporting segment and other business operations for the fiscal years ended September 30, are as follows:

Energy Services incurred a net loss of $11 million and $1.3 million in fiscal 2020 and 2019, respectively, which is not shown clearly in the above graph.

Assets composition by reporting segment and other business operations at September 30, are as follows:

2020 2019

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Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

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

Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP, and should be considered in addition to, and not as a substitute for, the comparable GAAP measure. The following is a reconciliation of consolidated net income, the most directly comparable GAAP measure, to NFE for the fiscal years ended September 30:

(Thousands)	2020		2019		2018
Net income	$	163,007	$	123,935	$	231,013
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(9,644)		2,881		26,770
Tax effect	2,296		(711)		(4,512)
Effects of economic hedging related to natural gas inventory	12,690		4,309		(22,570)
Tax effect	(3,016)		(1,024)		7,362
NFE (1)	$	165,333	$	129,390	$	238,063
Basic earnings per share	$	1.72	$	1.39	$	2.63
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(0.10)		0.03		0.31
Tax effect	0.02		(0.01)		(0.05)
Effects of economic hedging related to natural gas inventory	0.13		0.05		(0.26)
Tax effect	(0.03)		(0.01)		0.08
Basic NFE per share	$	1.74	$	1.45	$	2.71

(1)    NFE during fiscal 2018 was $59.6 million, or $0.68 per share, higher due to the revaluation of deferred taxes resulting from the reduction in the federal corporate tax rate related to the Tax Act.

NFE by reporting segment and other business operations for the fiscal years ended September 30, are as follows:

NFE at Energy Services had a loss of $7.9 million in fiscal 2020 and income of $2.9 million in fiscal 2019, which is not shown clearly in the above graph.

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Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

Natural Gas Distribution

General

Our Natural Gas Distribution segment consists of regulated utility operations that provide natural gas service to approximately 558,000 customers. NJNG’s service territory includes Monmouth, Ocean, Morris, Middlesex and Burlington counties in New Jersey. It encompasses 1,516 square miles, covering 105 municipalities with an estimated population of 1.5 million people. It is primarily suburban, highlighted by approximately 100 miles of New Jersey coastline. It is in close proximity to New York City, Philadelphia and the metropolitan areas of northern New Jersey and is accessible through a network of major roadways and mass transportation.

NJNG’s business is subject to various risks, such as those associated with adverse economic conditions, which can negatively impact customer growth and operating and financing costs; fluctuations in commodity prices, which can impact customer usage; customer conservation efforts; certain regulatory actions; and environmental remediation. It is often difficult to predict the impact of trends associated with these risks. NJNG employs strategies to manage the challenges it faces, including pursuing customer conversions from other fuel sources and monitoring new construction markets through contact with developers, utilizing incentive programs through BPU-approved mechanisms to reduce natural gas costs, pursuing rate and other regulatory strategies designed to stabilize and decouple gross margin, and working actively with consultants and the NJDEP to manage expectations related to its obligations associated with its former MGP sites.

Operating Revenues/Throughput

For the fiscal years ended September 30, operating revenues and throughput by customer class for our Natural Gas Distribution segment are as follows:

	2020			2019			2018
($ in thousands)	Operating Revenue (2)		Bcf	Operating Revenue (2)		Bcf	Operating Revenue		Bcf
Residential	$	500,271	44.6	$	450,515	46.0	$	441,486	45.5
Commercial and other	98,463		8.2	104,372		9.7	95,351		8.9
Firm transportation	66,871		13.3	57,513		13.7	65,256		15.5
Total residential and commercial	665,605		66.1	612,400		69.4	602,093		69.9
Interruptible	6,322		30.9	6,637		39.0	7,522		46.2
Total system	671,927		97.0	619,037		108.4	609,615		116.1
BGSS incentive programs (1)	57,996		118.4	91,756		37.8	122,250		42.8
Total	$	729,923	215.4	$	710,793	146.2	$	731,865	158.9

(1)Does not include 86.3, 86 and 107.4 Bcf for the capacity release program and related amounts of $3.1 million, $4.1 million and $5.7 million, which are recorded as a reduction of natural gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30, 2020, 2019 and 2018, respectively.

(2)Operating revenue presents sales tax, net during fiscal 2020 and 2019, due to the adoption of ASC 606, Revenue from Contracts with Customers. During fiscal 2018, operating revenue only included sales tax on operating revenues excluding tax-exempt sales.

NJNG added 8,349 and 9,711 new customers and added natural gas heat and other services to another 260 and 218 existing customers in fiscal 2020 and 2019, respectively. NJNG expects its new customer annual growth rate to continue to be approximately 1.7 percent with projected additions in the range of approximately 28,000 to 30,000 new customers over the next three fiscal years. This anticipated customer growth represents approximately $6.3 million in new annual utility gross margin, a non-GAAP financial measure, as calculated under NJNG’s current CIP tariff. For a definition of utility gross margin see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution Segment.

In fiscal 2020, no single customer represented more than 10 percent of consolidated operating revenues.

Seasonality of Natural Gas Revenues

Therm sales are significantly affected by weather conditions, with customer demand being greatest during the winter months when natural gas is used for heating purposes. The relative measurement of the impact of weather is in degree-days. Degree-day data is used to estimate amounts of energy required to maintain comfortable indoor temperature levels based on each day’s average temperature. A degree-day is the measure of the variation in the weather based on the extent to which the average daily temperature falls below 65 degrees Fahrenheit. Each degree of temperature below 65 degrees Fahrenheit is counted as one heating degree-day. Normal heating degree-days are based on a 20-year average, calculated based on three reference areas representative of NJNG’s service territory.

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Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

The CIP, a mechanism authorized by the BPU, stabilizes NJNG’s utility gross margin, regardless of variations in weather. In addition, the CIP decouples the link between utility gross margin and customer usage, allowing NJNG to promote energy conservation measures. Recovery of utility gross margin is subject to additional conditions, including an earnings test, a revenue test and an evaluation of BGSS-related savings achieved over a 12-month period. In May 2014, the BPU approved the continuation of the CIP program.

Concurrent with its annual BGSS filing, NJNG files for an annual review of its CIP, during which time it can request rate changes, as appropriate. For additional information regarding the CIP, including rate actions and impact to margin, see Note 4. Regulation in the accompanying Consolidated Financial Statements and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution Segment.

Natural Gas Supply

Firm Natural Gas Supplies

In fiscal 2020, NJNG purchased natural gas from approximately 65 suppliers under contracts ranging from one day to one year and purchased over 10 percent of its natural gas from one supplier. NJNG believes the loss of this supplier would not have a material adverse impact on its results of operations, financial position or cash flows, as an adequate number of alternative suppliers exist. NJNG believes that its supply strategy should adequately meet its expected firm load for the upcoming winter season.

Firm Transportation and Storage Capacity

NJNG maintains agreements for firm transportation and storage capacity with several interstate pipeline companies to take delivery of firm natural gas supplies, which ensures the ability to reliably service its customers. NJNG receives natural gas at 10 citygate stations located in Middlesex, Morris and Passaic counties in New Jersey.

The pipeline companies that provide firm transportation service to NJNG’s citygate stations, the maximum daily deliverability of that capacity and the contract expiration dates are as follows:

Pipeline	Dths(1)	Expiration
Texas Eastern Transmission, L.P.	300,738	Various dates between 2021 and 2025
Columbia Gas Transmission Corp.	50,000	Various dates between 2024 and 2030
Tennessee Gas Pipeline Co.	55,166	Various dates between 2021 and 2024
Transcontinental Gas Pipe Line Corp.	210,606	Various dates between 2021 and 2033
Algonquin Gas Transmission	12,000	2022
Total	628,510

(1)    Numbers are shown net of any capacity release contracted amounts.

Eastern Gas Transmission and Storage, Inc., formerly known as Dominion Energy Transmission, Inc. provides NJNG firm contract transportation service and supplies the pipelines included in the table above.

In addition, NJNG has storage contracts that provide an additional 102,941 Dths of maximum daily deliverability to NJNG’s citygate stations from storage fields in its Northeast market area. The storage suppliers, the maximum daily deliverability of that storage capacity and the contract expiration dates are as follows:

Pipeline	Dths	Expiration
Texas Eastern Transmission, L.P.	94,557	2022
Transcontinental Gas Pipe Line Corp.	8,384	2028
Total	102,941

NJNG also has upstream storage contracts. The maximum daily deliverability and contract expiration dates are as follows:

Company	Dths	Expiration
Eastern Gas Transmission and Storage, Inc.	251,829	Various dates between 2023 and 2026
Steckman Ridge, L.P.	38,000	2025
Central New York Oil & Gas	25,337	2023
Total	315,166

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Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

NJNG utilizes its transportation contracts to transport natural gas to NJNG’s citygates from the Eastern Gas Transmission and Storage, Inc., Steckman Ridge and Stagecoach Pipeline & Storage Company LLC storage fields. NJNG has sufficient firm transportation, storage and supply capacity to fully meet its firm sales contract obligations.

Citygate Supplies from Energy Services

NJNG has several citygate supply agreements with Energy Services. NJNG and Energy Services have an agreement where NJNG releases 10,000 Dths/day of TETCO capacity, 2,200 Dths/day of Eastern Gas Transmission and Storage, Inc. capacity, 10,728 Dths/day of Tennessee Gas Pipeline capacity and 1.6 million Dths of Stagecoach Pipeline & Storage Company LLC storage capacity to Energy Services for the period of April 1, 2019 to March 31, 2021. NJNG can call upon a supply of up to 20,000 Dths/day delivered to NJNG’s TETCO citygate. Energy Services manages the storage inventory and NJNG can call on that storage supply as needed at NJNG’s Tennessee citygate or storage point.

NJNG also has agreements where it releases 160,000 Dths/day of its TETCO capacity to Energy Services for the period of April 1, 2018 to October 31, 2021. Under these agreements, NJNG can call upon a supply of up to 160,000 Dths/day delivered to its TETCO citygate as needed. See Note 18. Related Party Transactions in the accompanying Consolidated Financial Statements for additional information regarding these transactions.

Peaking Supply

To manage its winter peak day demand, NJNG maintains two LNG facilities with a combined deliverability of approximately 170,000 Dths/day, which represents approximately 18 percent of its estimated peak day sendout. NJNG’s liquefaction facility allows NJNG to convert natural gas into LNG to fill NJNG’s existing LNG storage tanks. See Item 2. Properties - Natural Gas Distribution for additional information regarding the LNG storage facilities.

Basic Gas Supply Service

BGSS is a BPU-approved clause designed to allow for the recovery of natural gas commodity costs on an annual basis. The clause requires all New Jersey natural gas utilities to make an annual filing by each June 1 for review of BGSS rates and to request a potential rate change effective the following October 1. The BGSS also allows each natural gas utility to provisionally increase residential and small commercial customer BGSS rates on December 1 and February 1 for up to a five percent increase to the average residential heat customer’s bill on a self-implementing basis with proper notice. Such increases are subject to subsequent BPU review and final approval.

In addition to making periodic rate adjustments to reflect changes in commodity prices, NJNG is also permitted to refund or credit back a portion of the commodity costs to customers when the natural gas commodity costs decrease in comparison to amounts projected or to amounts previously collected from customers. Decreases in the BGSS rate and BGSS refunds can be implemented with five days’ notice to the BPU. Rate changes, as well as other regulatory actions related to BGSS, are discussed further in Note 4. Regulation in the accompanying Consolidated Financial Statements.

Wholesale natural gas prices are, by their nature, volatile. NJNG mitigates the impact of volatile price changes on customers through the use of financial derivative instruments, which are part of its storage incentive program and its BGSS clause.

Future Natural Gas Supplies

NJNG expects to meet the natural gas requirements for existing and projected firm customers. If NJNG’s long-term natural gas requirements change, NJNG expects to renegotiate and restructure its contract portfolio to better match the changing needs of its customers and changing natural gas supply landscape.

Regulation and Rates

State

NJNG is subject to the jurisdiction of the BPU with respect to a wide range of matters such as base rates and regulatory rider rates, the issuance of securities, the safety and adequacy of service, the manner of keeping its accounts and records, the sufficiency of natural gas supply, pipeline safety, environmental issues, compliance with affiliate standards and the sale or encumbrance of its properties. See Note 4. Regulation in the accompanying Consolidated Financial Statements for additional information regarding NJNG’s rate proceedings.

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Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

Federal

FERC regulates rates charged by interstate pipeline companies for the transportation and storage of natural gas. This affects NJNG’s agreements with several interstate pipeline companies for the purchase of such services. Costs associated with these services are currently recoverable through the BGSS.

Competition

Although its franchises are nonexclusive, NJNG is not currently subject to competition from other natural gas distribution utilities with regard to the transportation of natural gas in its service territory. Due to significant distances between NJNG’s current large industrial customers and the nearest interstate natural gas pipelines, as well as the availability of its transportation tariff, NJNG currently does not believe it has significant exposure to the risk that its distribution system will be bypassed. Competition does exist from suppliers of oil, electricity and propane. At the present time, however, natural gas is used in over 95 percent of new construction due to its efficiency, reliability and price advantage. Natural gas prices are a function of market supply and demand. Although NJNG believes natural gas will remain competitive with alternate fuels, no assurance can be given in this regard.

The BPU, within the framework of the EDECA, fully opened NJNG’s residential markets to competition, including third-party suppliers, and restructured rates to segregate its BGSS and delivery (i.e., transportation) prices. New Jersey’s natural gas utilities must provide BGSS in the absence of a third-party supplier. On September 30, 2020, NJNG had 22,420 residential and 9,184 commercial and industrial customers utilizing the transportation service.

Clean Energy Ventures

Our Clean Energy Ventures segment invests in, owns and operates clean energy projects, including commercial and residential solar installations located in New Jersey, Connecticut and Rhode Island.

As of September 30, 2020, Clean Energy Ventures has constructed a total of 357.4 MW of solar capacity in New Jersey that has qualified for ITCs, including a combination of residential and commercial net-metered and grid-connected solar systems. As part of its solar investment program, Clean Energy Ventures operates a residential solar program, The Sunlight Advantage®, which provides qualifying homeowners with the opportunity to have a solar system installed at their home with no installation or maintenance expenses. Clean Energy Ventures owns, operates and maintains the system over the life of the lease in exchange for monthly lease payments. The program is operated by Clean Energy Ventures using qualified contracting partners in addition to strategic suppliers for material standardization and sourcing. The residential solar lease and PPA market is highly competitive, with a large number of companies operating in New Jersey. Clean Energy Ventures competes on price, quality and brand reputation, leveraging its partner network and customer referrals.

Clean Energy Ventures’ commercial solar projects are sourced through various channels and include both net-metered and grid-connected systems. Net-metered projects involve the sale of energy to a host and grid-connected systems into the wholesale energy markets. Project construction is competitively sourced through third parties. New Jersey has the sixth largest solar market in the U.S., according to the Solar Energy Industries Association®, with a large number of firms competing in all facets of the market including development, financing and construction.

Our solar systems are registered and certified with the BPU’s Office of Clean Energy and qualified to produce RECs. One REC is created for every MWh of electricity produced by a solar generator. Clean Energy Ventures sells SRECs generated to a variety of counterparties, including electric load-serving entities that serve electric customers in New Jersey and are required to comply with the solar carve-out of the Renewable Portfolio Standard, a regulation that requires the increased production of energy from renewable energy sources. Solar projects are also currently eligible for federal ITCs in the year that they are placed into service. In December 2019, the BPU established the TREC as the interim program 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.

Clean Energy Ventures is subject to various risks including those associated with adverse federal and state legislation and regulatory policies, construction delays that can impact the timing or eligibility of tax incentives, technological changes and the future market of SRECs and TRECs. See Item 1A. Risk Factors for additional information regarding these risks.

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New Jersey Resources Corporation

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ITEM 1. BUSINESS Continued)                                                                                                                                                     

Energy Services

Our Energy Services segment consists of unregulated wholesale and retail natural gas operations and provides producer and asset management services to a diverse customer base across North America. Energy Services has acquired contractual rights to natural gas transportation and storage assets it utilizes to implement its strategic and opportunistic market strategies. The rights to these assets were acquired in anticipation of delivering natural gas, performing asset management services for customers or identifying strategic opportunities that exist in or between the market areas that it serves. These opportunities are driven by price differentials between market locations and/or time periods. Energy Services’ activities are conducted in the market areas in which it has strong expertise, including the U.S. and Canada. Energy Services differentiates itself in the marketplace based on price, reliability and quality of service. Its competitors include wholesale marketing and trading companies, utilities, natural gas producers and financial institutions. Energy Services’ portfolio of customers includes regulated natural gas distribution companies, industrial companies, electric generators, natural gas/liquids processors, retail aggregators, wholesale marketers and natural gas producers.

While focusing on maintaining a low-risk operating and counterparty credit profile, Energy Services’ activities specifically consist of the following elements:

•Providing natural gas portfolio management services to nonaffiliated and our affiliated natural gas utility, electric generation facilities and natural gas producers;

•Managing strategies for new and existing natural gas transportation and storage assets to capture value from changes in price due to location or timing differences as a means to generate financial margin (as defined below);

•Managing transactional logistics to minimize the cost of natural gas delivery to customers while maintaining security of supply. Transactions utilize the most optimal and advantageous natural gas supply transportation routing available within its contractual asset portfolio and various market areas; and

•Managing economic hedging programs that are designed to mitigate the impact of changes in market prices on financial margin generated on its natural gas transportation and storage commitments.

In fiscal 2020, Energy Services did not purchase over 10 percent of its natural gas from any one supplier.

Transportation and Natural Gas Storage Transactions

Energy Services focuses on creating value from the use of its physical assets, which are typically amassed through contractual rights to natural gas transportation and storage capacity. These assets become more valuable when favorable price changes occur that impact the value between or within market areas and across time periods. On a forward basis, Energy Services may hedge these price differentials through the use of financial instruments. In addition, Energy Services may seek to optimize these assets on a daily basis, as market conditions warrant, by evaluating natural gas supply and transportation availability within its portfolio. This enables Energy Services to capture geographic pricing differences across various regions, as delivered natural gas prices may change favorably as a result of market conditions. Energy Services may, for example, initiate positions when intrinsic financial margin is present, and then enhance that financial margin as prices change across regions or time periods.

Energy Services also engages in park-and-loan transactions with storage and pipeline operators, where Energy Services will either borrow (receive a loan of) natural gas with an obligation to repay the storage or pipeline operator at a later date or “park” natural gas with an obligation to withdraw at a later date. In these cases, Energy Services evaluates the economics of the transaction to determine if it can capture pricing differentials in the marketplace and generate financial margin. Energy Services evaluates deal attributes such as fixed fees, calendar spread value from deal inception until volumes are scheduled to be returned and/or repaid, as well as the time value of money. If this evaluation demonstrates that financial margin exists, Energy Services may enter into the transaction and hedge with natural gas futures contracts, thereby locking in financial margin.

Energy Services maintains inventory balances to satisfy existing or anticipated sales of natural gas to its counterparties and/or to create additional value, as described above. During fiscal 2020 and 2019, Energy Services managed and sold 526.7 Bcf and 584.9 Bcf of natural gas, respectively. In addition, as of September 30, 2020 and 2019, Energy Services had 34.3 Bcf or $57.4 million of natural gas in storage and 25.6 Bcf or $52.4 million of natural gas in storage, respectively.

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ITEM 1. BUSINESS Continued)                                                                                                                                                     

Weather/Seasonality

Energy Services activities are typically seasonal in nature as a result of changes in the supply and demand for natural gas. Demand for natural gas is generally higher during the winter months when there may also be supply constraints; however, during periods of milder temperatures, demand can decrease. In addition, demand for natural gas can also be high during periods of extreme heat in the summer months, resulting from the need for additional natural gas supply for natural gas-fired electric generation facilities. Accordingly, Energy Services can be subject to variations in earnings and working capital throughout the year as a result of changes in weather.

Volatility

Energy Services’ activities are also subject to price volatility or supply/demand dynamics within its North American wholesale markets, including in the Northeastern, Appalachian, Mid-Continent and Southeast regions. Changes in natural gas supply can affect capacity values and Energy Services’ financial margin, which, as described below, is generated from the optimization of transportation and storage assets. With its focus on risk management, Energy Services continues to diversify its revenue stream by identifying new growth opportunities in producer and asset management services. Energy Services monitors changing market dynamics and strategically adjusts its portfolio of transportation and storage assets, which currently includes an average of approximately 35bcf of firm storage and 1.4bcf/d of firm transportation capacity.

Financial Margin

To economically hedge the commodity price risk associated with its existing and anticipated commitments for the purchase and sale of natural gas, Energy Services enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial swaps and options. These derivative instruments are accounted for at fair value with changes in fair value recognized in earnings as they occur. Energy Services views “financial margin” as a key internal financial metric. Energy Services’ financial margin, which is a non-GAAP financial measure, represents revenues earned from the sale of natural gas less costs of natural gas sold including any transportation and storage costs, and excluding any accounting impact from changes in the fair value of certain derivative instruments. For additional information regarding financial margin, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Energy Services Segment.

Risk Management

In conducting its business, Energy Services mitigates risk by following formal risk management guidelines, including transaction limits, segregation of duties and formal contract and credit review approval processes. Energy Services continuously monitors and seeks to reduce the risk associated with its counterparty credit exposures. Our Risk Management Committee oversees compliance with these established guidelines.

Storage and Transportation

Our Storage and Transportation segment, formerly known as our Midstream segment, includes investments in FERC-regulated interstate natural gas storage and transportation assets and is comprised of the following subsidiaries:

•NJR Steckman Ridge Storage Company, which holds our 50 percent equity investment in Steckman Ridge. Steckman Ridge is a Delaware limited partnership, jointly owned and controlled by our subsidiaries and subsidiaries of Enbridge Inc., which built, owns and operates a natural gas storage facility with up to 12 Bcf of working natural gas capacity in Bedford County, Pennsylvania. The facility has direct access to the TETCO and Eastern Gas Transmission and Storage, Inc. pipelines and has access to the Northeast and Mid-Atlantic markets; and

•NJR Midstream Company, formerly NJR Pipeline Company, which includes our 20 percent equity investment in PennEast, which is expected to construct a 120-mile, FERC-regulated interstate natural gas pipeline system that will extend from northern Pennsylvania to western New Jersey; Leaf River Energy Center LLC, which owns and operates a 32.2 million Dth salt dome natural gas facility, located in southeastern Mississippi; and FERC-regulated Adelphia Gateway, an indirect wholly-owned subsidiary of NJR, which acquired all of Talen’s membership interests in IEC, an existing 84-mile pipeline in southeastern Pennsylvania. See Note 19. Acquisitions and Dispositions for more information.

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ITEM 1. BUSINESS Continued)                                                                                                                                                     

OTHER BUSINESS OPERATIONS

Home Services and Other

Home Services and Other operations consist primarily of the following unregulated affiliates:

•NJRHS, which provides heating, ventilation and cooling service, sales and installation of appliances to approximately 107,000 service contract customers, as well as installation of solar equipment;

•NJR Plumbing Services, Inc., which provides plumbing repair and installation services;

•New Jersey Resources Corporation, a diversified energy services holding company;

•CR&R, which holds commercial real estate; and

•NJR Service Corporation, which provides shared administrative and financial services to the Company and all of its subsidiaries and affiliates.

ENVIRONMENT

We, along with our subsidiaries, are subject to legislation and regulation by federal, state and local authorities with respect to environmental matters. We believe that we are, in all material respects, in compliance with all applicable environmental laws and regulations.

NJNG is responsible for the environmental remediation of identified former MGP sites, which contain contaminated residues from former gas manufacturing operations that ceased at these sites by the mid-1950s and, in some cases, had been discontinued many years earlier. NJNG periodically, and at least annually, performs an environmental review of the former MGP sites, including a review of potential estimated liabilities related to the investigation and remedial action on these sites. Based on this review, NJNG has estimated that the total future expenditures to remediate and monitor the former MGP sites for which it is responsible will range from approximately $143.1 million to $181.7 million.

NJNG’s estimate of these liabilities is based upon known and measurable facts, existing technology and enacted laws and regulations in place when the review was completed in fiscal 2020. 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. As of September 30, 2020, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $150.6 million on the Consolidated Balance Sheets, based on the most likely amount; however, actual costs may differ from these estimates.

HUMAN CAPITAL RESOURCES

Employee Overview

NJR fundamentally believes that its employees make the Company a unique, successful organization – in creativity, commitment, ingenuity, hard work and innovation. NJR employees fulfill the responsibilities that enable the Company to deliver natural gas service to its customers; to be a leader in clean energy investments; to grow its storage and transportation energy business; and, to earn the loyalty of its retail home services customers. NJR also is committed to provide every appropriate resource to ensure its employees’ safety. Through initiatives that start at the top, NJR has invested time, energy and manpower to foster a culture where safety is top-of-mind at all times, and where achieving safety goals is a shared priority for every NJR employee.

As of September 30, 2020, the Company and our subsidiaries employed 1,156 employees compared with 1,108 employees as of September 30, 2019. Of the total number of employees, NJNG had 469 and 460 and NJRHS had 101 and 101 Union or Represented employees as of September 30, 2020 and 2019, respectively. NJNG and NJRHS have collective bargaining agreements with the Union, which is affiliated with the American Federation of Labor and Congress of Industrial Organizations, that expire on December 7, 2021 and April 2, 2023, respectively. The labor agreements cover wage increases and other benefits, including the defined benefit pension (which was closed to all employees hired on or after January 1, 2012, with the exception of certain rehires who are eligible to resume active participation), the postemployment benefit plan (which was closed to all employees hired on or after January 1, 2012) and the enhanced 401(k) retirement savings plan. We consider our relationship with employees, including those covered by collective bargaining agreements, to be in good standing.

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New Jersey Resources Corporation

Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

The Company depends on its key personnel to successfully operate its businesses, including its executive officers, senior corporate management and management at its operating units. NJR seeks to attract and retain its employees by offering competitive compensation packages including base and incentive compensation (and in certain instances share-based compensation and retention incentives), attractive benefits and opportunities for advancement and rewarding careers. NJR periodically reviews and adjusts, if needed, its employees’ total compensation (including salaries, annual cash incentive compensation, other cash and equity incentives, and benefits) to ensure that it is competitive within the industry and is consistent with our level of performance. NJR has also implemented enterprise-wide talent development and succession planning programs designed to identify future and/or replacement candidates for key positions. In addition to compensation, NJR promotes numerous charitable, philanthropic, and social awareness programs that not only support the communities served, but also provide experiences for employees to promote a collaborative and rewarding work environment.

Further, in order to take advantage of available opportunities and successfully implement our long-term strategy, NJR must be able to employ, train and retain the necessary skilled personnel. As a result, NJR supports and utilizes various training and educational programs and has developed additional company-wide and project-specific employee training and educational programs. NJR continues key programs focused on employee safety, leadership development, work-life balance, talent management, health and wellness, diversity and inclusion as well as employee engagement. Moreover, diversity, inclusion and employee engagement are integral to NJR’s vision, strategy and business success. NJR prides itself on a culture that respects co-workers and values concern for others. Fostering an environment that values diversity, inclusion and ethics helps create an inclusive organization that is able to embrace, leverage and respect the differences of employees, customers and the communities where we live, work and serve.

NJR regularly evaluates employees and their productivity against future demand expectations and historical trends. NJR employees continue to maintain high levels of engagement, satisfaction and retention according to NJR’s annual employee survey. From time to time, NJR may reduce or add resources in certain areas in an effort to align with changing demands.

NJR’s Board of Directors’ Role in Human Capital Resource Management

NJR’s Board of Directors believes that human capital management is an important component of the Company’s continued growth and success, and is essential for our ability to attract, retain and develop talented and skilled employees. We pride ourselves on a culture that respects co-workers and values concern for others.

Management regularly reports to the LDCC of the Board of Directors on human capital management topics, including corporate culture, diversity and inclusion, employee development and compensation and benefits. The LDCC has oversight of talent retention and development and succession planning, and the Board of Director’s provides input on important decisions in each of these areas.

Each year, NJR conducts an employee feedback survey designed to help the Company measure overall employee engagement. The feedback employees provide during the survey helps NJR evaluate employee programs and benefits and monitor its current practices for potential areas of improvement. The LDCC maintains oversight of matters related to human capital management and in that capacity reviews the results of the employee feedback survey.

Employee Benefits

The LDCC believes employee benefits are an essential component of the Company’s competitive total compensation package. These benefits are designed to attract and retain our employees and include medical, health and dental insurance, long-term disability insurance, accidental death and disability insurance, travel and accident insurance, and our 401(k) Plan. As part of the 401(k) Plan, NJR generally matches 80 percent of the first 6 percent of compensation contributed by the employee into the 401(k) Plan, subject to the Internal Revenue Code and NJR’s 401(k) Plan limits. The matching contribution is limited to 70 percent for represented employees of NJRHS. Additionally, for employees who are not eligible to participate in the defined benefit plans, NJR contributes between 3.5 percent and 4.5 percent of base compensation, depending upon years of service, into the 401(k) Plan on their behalf.

AVAILABLE INFORMATION AND CORPORATE GOVERNANCE DOCUMENTS

The following reports and any amendments to those reports are available free of charge on our website at https://investor.njresources.com/financials/sec-filings/default.aspx as soon as reasonably possible after filing or furnishing them with the SEC:

•Annual reports on Form 10-K;

•Quarterly reports on Form 10-Q; and

•Current reports on Form 8-K.

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Part I

ITEM 1. BUSINESS Continued)                                                                                                                                                     

The following documents are available free of charge on our website (https://investor.njresources.com/governance/governance-documents/default.aspx):

•Amended and Restated Bylaws;

•Corporate Governance Guidelines;

•Wholesale Trading Code of Conduct;

•NJR Code of Conduct;

•Charters of the following Board of Directors Committees: Audit, Leadership Development and Compensation and Nominating/Corporate Governance;

•Audit Complaint Procedure;

•Communicating with Non-Management Directors Procedure; and

•Statement of Policy with Respect to Related Person Transactions.

In Part III of this Form 10-K, we incorporate certain information by reference from our Proxy Statement for our 2021 Annual Meeting of Shareowners. We expect to file that Proxy Statement with the SEC on or about December 11, 2020. We will make it available on our website as soon as reasonably possible following that filing date. Please refer to the Proxy Statement when it is available.

A printed copy of each document is available free of charge to any shareowner who requests it by contacting the Corporate Secretary at New Jersey Resources Corporation, 1415 Wyckoff Road, Wall, New Jersey 07719.

INFORMATION ABOUT OUR EXECUTIVE OFFICERS

The Company’s Executive Officers and their age, position and business experience during the past five years are below.

Name	Age	Officer since	Business experience during last five years
Stephen D. Westhoven	52	2004	President and Chief Executive Officer (October 2019 - present) President and Chief Operating Officer (October 2018 - September 2019) Executive Vice President and Chief Operating Officer (November 2017 - September 2018) Senior Vice President and Chief Operating Officer, NJRES and NJRCEV (October 2016 -         October 2017) Senior Vice President, NJRES (May 2010 - September 2016)
Patrick J. Migliaccio	46	2013	Senior Vice President and Chief Financial Officer (January 2016 - present) Vice President, Finance and Accounting (November 2014 - December 2015)
Amanda E. Mullan	54	2015	Senior Vice President and Chief Human Resources Officer (January 2017 - present) Vice President and Chief Human Resources Officer (April 2015 - December 2016)
Amy Cradic	49	2018	Senior Vice President and Chief Operating Officer of Non-Utility Businesses, Strategy and External Affairs (March 2020 - present) Vice President, Corporate Strategy and External Affairs (January 2020 – February 2020) Vice President, Government Affairs and Policy (January 2018 – December 2019) Chief of Staff, Office of New Jersey Governor Chris Christie (April 2016 – January 2018) Chief Policy Advisor, Office of New Jersey Governor Chris Christie (December 2013 – March 2016)
Nancy A. Washington	56	2017	Senior Vice President and General Counsel (March 2017 - present) Senior Vice President and Chief Litigation Counsel, CIT Group Inc., a Livingston, NJ-based        financial services firm (September 2010 - March 2017)

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Part II

ITEM 6. SELECTED FINANCIAL DATA                                                                                                                                   

CONSOLIDATED FINANCIAL STATISTICS

(Thousands, except per share data)
Fiscal Years Ended September 30,	2020 (1)		2019 (1)		2018 (1)		2017		2016
SELECTED FINANCIAL DATA
Operating revenues	$	1,953,668	$	2,592,045	$	2,915,109	$	2,268,617	$	1,880,905
Natural gas purchases	$	1,304,719	$	2,044,302	$	2,275,342	$	1,703,767	$	1,352,686
Net income	$	163,007	$	123,935	$	231,013	$	132,065	$	131,672
Total assets	$	5,316,477	$	4,157,942	$	3,986,305	$	3,928,507	$	3,718,570
Common stock equity	$	1,643,896	$	1,381,833	$	1,294,664	$	1,114,752	$	1,166,591
Long-term debt (2) (3)	$	2,259,466	$	1,537,177	$	1,180,619	$	997,080	$	1,055,038
COMMON STOCK DATA
Earnings per share-basic	$1.72		$1.39		$2.63		$1.53		$1.53
Earnings per share-diluted	$1.71		$1.38		$2.62		$1.52		$1.52
Dividends declared per share	$1.27		$1.19		$1.11		$1.038		$0.975
NON-GAAP RECONCILIATION
Net income	$	163,007	$	123,935	$	231,013	$	132,065	$	131,672
Add:
Unrealized loss (gain) on derivative instruments and related transactions	(9,644)		2,881		26,770		(11,241)		46,883
Tax effect	2,296		(711)		(4,512)		4,062		(17,018)
Effects of economic hedging related to natural gas inventory	12,690		4,309		(22,570)		38,470		(36,816)
Tax effect	(3,016)		(1,024)		7,362		(13,964)		13,364
Net financial earnings (4)	$	165,333	$	129,390	$	238,063	$	149,392	$	138,085
Basic earnings per share	$1.72		$1.39		$2.63		$1.53		$1.53
Add:
Unrealized loss (gain) on derivative instruments and related transactions	(0.10)		0.03		0.31		(0.13)		0.55
Tax effect	0.02		(0.01)		(0.05)		0.05		(0.20)
Effects of economic hedging related to natural gas inventory	0.13		0.05		(0.26)		0.45		(0.43)
Tax effect	(0.03)		(0.01)		0.08		(0.17)		0.16
Net financial earnings per share-basic (4)	$1.74		$1.45		$2.71		$1.73		$1.61
Diluted earnings per share	$1.71		$1.38		$2.62		$1.52		$1.52
Add:
Unrealized loss (gain) on derivative instruments and related transactions	(0.10)		0.03		0.30		(0.13)		0.54
Tax effect	0.03		(0.01)		(0.05)		0.05		(0.20)
Effects of economic hedging related to natural gas inventory	0.13		0.05		(0.25)		0.44		(0.42)
Tax effect	(0.03)		(0.01)		0.08		(0.17)		0.15
Net financial earnings per share-diluted (4)	$1.74		$1.44		$2.70		$1.71		$1.59

(1)Certain amounts have been revised to reflect the retrospective application of the Company's accounting policy change regarding its method of accounting for ITCs. Please see Item 8. Note 2. Summary of Significant Accounting Policies for additional details regarding this accounting policy change.

(2)Includes long-term financial leases of $63.7 million, $25 million, $26.4 million, $28.9 million and $30.7 million, respectively.

(3)Includes long-term solar asset financing obligation of $105.5 million, $80.4 million, $89.8 million, $28.2 million and $0, respectively.

(4)NFE is a non-GAAP financial measure that eliminates the timing differences surrounding the recognition of certain derivative gains or losses, to effectively match the earnings effects of economic hedges associated with the physical sale or purchase of natural gas and, therefore, eliminate the impact of volatility to GAAP earnings associated with the related derivative instruments. For further discussion of this financial measure, see the Energy Services segment discussion in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

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New Jersey Resources Corporation

Part II

ITEM 6. SELECTED FINANCIAL DATA (Continued)                                                                                                             

NJNG OPERATING STATISTICS

Fiscal Years Ended September 30,	2020			2019			2018			2017			2016
Operating revenues ($ in thousands)
Residential	$	500,271		$	450,515		$	441,486		$	395,315		$	345,597
Commercial, industrial and other	98,463			104,372			95,351			98,777			80,994
Firm transportation	66,871			57,513			65,256			73,206			69,696
Total residential and commercial	665,605			612,400			602,093			567,298			496,287
Interruptible	6,322			6,637			7,522			7,970			8,867
Total system	671,927			619,037			609,615			575,268			505,154
BGSS incentive programs	57,996			91,756			122,250			120,369			89,192
Total operating revenues	$	729,923		$	710,793		$	731,865		$	695,637		$	594,346
Throughput (Bcf)
Residential	44.6			46.0			45.5			40.7			36.9
Commercial, industrial and other	8.2			9.7			8.9			8.7			7.3
Firm transportation	13.3			13.7			15.5			14.4			14.1
Total residential and commercial	66.1			69.4			69.9			63.8			58.3
Interruptible	30.9			39.0			46.2			55.0			61.5
Total system	97.0			108.4			116.1			118.8			119.8
BGSS incentive programs	118.4			123.8			150.2			178.4			216.7
Total throughput	215.4			232.2			266.3			297.2			336.5
Customers at year-end
Residential	497,779			486,474			474,495			460,013			448,273
Commercial, industrial and other	28,735			28,992			28,037			26,947			26,218
Firm transportation	31,604			32,107			36,126			42,790			46,608
Total residential and commercial	558,118			547,573			538,658			529,750			521,099
Interruptible	29			32			31			33			34
BGSS incentive programs	19			21			28			27			30
Total customers at year-end	558,166			547,626			538,717			529,810			521,163
Interest coverage ratio (1)	8.29			6.57			6.35			7.96			8.97
Average therm use per customer
Residential	895			945			959			885			824
Commercial, industrial and other	8,683			10,198			10,992			11,183			11,378
Degree days	4,254			4,506			4,537			4,129			3,867
Weather as a percent of normal (2)	92.8		%	99.0		%	99.5		%	90.0		%	82.5		%
Number of employees	721			709			686			680			670

(1)NJNG’s income from operations divided by interest expense.

(2)Normal heating degree days are based on a 20-year average, calculated based upon three reference areas representative of NJNG’s service territory.

(3)Operating revenue presents sales tax, net during fiscal 2020 and 2019, due to the adoption of ASC 606, Revenue from Contracts with Customers. Prior to fiscal 2019, operating revenue only included sales tax on operating revenues excluding tax-exempt sales.

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New Jersey Resources Corporation

Part II

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS                                                                                                                                                                                 

Critical Accounting Policies

We prepare our financial statements in accordance with GAAP. Application of these accounting principles requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingencies during the reporting period. We regularly evaluate our estimates, including those related to the calculation of the fair value of derivative instruments, regulatory assets, income taxes, pension and postemployment benefits other than pensions and contingencies related to environmental matters and litigation. We base our estimates 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. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.

Regulatory Accounting

NJNG maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and recognizes the impact of regulatory decisions on its financial statements. As a result of the ratemaking process, NJNG is required to apply the accounting principles in ASC 980, Regulated Operations, which differ in certain respects from those applied by unregulated businesses. Specifically, NJNG records regulatory assets when it is probable that certain operating costs will be recoverable from customers in future periods and records regulatory liabilities associated with probable future obligations to customers.

Regulatory decisions can have an impact on the recovery of costs, the rate of return earned on investment, and the timing and amount of assets to be recovered by rates. The BPU’s regulation of rates is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital. Decisions to be made by the BPU in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required. If the BPU indicates that recovery of all or a portion of a regulatory asset is not probable or does not allow for recovery of and a reasonable return on investments in property plant and equipment, a charge to income would be made in the period of such determination.

Environmental Costs

At the end of each fiscal year, NJNG, with the assistance of an independent consulting firm, updates the environmental review of its MGP sites, including its potential liability for investigation and remedial action. From this review, NJNG estimates expenditures necessary to remediate and monitor these MGP sites. NJNG’s estimate of these liabilities is developed from then-currently available facts, existing technology and current laws and regulations.

In accordance with accounting standards for contingencies, NJNG’s policy is to record a liability when it is probable that the cost will be incurred and can be reasonably estimated. NJNG will determine a range of liabilities and will record the most likely amount. If no point within the range is more likely than any other, NJNG will accrue the lower end of the range. Since we believe that recovery of these expenditures, as well as related litigation costs, is possible through the regulatory process, we have recorded a regulatory asset corresponding to the related accrued liability. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Consolidated Balance Sheets, which is 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 and the ultimate ability of other responsible parties to pay, as well as the potential impact of any litigation and any insurance recoveries. Previously incurred remediation costs, net of recoveries from customers and insurance proceeds received are included in regulatory assets on the Consolidated Balance Sheets.

If there are changes in the regulatory position surrounding these costs, or should actual expenditures vary significantly from estimates in that these costs are disallowed for recovery by the BPU, such costs would be charged to income in the period of such determination. See the Legal Proceedings section in Note 15. Commitments and Contingent Liabilities for more details.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Postemployment Employee Benefits

Our costs of providing postemployment employee benefits are dependent upon numerous factors, including actual plan experience and assumptions of future experience. Postemployment employee benefit costs are affected by actual employee demographics including age, compensation levels and employment periods, the level of contributions made to the plans, changes in long-term interest rates and the return on plan assets. Changes made to the provisions of the plans or healthcare legislation may also impact current and future postemployment employee benefit costs. Postemployment employee benefit costs may also be significantly affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets, changes in mortality tables, health care cost trends and discount rates used in determining the PBO. In determining the PBO and cost amounts, assumptions can change from period to period and could result in material changes to net postemployment employee benefit periodic costs and the related liability recognized by us.

The remeasurement of plan assets and obligations for a significant event should occur as of the date of the significant event. We may use a practical expedient to remeasure the plan assets and obligations as of the nearest calendar month-end date. When performing interim remeasurements, we obtain new asset values, roll forward the obligation to reflect population changes and review the appropriateness of all assumptions, regardless of the reason for performing the interim remeasurement.

Our postemployment employee benefit plan assets consist primarily of U.S. equity securities, international equity securities, fixed-income investments and other assets, with a targeted allocation of 34 percent, 17 percent, 38 percent and 11 percent, respectively. Fluctuations in actual market returns, as well as changes in interest rates, may result in increased or decreased postemployment employee benefit costs in future periods. Postemployment employee benefit expenses are included in O&M and other income, net on the Consolidated Statements of Operations.

The following is a summary of a sensitivity analysis for each actuarial assumption:

Pension Plans
Actuarial Assumptions	Increase/ (Decrease)		Estimated Increase/(Decrease) on PBO (Thousands)		Estimated Increase/(Decrease) to Expense (Thousands)
Discount rate	1.00	%		$(49,896)		$(4,671)
Discount rate	(1.00)	%		$62,361		$5,643
Rate of return on plan assets	1.00	%		n/a		$(2,840)
Rate of return on plan assets	(1.00)	%		n/a		$2,839

Other Postemployment Benefits
Actuarial Assumptions	Increase/ (Decrease)		Estimated Increase/(Decrease) on PBO (Thousands)			Estimated Increase/(Decrease) to Expense (Thousands)
Discount rate	1.00	%		$	(36,740)		$	(3,608)
Discount rate	(1.00)	%		$	47,260		$	4,486
Rate of return on plan assets	1.00	%		n/a			$	(898)
Rate of return on plan assets	(1.00)	%		n/a			$	898
Actuarial Assumptions	Increase/ (Decrease)		Estimated Increase/(Decrease) on PBO (Thousands)			Estimated Increase/(Decrease) to Expense (Thousands)
Health care cost trend rate	1.00	%		$	49,106		$	6,861
Health care cost trend rate	(1.00)	%		$	(38,844)		$	(5,383)

Acquisitions

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

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New Jersey Resources Corporation

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

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

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

Investments in Equity Investees

The Company accounts for its investments in Steckman Ridge and PennEast, using the equity method of accounting where it is not the primary beneficiary, as defined under ASC 810, Consolidation, in that its respective ownership interests are 50 percent or less and/or it has significant influence over operating and management decisions. The Company’s share of earnings is recognized as equity in earnings of affiliates on the Consolidated Statements of Operations.

Equity method investments are reviewed for impairment when changes in facts and circumstances indicate that the current fair value may be less than the asset’s carrying amount. Factors that the Company analyzes in determining whether an impairment in its equity investments exists include reviewing the financial condition and near-term prospects of the investees, including economic conditions and trends in the general market, significant delays in or failure to complete significant projects, unfavorable regulatory or legal actions expected to substantially impact future earnings potential and lower than expected cash distributions from investees. If the Company determines the decline in the value of its equity method investment is other than temporary, an impairment charge is recorded in an amount equal to the excess of the carrying value of the asset over its fair value.

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

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

On November 14, 2019, PennEast announced that it will ask the Supreme Court of the U.S. to review the September 2019 decision by the Third Circuit.

As a result of the adverse court rulings, the Company evaluated its investment in PennEast for impairment and determined an impairment charge was not necessary. The Company estimated the fair value of its investment using probability-weighted scenarios of discounted future cash flows. Management made significant estimates and assumptions related to development options and legal outcomes, construction costs, timing of capital investments and in-service dates, revenues and discount rates. The discounted cash flow scenarios contemplate the impact of key assumptions of potential future court decisions and potential future management decisions and require management to make significant estimates regarding the likelihood of various scenarios and assumptions. It is reasonably possible that future unfavorable developments, such as a reduced likelihood of success from development options and legal outcomes, estimated increases in construction costs, increases in the discount rate or further significant delays, could result in an impairment of our equity method investment. Also, the use of alternate judgments and assumptions could result in a different calculation of fair value, which could ultimately result in the recognition of an impairment charge in the Consolidated Financial Statements. Higher probabilities were assumed related to those scenarios where the project is completed.

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New Jersey Resources Corporation

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

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

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

For further information on these investments, see Note 7. Investments in Equity Investees.

Impairment of Long-lived assets

Property, plant and equipment and finite-lived intangible assets are reviewed periodically for impairment when changes in facts and circumstances indicate that the carrying amount of an asset may not be fully recoverable in accordance with the appropriate accounting guidance. Factors that the Company analyzes in determining whether an impairment in its long-lived assets exists include determining if a significant decrease in the market price of a long-lived asset is present; a significant adverse change in the extent in which a long-lived asset is being used in its physical condition; legal proceedings or factors; significant business climate changes, accumulations of costs in significant excess of the amounts expected; a current-period operating or cash flow loss coupled with historical negative cash flows or expected future negative cash flows; and current expectations that more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its estimated useful life. When an impairment indicator is present, the Company determines if the carrying value of the asset is recoverable by comparing it to its expected undiscounted future cash flows. If the carrying value of the asset is greater than the expected undiscounted future cash flows, an impairment charge is recorded in an amount equal to the excess of the carrying value of the asset over its fair value.

Derivative Instruments

We record our derivative instruments held as assets and liabilities at fair value on the Consolidated Balance Sheets. In addition, since we choose not to designate any of our physical and financial natural gas commodity derivatives as accounting hedges, changes in the fair value of Energy Services’ commodity derivatives are recognized in earnings, as they occur, as a component of operating revenues or natural gas purchases on the Consolidated Statements of Operations. Changes in the fair value of foreign exchange contracts are recognized in natural gas purchases on the Consolidated Statements of Operations.

The fair value of derivative instruments is determined by reference to quoted market prices of listed exchange-traded contracts, published price quotations, pipeline tariff information or a combination of those items. Energy Services’ portfolio is valued using the most current and reasonable market information. If the price underlying a physical commodity transaction does not represent a visible and liquid market, Energy Services may utilize additional published pipeline tariff information and/or other services to determine an equivalent market price. As of September 30, 2020, the fair value of its derivative assets and liabilities reported on the Consolidated Balance Sheets that is based on such pricing is considered immaterial.

Should there be a significant change in the underlying market prices or pricing assumptions, Energy Services may experience a significant impact on its financial position, results of operations and cash flows. Refer to Item 7A. Quantitative and Qualitative Disclosures About Market Risks for a sensitivity analysis related to the impact to derivative fair values resulting from changes in commodity prices. The valuation methods we use to determine fair values remained consistent for fiscal 2020, 2019 and 2018. We apply a discount to our derivative assets to factor in an adjustment associated with the credit risk of its physical natural gas counterparties and to our derivative liabilities to factor in an adjustment associated with its own credit risk. We determine this amount by using historical default probabilities corresponding to the appropriate S&P issuer ratings. Since the majority of our counterparties are rated investment grade, this results in an immaterial credit risk adjustment.

Gains and losses associated with derivatives utilized by NJNG to manage the price risk inherent in its natural gas purchasing activities are recoverable through its BGSS, subject to BPU approval. Accordingly, the offset to the change in fair value of these derivatives is recorded as either a regulatory asset or liability on the Consolidated Balance Sheets.

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New Jersey Resources Corporation

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Clean Energy Ventures hedges certain of its expected production of SRECs through forward and futures contracts. Clean Energy Ventures intends to physically deliver all SRECs it sells and recognizes SREC revenue as operating revenue on the Consolidated Statements of Operations upon delivery of the underlying SREC.

We have not designated any derivatives as fair value or cash flow hedges as of September 30, 2020 and 2019.

Income Taxes

The determination of our provision for income taxes requires the use of estimates and the interpretation and application of tax laws. Judgment is required in assessing the deductibility and recoverability of certain tax benefits. We use the asset and liability method to determine and record deferred tax assets and liabilities, representing future tax benefits and taxes payable, which result from the differences in basis recorded in GAAP financial statements and amounts recorded in the income tax returns. The deferred tax assets and liabilities are recorded utilizing the statutorily enacted tax rates expected to be in effect at the time the assets are realized, and/or the liabilities settled. An offsetting valuation allowance is recorded when it is more likely than not that some or all of the deferred income tax assets won’t be realized. Any significant changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a material change to earnings and cash flows. For a more detailed description of Income Taxes see Note 13. Income Taxes in the accompanying Consolidated Financial Statements.

For state income tax and other taxes, estimates and judgments are required with respect to the apportionment among the various jurisdictions. In addition, we operate within multiple tax jurisdictions and are subject to audits in these jurisdictions. These audits can involve complex issues, which may require an extended period of time to resolve. We maintain a liability for the estimate of potential income tax exposure and, in our opinion, adequate provisions for income taxes have been made for all years reported. Any significant changes to the estimates and judgments with respect to the apportionment factor could result in a material change to earnings and cash flows.

Occasionally, the federal and state taxing authorities determine that it is necessary to make certain changes to the income tax laws. These changes may include but are not limited to changes in the tax rates and/or the treatment of certain items of income or expense. Accounting guidance requires that the Company reflect the effect of tax laws or tax rates at the date of enactment. Additionally, the Company is required to re-measure its deferred tax assets and liabilities as of the date of enactment. For non-regulated entities, the effect of changes in tax rates and/or tax laws are required to be included in income from continuing operations for the period that includes the enactment date. For regulated entities, if as the result of an action by a regulator it is probable that the future increase or decrease in taxes payable for items such as changes in tax law or rates will be recovered from or returned to customers through future rates, an asset or liability shall be recognized for that probable increase or decrease in future revenue. Accounting guidance also requires that regulatory liabilities/assets be considered a temporary difference for which a deferred tax asset/liability shall be recognized.

Accounting guidance requires that we establish reserves for uncertain tax positions when it is more likely than not that the positions will not be sustained when challenged by taxing authorities. Any changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a change to earnings and cash flows. Interest and penalties related to unrecognized tax benefits, if any, are recognized within income tax expense and accrued interest, and penalties are recognized within accrued taxes on the Consolidated Balance Sheets.

To the extent that NJNG invests in property that qualifies for ITCs, the ITC is deferred and amortized to income over the life of the equipment in accordance with regulatory treatment.

Changes to the federal statutes related to ITCs, which have the effect of reducing or eliminating the credits, could have a

negative impact on earnings and cash flows.

Recently Issued Accounting Standards

Refer to Note 2. Summary of Significant Accounting Policies in the accompanying Consolidated Financial Statements for discussion of recently issued accounting standards.

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New Jersey Resources Corporation

Part II

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Management’s Overview

Consolidated

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

The following sections include a discussion of results for fiscal 2020 compared to fiscal 2019. The comparative results for fiscal 2019 with fiscal 2018 have been omitted from this Form 10-K, but may be found in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations on Form 10-K of our Annual Report for the fiscal year ended September 30, 2019, filed with the SEC on November 22, 2019.

Reporting Segments

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

In addition to our four reporting segments, we have non-utility operations that either provide corporate support services or do not meet the criteria to be treated as a separate reporting segment. These operations, which comprise Home Services and Other, include: appliance repair services, sales and installations at NJRHS and commercial real estate holdings at CR&R.

Impacts of the COVID-19 Pandemic

We are closely monitoring developments related to the COVID-19 pandemic and are taking steps intended to limit potential exposure for our employees and those we serve. We have also taken proactive steps to ensure business continuity in the safe operation of our business. Both NJR and NJNG continue to have sufficient liquidity to meet their current obligations, and business operations remain fundamentally unchanged at this time. This is, however, a rapidly evolving situation, and we cannot predict the extent or duration of the outbreak, the effects of the pandemic on the global, national or local economy or its effects on our financial condition, results of operations and cash flows. We cannot predict the nature and extent of impacts to future operations. We will continue to monitor developments affecting our employees, customers and operations and take additional steps to address the COVID-19 pandemic and its impacts, as necessary.

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New Jersey Resources Corporation

Part II

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Operating Results

A summary of our consolidated results in net income and assets by reporting segment and operations for the fiscal years ended September 30, is as follows:

(Thousands)	2020				2019				2018
	Net Income		Assets		Net Income		Assets		Net Income		Assets
Natural Gas Distribution	$	126,902	$	3,531,477	$	78,062	$	3,064,309	$	84,048	$	2,663,054
Clean Energy Ventures	22,111		814,277		31,903		694,439		73,426		740,704
Energy Services	(11,008)		244,836		(1,268)		290,847		53,139		396,852
Storage and Transportation	18,311		844,799		14,689		240,955		24,367		242,069
Home Services and Other	5,784		138,375		1,637		104,411		(3,555)		114,732
Intercompany (1)	907		(257,287)		(1,088)		(237,019)		(412)		(171,107)
Total	$	163,007	$	5,316,477	$	123,935	$	4,157,942	$	231,013	$	3,986,304

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

The increase in net income of $39.1 million during fiscal 2020, compared with fiscal 2019, was driven primarily by increased earnings at our Natural Gas Distribution segment due to higher base rates resulting from the base rate case in November 2019, partially offset by decreased earnings at Energy Services resulting from warmer weather, which lead to decreased demand, lower natural gas prices and ultimately decreased volatility in the wholesale natural gas markets and decreased PTCs at Clean Energy Ventures resulting from the absence of wind revenue in fiscal 2020. The primary drivers of the changes noted above are described in more detail in the individual segment discussions.

The increase in assets during fiscal 2020, compared with fiscal 2019, was due primarily to the acquisition of Leaf River and Adelphia Gateway within our Storage and Transportation segment, increases in utility plant and solar asset investment within our Natural Gas Distribution segment and Clean Energy Ventures segment, respectively, and the recognition of a right-of-use asset upon adoption of ASC 842 - Leases on October 1, 2019.

Non-GAAP Financial Measures

Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. Energy Services economically hedges its natural gas inventory with financial derivative instruments. NFE is a measure of the earnings based on eliminating timing differences surrounding the recognition of certain gains or losses, to effectively match the earnings effects of the economic hedges with the physical sale of natural gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. There is a related tax effect on current and deferred income tax expense corresponding with this non-GAAP measure. To the extent we utilize forwards, futures or other derivatives to hedge forecasted SREC production, unrealized gains and losses are also eliminated for NFE purposes.

GAAP requires us, during the interim periods, to estimate our annual effective tax rate and use this rate to calculate the year-to-date tax provision. We also determine an annual estimated effective tax rate for NFE purposes and calculate a quarterly tax adjustment based on the difference between our forecasted net income and our forecasted NFE for the fiscal year. Since the annual estimated effective tax rate is based on certain forecasted assumptions, including estimates surrounding completion of Clean Energy Ventures projects, the rate and resulting NFE are subject to change. No adjustment is needed during the fourth quarter, since the actual effective tax rate is calculated at fiscal year-end.

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

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New Jersey Resources Corporation

Part II

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Below is a reconciliation of consolidated net income, the most directly comparable GAAP measure, to NFE for the fiscal years ended September 30:

(Thousands, except per share data)	2020		2019		2018
Net income	$	163,007	$	123,935	$	231,013
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(9,644)		2,881		26,770
Tax effect	2,296		(711)		(4,512)
Effects of economic hedging related to natural gas inventory (1)	12,690		4,309		(22,570)
Tax effect	(3,016)		(1,024)		7,362
Net financial earnings	$	165,333	$	129,390	$	238,063
Basic earnings per share	$	1.72	$	1.39	$	2.63
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(0.10)		0.03		0.31
Tax effect	0.02		(0.01)		(0.05)
Effects of economic hedging related to natural gas inventory (1)	0.13		0.05		(0.26)
Tax effect	(0.03)		(0.01)		0.08
Basic net financial earnings per share	$	1.74	$	1.45	$	2.71

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

NFE by reporting segment and other operations for the fiscal years ended September 30, discussed in more detail within the operating results sections of each segment, is summarized as follows:

(Thousands)	2020				2019				2018
Natural Gas Distribution	$	126,902	77	%	$	78,062	60	%	$	84,048	35	%
Clean Energy Ventures	22,111		13		31,903		25		73,426		31
Energy Services	(7,873)		(5)		2,918		2		60,378		25
Storage and Transportation	18,311		11		14,689		11		24,367		10
Home Services and Other	5,784		4		1,911		2		(3,829)		(1)
Eliminations (1)	98		—		(93)		—		(327)		—
Total	$	165,333	100	%	$	129,390	100	%	$	238,063	100	%

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

The increase in NFE of $35.9 million during fiscal 2020, compared with fiscal 2019, was driven primarily by increased base rates at our Natural Gas Distribution and Transportation segments, partially offset by lower financial margin generated at Energy Services resulting from warmer weather, which led to decreased demand, lower natural gas prices and ultimately decreased volatility in the wholesale natural gas markets and decreased earnings at Clean Energy Ventures, as previously discussed.

Natural Gas Distribution Segment

Overview

Our Natural Gas Distribution segment is comprised of NJNG, a natural gas utility that provides regulated retail natural gas service throughout Monmouth, Ocean, Morris, Middlesex and Burlington counties in New Jersey to approximately 558,000 residential and commercial customers in its service territory and also participates in the off-system sales and capacity release markets. The business is subject to various risks, including those risks associated with COVID-19 and may include but are not limited to impacts to customer growth and customer usage, customer collections, the timing and costs of capital expenditures and construction of infrastructure projects, operating and financing costs, fluctuations in commodity prices and customer conservation efforts. In addition, NJNG may be subject to adverse economic conditions, certain regulatory actions, environmental remediation and severe weather conditions. It is often difficult to predict the impact of events or trends associated with these risks.

NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered to customers on an annual basis. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG receives most of its natural gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the fiscal year.

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New Jersey Resources Corporation

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 4. Regulation in the accompanying Consolidated Financial Statements for a more detailed discussion on regulatory actions, including filings related to programs and associated expenditures, as well as rate requests related to recovery of capital investments and operating costs.

NJNG’s operations are managed with the goal of providing safe and reliable service, growing its customer base, diversifying its utility gross margin, promoting clean energy programs and mitigating the risks discussed above.

Base Rate Case

On March 29, 2019, NJNG filed a base rate case with the BPU requesting a natural gas revenue increase of $128.2 million, including a change in NJNG’s overall rate of return on rate base to 7.87 percent. NJNG was also seeking permission to request recovery for SRL in a future filing, upon completion of the project. On July 2, 2019, NJNG filed an update with actual information through May 31, 2019, which reflected a revenue increase of $129.8 million. On September 30, 2019, NJNG filed a second update with actual information through August 31, 2019, which reflected a revenue increase of $134.3 million. On November 13, 2019, the BPU issued an order adopting a stipulation of settlement approving a $62.2 million increase to base rates, effective November 15, 2019. The increase includes an overall rate of return on rate base of 6.95 percent, return on common equity of 9.6 percent, a common equity ratio of 54 percent and a depreciation rate of 2.78 percent.

Infrastructure Projects

NJNG has significant annual capital expenditures associated with the management of its natural gas distribution and transmission system, including new utility plant associated with customer growth and its associated PIM and infrastructure programs. Below is a summary of NJNG’s capital expenditures, including accruals for fiscal 2020 and estimates for expected investments over the next fiscal year:

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

Infrastructure Investment Program

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

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New Jersey Resources Corporation

Part II

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Company’s transmission and distribution component of the IIP for $150 million over five years, effective November 1, 2020. NJNG voluntarily withdrew the information technology upgrade component and will seek to recover associated costs in future rate case proceedings.

SAFE II and NJ RISE

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

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

The BPU approved NJNG’s NJ RISE capital infrastructure program, which consists of six capital investment projects estimated to cost $102.5 million, excluding AFUDC, for natural gas distribution storm hardening and mitigation projects, along with associated depreciation expense. These system enhancements are intended to minimize service impacts during extreme weather events to customers in the most storm-prone areas of NJNG’s service territory. Recovery of NJ RISE investments is included in NJNG’s base rates.

In September 2019, the BPU approved NJNG’s annual petition requesting a rate increase of $7.8 million, effective October 1, 2019.

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

Southern Reliability Link

The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG’s service territory. Construction began on the project in December 2018 and is estimated to cost between $250 million and $270 million upon completion. Costs associated with SRL will be requested for recovery in a future base rate case.

Customer Growth

In conducting NJNG’s business, management focuses on factors it believes may have significant influence on its future financial results. NJNG’s policy is to work with all stakeholders, including customers, regulators and policymakers, to achieve favorable results. These factors include the rate of NJNG’s customer growth in its service territory, which can be influenced by political and regulatory policies, the delivered cost of natural gas compared with competing fuels, interest rates and general economic and business conditions. NJNG’s total customers as of September 30, include the following:

	2020	2019	2018
Firm customers
Residential	497,779	486,474	474,495
Commercial, industrial & other	28,735	28,992	28,037
Residential transport	22,420	22,870	26,490
Commercial transport	9,184	9,237	9,636
Total firm customers	558,118	547,573	538,658
Other	48	53	59
Total customers	558,166	547,626	538,717

During fiscal 2020, NJNG added 8,349 new customers, which represents a new customer growth rate of approximately 1.5 percent. During that same time period, NJNG converted 260 existing customers to natural gas heat and other services. This

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OPERATIONS (Continued)                                                                                                                                                             

customer growth, as well as commercial customers who switched from interruptible to firm natural gas service, will contribute approximately $6.2 million, on an annualized basis, to utility gross margin. NJNG also added 9,711 and 9,596 new customers and converted 218 and 613 existing customers to natural gas heat and other services during the fiscal years ended September 30, 2019 and 2018, respectively.

NJNG continues to expect to add approximately 28,000 to 30,000 new customers during the three-year period of fiscal 2021 to 2023. NJNG’s estimates are based on information from municipalities and developers, as well as external industry analysts and management’s experience. NJNG estimates that approximately 65 percent of the growth will come from new construction markets and 35 percent from customer conversions to natural gas from other fuel sources. See the Natural Gas Distribution Segment Operating Results section that follows for a definition and further discussion of utility gross margin.

Energy Efficiency Programs

SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives designed to encourage the installation of high-efficiency heating and cooling equipment and other energy efficiency upgrades. Depending on the specific incentive or approval, NJNG recovers costs associated with the programs over a two- to 10-year period through a tariff rider mechanism. On September 25, 2020, NJNG filed a petition with the BPU for an additional three-year SAVEGREEN program consisting of approximately $127 million in direct investment, $113 million in financing options, and approximately $23 million in operation and maintenance expenses, to be effective July 1, 2021.

On December 18, 2018, the BPU approved a decrease in NJNG's EE recovery rate reflecting actual costs incurred through September 30, 2018, which resulted in an annual recovery of approximately $8.8 million, effective January 1, 2019. On October 25, 2019, the BPU approved NJNG’s annual filing to increase its EE recovery rate, which resulted in an annual recovery of approximately $11.3 million, effective November 1, 2019. On May 29, 2020, NJNG filed a petition with the BPU to minimally decrease its EE recovery rate. Throughout the course of the proceeding, the Company updated the filing with additional actual information. Based on the updated information, the BPU approved the Company to maintain its existing rate, which will result in an annual recovery of approximately $11.4 million, effective November 1, 2020.

The following table summarizes, since inception, loans, grants, rebates and related investments as of September 30:

(Thousands)	2020		2019
Loans	$	119,400	$	99,000
Grants, rebates and related investments	80,500		70,100
Total	$	199,900	$	169,100

Program recoveries from customers during the period ending September 30, 2020 and 2019, were $10.3 million and $11.6 million, respectively. The recovery includes a weighted average cost of capital that ranges from 6.69 percent to 7.76 percent, with a return on equity of 9.75 percent to 10.3 percent.

Conservation Incentive Program/BGSS

The CIP facilitates normalizing NJNG’s utility gross margin for variances not only due to weather but also for other factors affecting customer usage, such as conservation and energy efficiency. Recovery of utility gross margin for the non-weather variance through the CIP is limited to the amount of certain natural gas supply cost savings achieved and is subject to a variable margin revenue test. Additionally, recovery of the CIP utility gross margin is subject to an annual earnings test. An annual review of the CIP must be filed by June 1, coincident with NJNG’s annual BGSS filing, during which NJNG can request rate changes to the CIP. In May 2014, the BPU approved the continuation of the CIP program with no expiration date.

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

(Thousands)	2020		2019		2018
Weather (1)	$	17,882	$	2,699	$	205
Usage	292		(341)		(1,629)
Total	$	18,174	$	2,358	$	(1,424)

(1)Compared with the CIP 20-year average, weather was 7.2 percent, 1 percent and 0.5 percent warmer-than-normal during fiscal 2020, 2019 and 2018, respectively.

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OPERATIONS (Continued)                                                                                                                                                             

Recovery of Natural Gas Costs

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

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

On December 28, 2018, NJNG notified the BPU that it would implement a BGSS increase effective February 1, 2019, which resulted in an increase in revenues credited to BGSS of $10.9 million through September 30, 2019.

On March 27, 2020, the BPU approved, on a final basis, a decrease to NJNG’s BGSS rate for residential and small commercial customers, an increase to its balancing charge rate, resulting in a $2 million decrease to the annual revenues credited to BGSS, as well as changes to the CIP rates, which resulted in a $10.6 million annual recovery increase, effective October 1, 2019.

On May 29, 2020, NJNG filed its annual petition with the BPU to decrease its BGSS rate for residential and small commercial customers, decrease its balancing charge and modify its CIP rates. On September 9, 2020, the BPU approved NJNG’s petition, effective October 1, 2020, which will result in a $7.7 million overall net decrease to the annual recovery. The balancing charge rate includes the cost of balancing natural gas deliveries with customer usage for sales and transportation customers and balancing charge revenues are credited to BGSS.

On November 20, 2020, NJNG submitted notification that it will provide an estimated $10 million in BGSS bill credits in December 2020

Refer to Note 4. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements for a further discussion of NJNG’s periodic BGSS and CIP rate adjustments.

BGSS Incentive Programs

NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of utility gross margin-sharing programs that include off-system sales, capacity release and storage incentive programs. These programs are designed to encourage better utilization and hedging of NJNG’s natural gas supply, transportation and storage assets. Depending on the program, NJNG shares 80 or 85 percent of utility gross margin generated by these programs with firm customers. Utility gross margin from incentive programs was $9.5 million, $8.4 million and $12.5 million during the fiscal years ended September 30, 2020, 2019 and 2018, respectively.

Hedging

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

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OPERATIONS (Continued)                                                                                                                                                             

Commodity prices

Our Natural Gas Distribution segment is affected by the price of natural gas, which can have a significant impact on our cash flows, short-term financing costs, the price of natural gas charged to our customers through the BGSS clause, our ability to collect accounts receivable, which impacts our bad debt expense, and our ability to maintain a competitive advantage over other energy sources.

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

(1) Data sourced from S&P Global Platts.

The maximum price per MMBtu was $5.59, $9.17 and $94.93 and the minimum price was $0.68, $1.09 and $0.53 for the fiscal years ended September 30, 2020, 2019 and 2018, respectively. A more detailed discussion of the impacts of the price of natural gas on operating revenues, natural gas purchases and cash flows can be found in the Results of Operations and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Societal Benefits Charge

USF

NJNG’s qualifying customers are eligible for the USF program, which is administered by the New Jersey Department of Community Affairs, to help make energy bills more affordable. In September 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which will result in a $1 million annual increase, effective October 1, 2018. On June 24, 2019, NJNG filed its annual USF compliance filing proposing an increase to the statewide USF rate, which will result in the annual recovery increasing by $1.2 million, effective October 1, 2019. On June 25, 2020, NJNG filed its annual USF compliance filing proposing a decrease to the statewide USF rate, which will result in annual decreases of approximately $400,000. On September 23, 2020, the BPU approved the decrease, effective October 1, 2020. Refer to Note 4. Regulation - Societal Benefits Clause in the accompanying Consolidated Financial Statements for a further discussion of NJNG’s USF rates.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Environmental Remediation

NJNG is responsible for the environmental remediation of former MGP sites, which contain contaminated residues from former gas manufacturing operations that ceased operating at these sites by the mid-1950s and, in some cases, had been discontinued many years earlier. Actual MGP remediation costs may vary from management’s estimates due to the developing nature of remediation requirements, regulatory decisions by the NJDEP and related litigation. NJNG reviews these costs at the end of each fiscal year and adjusts its liability and corresponding regulatory asset as necessary to reflect its expected future remediation obligation. Accordingly, NJNG recognized a regulatory asset and an obligation of $150.6 million as of September 30, 2020, an increase of $19.5 million compared with the prior fiscal period. On September 27, 2019, NJNG filed its annual SBC application requesting to recover remediation expenses, including an increase in the RAC, of approximately $1.4 million annually and an increase to the NJCEP factor, which will result in an annual increase of approximately $3.3 million, to be effective April 1, 2020. On March 16, 2020, a stipulation was signed in NJNG’s annual SBC application including recovery of remediation expenses, an increase in the RAC of approximately $1.2 million annually and an annual decrease to the NJCEP factor of $600,000. The BPU approved the stipulation on September 9, 2020. On September 29, 2020, NJNG filed its annual SBC application requesting to recover remediation expenses, including an increase in the RAC, of approximately $1.3 million annually and an increase to the NJCEP factor, which will result in an annual increase of approximately $6 million, effective April 1, 2021.

In June 2019, NJNG initiated a preliminary assessment of a site in Aberdeen, New Jersey to determine prior ownership and if there were former MGP operations active at the location. The Company is in the process of conducting site investigation activities to identify and evaluate the nature and extent of MGP-related contaminants present at the location. The costs associated with preliminary assessment and site investigation activities are considered immaterial and are included as a component of NJNG’s annual SBC application to recover remediation expenses. We will continue to gather information to further refine and enhance its estimate of potential costs for this site as it becomes available. See Note 15. Commitments and Contingent Liabilities for a more detailed description.

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

Operating Results

NJNG’s operating results for the fiscal years ended September 30, are as follows:

(Thousands)	2020		2019		2018
Operating revenues	$	729,923	$	710,793	$	731,865
Operating expenses
Natural gas purchases (1) (2)	287,307		336,489		333,208
Operation and maintenance	162,792		171,198		203,627
Regulatory rider expense (3)	34,529		33,937		38,969
Depreciation and amortization	71,883		57,980		53,208
Total operating expenses	556,511		599,604		629,012
Operating income	173,412		111,189		102,853
Other income, net	11,486		2,441		4,584
Interest expense, net of capitalized interest	30,975		26,134		25,299
Income tax provision (benefit)	27,021		9,434		(1,910)
Net income	$	126,902	$	78,062	$	84,048

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

(2)Includes related party transactions of approximately $11.5 million, $16.2 million and $57.2 million during fiscal 2020, 2019 and 2018, respectively, a portion of which are eliminated in consolidation.

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

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Operating Revenues and Natural Gas Purchases

Operating revenues increased 2.7 percent during fiscal 2020 compared with fiscal 2019. Natural gas purchases decreased 14.6 percent during fiscal 2020 compared with fiscal 2019. The factors contributing to the increases (decreases) in operating revenues and natural gas purchases during fiscal 2020, are as follows:

	2020 v. 2019
(Thousands)	Operating revenue		Natural gas purchases
Base rate impact	$	55,348	$	—
CIP adjustments	15,816		—
SAFE II/NJ RISE	7,728		—
Firm sales	(27,461)		(13,217)
BGSS incentives	(33,761)		(34,834)
Average BGSS rates	(5,258)		(5,258)
Other (1)	6,718		4,127
Total increase (decrease)	$	19,130	$	(49,182)

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

Non-GAAP Financial Measures

Management uses utility gross margin, a non-GAAP financial measure, when evaluating the operating results of NJNG. NJNG’s utility gross margin is defined as natural gas revenues less natural gas purchases, sales tax and regulatory rider expenses, and may not be comparable to the definition of gross margin used by others in the natural gas distribution business and other industries. Management believes that utility gross margin provides a meaningful basis for evaluating utility operations since natural gas costs, sales tax and regulatory rider expenses are included in operating revenue and passed through to customers and, therefore, have no effect on utility gross margin. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.

Utility Gross Margin

A reconciliation of operating revenues, the closest GAAP financial measure to NJNG’s utility gross margin, is as follows for the fiscal years ended September 30:

(Thousands)	2020		2019		2018
Operating revenues	$	729,923	$	710,793	$	731,865
Less:
Natural gas purchases	287,307		336,489		333,208
Energy taxes	—		—		39,426
Regulatory rider expense	34,529		33,937		38,969
Utility gross margin	$	408,087	$	340,367	$	320,262

(1)Energy taxes does not include sales tax during fiscal 2020 and 2019, due to the adoption of ASC 606, Revenue from Contracts with Customers. Energy taxes includes only sales tax on operating revenues during fiscal 2018, excluding tax-exempt sales.

Utility gross margin consists of three components:

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

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

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

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OPERATIONS (Continued)                                                                                                                                                             

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

	2020			2019			2018
($ in thousands)	Margin		Bcf	Margin		Bcf	Margin		Bcf
Utility gross margin/throughput
Residential	$	275,033	44.6	$	224,597	46.0	$	203,195	45.5
Commercial, industrial and other	57,929		8.2	50,553		9.7	46,636		8.9
Firm transportation	60,199		13.3	51,069		13.7	51,880		15.5
Total utility firm gross margin/throughput	393,161		66.1	326,219		69.4	301,711		69.9
BGSS incentive programs	9,471		118.4	8,398		123.8	12,482		150.2
Interruptible/off-tariff agreements	5,455		30.9	5,750		39.0	6,069		46.2
Total utility gross margin/throughput	$	408,087	215.4	$	340,367	232.2	$	320,262	266.3

Utility Firm Gross Margin

Utility firm gross margin increased $66.9 million during fiscal 2020 compared with fiscal 2019, due primarily to the increase in base rates, along with increased returns on infrastructure programs related to SAFE II and NJ RISE.

BGSS Incentive Programs

A description of the factors contributing to the increases (decreases) in utility gross margin generated by NJNG’s BGSS incentive programs during fiscal 2020 is as follows:

(Thousands)	2020 v. 2019
Storage		$	1,217
Off-system sales		795
Capacity release		(939)
Total increase		$	1,073

The increase in utility gross margin was due primarily to an increase in storage incentive from market opportunities for low-cost storage injections and improved margins from off-system sales, partially offset by a decrease in capacity release volume.

Operation and Maintenance Expense

O&M expense decreased $8.4 million during fiscal 2020 compared with fiscal 2019, due primarily to decreased consulting expenses related to technology improvements projects, partially offset by increased compensation costs.

Depreciation Expense

Depreciation expense increased $13.9 million in fiscal 2020, compared with fiscal 2019, as a result of additional utility plant being placed into service, as well as an increase in the overall depreciation rate from 2.4 percent to 2.78 percent resulting from the settlement of the base rate case.

Interest Expense

Interest expense increased $4.8 million in fiscal 2020, compared with fiscal 2019, due primarily to the increased outstanding long-term debt.

Other Income

Other income increased $9 million during fiscal 2020, compared with fiscal 2019, due primarily to increased AFUDC earned on infrastructure projects.

Income Tax Provision

Income tax provision increased $17.6 million during fiscal 2020, compared with fiscal 2019, due primarily to increased operating income.

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OPERATIONS (Continued)                                                                                                                                                             

Net Income

Net income increased $48.8 million to $126.9 million in fiscal 2020, compared with fiscal 2019, due primarily to the increase in operating revenues related to increased base rates and increased other income related to AFUDC earned on infrastructure projects, partially offset by the increases in depreciation, income tax expense and interest expense, as previously discussed.

Clean Energy Ventures Segment

Overview

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

Capital expenditures related to clean energy projects are subject to change due to a variety of factors that may affect our ability to commence operations at these projects on a timely basis or at all, including logistics associated with the start-up of residential and commercial solar projects, such as timing of construction schedules, the permitting and regulatory process, any delays related to electric grid interconnection, economic trends, unforeseen events and the ability to access capital or allocation of capital to other investments or business opportunities. Clean Energy Ventures is also subject to risks associated with COVID-19, which may include impacts to residential solar customer growth and customer collections, our ability to identify and develop commercial solar asset investments, impacts to our supply chain and our ability to source materials for construction.

Through fiscal 2020, the primary contributors toward the value of qualifying clean energy projects are tax incentives and SRECs. Changes in the federal statutes related to the ITC or in the marketplace and/or relevant state legislation and regulatory policies affecting the market for solar renewable energy credits, could significantly affect future results.

Solar

Solar projects placed in service and related expenditures for the fiscal years ended September 30, are as follows:

($ in Thousands)	2020				2019				2018
Placed in service	Projects	MW	Costs		Projects	MW	Costs		Projects	MW	Costs
Grid-connected (1)	9	60.1	$	121,516	3	29.0	$	64,684	3	33.7	$	70,216
Net-metered:
Commercial (1) (2)	—	—	43		4	22.8	71,730		—	—	74
Residential	481	5.9	17,474		815	8.3	26,796		910	8.5	27,342
Total placed in service	490	66.0	$	139,033	822	60.1	$	163,210	913	42.2	$	97,632

(1)Includes projects subject to sale leaseback arrangements.

(2)Includes a 4.4 MW commercial solar project acquired in August 2019.

Since inception, Clean Energy Ventures has constructed a total of 357.4 MW of solar capacity and has an additional 8.1 MW under construction. Projects that were placed in service through December 31, 2019, qualify for a 30-percent federal ITC. The credit declines to 26 percent for property under construction during 2020, 22 percent for property under construction during 2021 and 10 percent for any property that is under construction after 2021. 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 the ITC safe harbor determination. We have taken steps to preserve the ITC at the higher rate for certain solar projects that are completed after the scheduled reduction in rates, in accordance with IRS guidance.

Clean Energy Ventures may enter into transactions to sell certain of its commercial solar assets concurrent with agreements to lease the assets back over a period of five to 15 years. The Company will continue to operate the solar assets and are responsible for related expenses and entitled to retain the revenue generated from SRECs, TRECs and energy sales. The ITCs and other tax benefits associated with these solar projects transfer to the buyer as applicable; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, for solar projects financed under sale leasebacks for which the assets were sold during the first 5 years of in-service life, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. During fiscal 2020 and 2018, Clean

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OPERATIONS (Continued)                                                                                                                                                             

Energy Ventures received proceeds of $42.9 million and $70.2 million, respectively, in connection with the sale leaseback of commercial solar assets. Clean Energy Ventures did not enter into any sale leaseback transactions for its commercial solar assets during fiscal 2019.

Excluding the project costs related to the commercial solar projects that were included in the sale leaseback transactions, the Company had $124 million, $163.2 million and $27.4 million of solar-related capital expenditures that were placed in service and ITC-eligible during fiscal 2020, 2019 and 2018, respectively, which were recognized in income tax (benefit) provision on the Consolidated Statements of Operations.

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

Once a solar installation has received the proper certifications and commences operations, each MWh of electricity produced creates an SREC that represents the renewable energy attribute of the solar-electricity generated that can be sold to third parties, predominantly load-serving entities that are required to comply with the solar requirements under New Jersey’s renewable portfolio standard.

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

SREC and TREC activity for the fiscal years ended September 30, is as follows:

	2020	2019	2018
Inventory balance as of October 1,	53,395	105,192	48,357
SRECs generated	389,716	311,803	245,147
TRECS generated	9,270	—	—
SRECs delivered	(408,100)	(363,600)	(188,312)
Inventory balance as of September 30,	44,281	53,395	105,192

The average SREC sales price was $199 in fiscal 2020, $207 in fiscal 2019 and $217 in fiscal 2018 and the average TREC price was $144 in fiscal 2020.

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

Energy Year (1)	Percent of SRECs Hedged
2021	99%
2022	93%
2023	59%
2024	22%

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

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

Onshore Wind

Clean Energy Ventures invested in small to mid-size onshore wind projects. In February 2019, Clean Energy Ventures finalized the sale of its remaining wind assets to a subsidiary of Skyline Renewables LLC for total proceeds of $208.6 million. The transaction generated a pre-tax gain of $645,000, which was recognized as a component of O&M expense on the Consolidated Statements of Operations.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Operating Results

Clean Energy Ventures’ financial results for the fiscal years ended September 30, are summarized as follows:

(Thousands)	2020		2019		2018
Operating revenues	$	102,617	$	98,099	$	71,375
Operating expenses
Operation and maintenance	30,310		28,614		27,058
Depreciation and amortization	25,329		22,376		22,747
Total operating expenses	55,639		50,990		49,805
Operating income	46,978		47,109		21,570
Other income, net	6,420		6,910		1,797
Interest expense, net	20,253		14,846		18,320
Income tax expense (benefit)	11,034		7,270		(68,379)
Net income	$	22,111	$	31,903	$	73,426

Operating Revenues

Operating revenues increased $4.5 million in fiscal 2020, compared with fiscal 2019, due primarily to increased SREC and electricity sales, partially offset by the sale of the remaining wind assets in February 2019.

Operation and Maintenance Expense

O&M expense increased $1.7 million in fiscal 2020, compared with fiscal 2019, due primarily to increased project maintenance expenses, partially offset by a decrease in shared corporate costs, as well as a pre-tax gain of $645,000, associated with the sale of the remaining wind assets in February 2019, that did not recur.

Depreciation Expense

Depreciation expense increased $3.0 million in fiscal 2020, compared with fiscal 2019, as a result of increases in solar capital additions placed in service, partially offset by the change in estimated useful lives of our commercial solar assets in the fourth quarter of fiscal 2020.

Income Tax Expense

Income tax expense increased $3.8 million during fiscal 2020, compared with fiscal 2019, due primarily to PTCs associated with our former wind projects, which were included in fiscal 2019 and not in fiscal 2020.

Net Income

Net income in fiscal 2020 decreased $9.8 million, compared with fiscal 2019, due primarily to decreased PTCs recognized along with increased interest and depreciation expenses, partially offset by increased revenue, as previously discussed.

Energy Services Segment

Overview

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

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

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

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

Energy Services accounts for its physical commodity contracts and its financial derivative instruments at fair value on the Consolidated Balance Sheets. Changes in the fair value of physical commodity contracts and financial derivative instruments are included in earnings as a component of operating revenue or natural gas purchases on the Consolidated Statements of Operations. Volatility in reported net income at Energy Services can occur over periods of time due to changes in the fair value of derivatives, as well as timing differences related to certain transactions. Unrealized gains and losses can fluctuate as a result of changes in the price of natural gas, SRECs and foreign currency from the original transaction price. Volatility in earnings can also occur as a result of timing differences between the settlement of financial derivatives and the sale of the underlying physical commodity. For example, when a financial instrument settles and the physical natural gas is injected into inventory, the realized gains and losses associated with the financial instrument are recognized in earnings. However, the gains and losses associated with the physical natural gas are not recognized in earnings until the natural gas inventory is withdrawn from storage and sold, at which time Energy Services realizes the entire margin on the transaction.

Operating Results

Energy Services’ financial results for the fiscal years ended September 30, are summarized as follows:

(Thousands)	2020		2019		2018
Operating revenues (1)	$	1,030,419	$	1,742,791	$	2,112,804
Operating expenses
Natural gas purchases (including demand charges (2)(3))	1,024,579		1,719,519		1,995,335
Operation and maintenance (4)	17,368		20,943		35,616
Depreciation and amortization	123		118		76
Total operating expenses	1,042,070		1,740,580		2,031,027
Operating income (loss)	(11,651)		2,211		81,777
Other income	304		153		303
Interest expense, net	3,276		5,205		3,945
Income tax (benefit) provision	(3,615)		(1,573)		24,996
Net (loss) income	$	(11,008)	$	(1,268)	$	53,139

(1)Includes related party transactions of approximately $1.1 million, $8.2 million and $48.3 million during fiscal 2020, 2019 and 2018, respectively, which are eliminated in consolidation.

(2)Costs associated with pipeline and storage capacity that are expensed over the term of the related contracts, which generally varies from less than one year to 10 years.

(3)Includes related party transactions of approximately $183,000, $3.4 million and $4.5 million during fiscal 2020, 2019 and 2018, respectively, a portion of which are eliminated in consolidation.

(4)Includes energy and other taxes due to change in presentation in the Consolidated Statements of Operations.

As of September 30, Energy Services’ portfolio of financial derivative instruments are composed of:

(in Bcf)	2020	2019	2018
Net short futures contracts	29.3	34.6	24.3
Net long options	—	1.0	—

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Operating Revenues and Natural Gas Purchases

During fiscal 2020, operating revenues decreased $712.4 million and natural gas purchases decreased $694.9 million, due primarily to warmer weather compared to the prior period, which led to decreased demand and lower natural gas prices, increased natural gas in storage and ultimately decreased volatility in the wholesale natural gas markets.

Future results at Energy Services are contingent upon natural gas market price volatility driven by variations in both the supply and demand balances caused by weather and other factors. As a result, variations in weather patterns in the key market areas served may affect earnings during the fiscal year. Changes in market fundamentals, such as an increase in supply and decrease in demand due to milder temperatures, and reduced volatility, can negatively impact Energy Services’ earnings. See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution Segment for TETCO M-3 Daily Prices, which illustrates the daily natural gas prices in the Northeast market region.

Operation and Maintenance Expense

O&M expense decreased $3.6 million during fiscal 2020, compared with fiscal 2019, due primarily to decreased compensation costs.

Income Tax Benefit

Income taxes increased $2 million during fiscal 2020, compared with fiscal 2019, due primarily to decreased operating income.

Net Loss

Net loss increased $9.7 million during fiscal 2020, compared with fiscal 2019, due primarily to lower operating income, partially offset by the related increase in income tax benefit, as previously discussed.

Non-GAAP Financial Measures

Management uses financial margin and NFE, non-GAAP financial measures, when evaluating the operating results of Energy Services. Financial margin and NFE are based on removing timing differences associated with certain derivative instruments, as discussed above. There is a related tax effect on current and deferred income tax expense corresponding with NFE.

Management views these measures as representative of the overall expected economic result and uses these measures to compare Energy Services’ results against established benchmarks and earnings targets as these measures eliminate the impact of volatility on GAAP earnings as a result of timing differences associated with the settlement of derivative instruments. To the extent that there are unanticipated impacts from changes in the market value related to the effectiveness of economic hedges, Energy Services’ actual non-GAAP results can differ from the results anticipated at the outset of the transaction. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.

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

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Financial Margin

The following table is a computation of Energy Services’ financial margin for the fiscal years ended September 30.

(Thousands)	2020		2019		2018
Operating revenues	$	1,030,419	$	1,742,791	$	2,112,804
Less: Natural gas purchases	1,024,579		1,719,519		1,995,335
Add:
Unrealized (gain) loss on derivative instruments and related transactions (1)	(8,583)		1,195		26,728
Effects of economic hedging related to natural gas inventory (2)	12,690		4,309		(22,570)
Financial margin	$	9,947	$	28,776	$	121,627

(1)Includes unrealized (gains) losses related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $(809,000), $995,000 and $85,000 for the fiscal years ended September 30, 2020, 2019 and 2018, respectively.

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

A reconciliation of operating income, the closest GAAP financial measure to Energy Services’ financial margin, is as follows for the fiscal years ended September 30:

(Thousands)	2020		2019		2018
Operating (loss) income	$	(11,651)	$	2,211	$	81,777
Add:
Operation and maintenance	17,368		20,943		35,616
Depreciation and amortization	123		118		76
Subtotal	5,840		23,272		117,469
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(8,583)		1,195		26,728
Effects of economic hedging related to natural gas inventory	12,690		4,309		(22,570)
Financial margin	$	9,947	$	28,776	$	121,627

Financial margin decreased $18.8 million during fiscal 2020, compared with fiscal 2019, due primarily to warmer weather compared to the prior period, which led to decreased demand and lower natural gas prices, increased natural gas in storage and ultimately decreased volatility in the wholesale natural gas markets.

Net Financial Earnings

A reconciliation of Energy Services’ net income (loss), the most directly comparable GAAP financial measure to NFE, is as follows for the fiscal years ended September 30:

(Thousands)	2020		2019		2018
Net (loss) income	$	(11,008)	$	(1,268)	$	53,139
Add:
Unrealized (gain) loss on derivative instruments and related transactions	(8,583)		1,195		26,728
Tax effect (1)	2,044		(294)		(4,281)
Effects of economic hedging related to natural gas inventory	12,690		4,309		(22,570)
Tax effect	(3,016)		(1,024)		7,362
Net financial earnings	$	(7,873)	$	2,918	$	60,378

(1)Includes taxes related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $252,000, $(310,000) and $(337,000) for the fiscal years ended September 30, 2020, 2019 and 2018, respectively.

NFE decreased $10.8 million during fiscal 2020, compared with fiscal 2019, due primarily to lower financial margin, as previously discussed.

Future results are subject to Energy Services’ ability to expand its wholesale sales and service activities and are contingent upon many other factors, including an adequate number of appropriate and credit-qualified counterparties in an active and liquid natural marketplace; volatility in the natural gas market due to weather or other fundamental market factors impacting supply and/or demand; transportation, storage and/or other market arbitrage opportunities; sufficient liquidity in the overall energy trading market; and continued access to liquidity in the capital markets.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Storage and Transportation Segment, formerly Midstream

Overview

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

Our Storage and Transportation segment is comprised of a 50 percent ownership interest in Steckman Ridge, a storage facility that operates under market-based rates and a 20 percent ownership interest in PennEast, a natural gas pipeline. NJR Midstream Company acquired 100 percent of Leaf River for $367.5 million, on October 11, 2019. Leaf River owns and operates a 32.2 million Dth salt dome natural gas storage facility that operates under market-based rates. In addition, on January 13, 2020, Adelphia Gateway, acquired all of Talen’s membership interests in IEC, an existing 84-mile pipeline in southeastern Pennsylvania, including related assets and rights of way, for a base purchase price of $166 million. Adelphia Gateway operates under cost of service rates but can enter into negotiated rates with counterparties. The northern portion of the pipeline was operational upon acquisition and it currently serves two natural gas generation facilities. The conversion of the southern portion of the pipeline to natural gas began in October 2020 upon receipt of the Notice to Proceed from FERC.

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

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

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

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

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

On February 18, 2020, PennEast filed a writ of certiorari with the Supreme Court of the U.S. to review the September 10, 2019 Third Circuit decision. On June 29, 2020, the Supreme Court requested that the Solicitor General of the U.S. file a brief that expresses the views on the question of the use of eminent domain to acquire state owned lands for pipeline construction. 

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

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

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

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

As of September 30, 2020, our investments in Steckman Ridge and PennEast were $112.4 million and $96 million, respectively.

Operating Results

The financial results of our Storage and Transportation segment for the fiscal years ended September 30, are summarized as follows:

(Thousands)	2020		2019		2018
Operating revenues (1)	$	44,728	$	—	$	—
Operating expenses
Natural gas purchases	1,122		—		—
Operation and maintenance	21,862		4,043		4,448
Depreciation and amortization	9,293		6		6
Total operating expenses	32,277		4,049		4,454
Operating income	12,451		(4,049)		(4,454)
Other income, net	7,328		7,345		5,775
Interest expense, net	13,124		2,185		1,667
Income tax provision	4,247		2,254		(8,548)
Equity in earnings of affiliates	15,903		15,832		16,165
Net income	$	18,311	$	14,689	$	24,367

(1)Includes related party transactions of approximately $2.7 million, which are eliminated in consolidation.

Operating revenue in fiscal 2020 increased $44.7 million, due to operating revenues at Leaf River and Adelphia Gateway that were not present during fiscal 2019.

Equity in earnings of affiliates remained flat during fiscal 2020, compared with fiscal 2019, due primarily to decreases in storage revenue at Steckman Ridge, offset by an increase in AFUDC earned at PennEast.

O&M and depreciation expenses increased $17.8 million and $9.3 million, respectively during fiscal 2020, compared with fiscal 2019, due primarily to operations of Leaf River and Adelphia Gateway during fiscal 2020.

Interest expense, net increased $10.9 million during fiscal 2020, compared with fiscal 2019, due primarily to increased debt service requirements related to the acquisition of Leaf River and Adelphia Gateway.

Income tax provision increased $2 million during fiscal 2020, compared with fiscal 2019, due primarily to the increased operating income generated at Leaf River and Adelphia Gateway.

Net income in fiscal 2020 increased $3.6 million, compared with fiscal 2019, due primarily to an increased revenue, partially offset by increased O&M and interest expense, as previously discussed.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Home Services and Other Operations

Overview

The financial results of Home Services and Other consist primarily of the operating results of NJRHS. NJRHS provides service, sales and installation of appliances to approximately 107,000 service contract customers. Home Services and Other also includes organizational expenses incurred at NJR and rental income at CR&R.

Operating Results

The condensed consolidated financial results of Home Services and Other for the fiscal years ended September 30, are summarized as follows:

(Thousands)	2020		2019		2018
Operating revenues	$	51,017	$	50,902	$	50,057
Operation and maintenance (1)	$	41,529	$	44,846	$	46,561
Income tax (benefit) provision	$	(2,478)	$	1,428	$	11,944
Net income (loss)	$	5,784	$	1,637	$	(3,555)

(1)Includes energy and other taxes due to change in presentation in the Consolidated Statements of Operations.

O&M expense decreased $3.3 million during fiscal 2020, compared with fiscal 2019, due primarily to lower consulting expenses related to technology improvement projects that were higher in the prior year, partially offset by increased compensation and shared corporate costs in the current period.

Income tax expenses decreased $3.9 million during fiscal 2020, compared with fiscal 2019, due primarily to tax credits and impacts of New Jersey corporate business tax reform.

Net income increased $4.1 million during fiscal 2020, compared with fiscal 2019, due primarily to changes in income taxes noted above.

Non-GAAP Financial Measures

NFE is based on removing timing differences associated with NJR's variable-for-fixed interest rate swap. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP, and should be considered in addition to, and not as a substitute, for the comparable GAAP measure. A reconciliation of Home Services and Other's net income for the fiscal years ended September 30, to the GAAP financial measure most directly comparable to NFE, is as follows:

(Thousands)	2020		2019		2018
Net income (loss)	$	5,784	$	1,637	$	(3,555)
Add:
Unrealized loss (gain) on derivative instruments and related transactions	—		381		(381)
Tax effect	—		(107)		107
Net financial earnings (loss)	$	5,784	$	1,911	$	(3,829)

Liquidity and Capital Resources

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

Our consolidated capital structure as of September 30, was as follows:

	2020		2019
Common stock equity	40	%	47	%
Long-term debt	56		52
Short-term debt	4		1
Total	100	%	100	%

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Common Stock Equity

We satisfy our external common equity requirements, if any, through issuances of our common stock, including the proceeds from stock issuances under our DRP. The DRP allows us, at our option, to use treasury shares or newly issued shares to raise capital. NJR raised approximately $18.1 million and $16.7 million of equity through the DRP by issuing approximately 520,000 and 351,000 shares of treasury stock, fiscal 2020 and 2019, respectively. During the fiscal 2019, NJR raised approximately $57.4 million of equity by issuing approximately 1,181,000 shares of common stock through the waiver discount feature of the DRP. There were no shares of common stock issued through the waiver discount feature of the DRP during fiscal 2020.

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

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

On September 18, 2020, the Company amended our forward sale agreements to extend the maturity date of such forward sales agreements from September 30, 2020 to September 10, 2021. As of September 30, 2020, if we had elected to net settle the forward sale agreements, we would have received $14 million under a cash settlement or 543,150 common shares under a net share settlement.

In 1996, the Board of Directors authorized us to implement a share repurchase program, which has been expanded seven times since the inception of the program, authorizing a total of 19.5 million shares of common stock for repurchase. As of September 30, 2020, we have repurchased a total of approximately 17.1 million shares and may repurchase an additional 2.4 million shares under the approved program. There were no shares of common stock shares repurchased during fiscal 2020 and 2019.

Debt

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

We believe that our existing borrowing availability, equity proceeds and cash flows from operations will be sufficient to satisfy our working capital, capital expenditures and dividend requirements for the next 12 months. NJR, NJNG, Clean Energy Ventures, Transportation and Storage and Energy Services currently anticipate that each of their financing requirements for the next 12 months will be met primarily through the issuance of short and long-term debt, meter and solar sale leasebacks.

We believe that as of September 30, 2020, NJR and NJNG were, and currently are, in compliance with all existing debt covenants, both financial and non-financial.

As a result of the COVID-19 pandemic there have been disruptions, uncertainty and volatility in the credit and capital markets. The Company has been able to obtain sufficient financing to meet its funding requirements for operations and capital expenditures.

Short-Term Debt

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

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

As of September 30, 2020, NJR had revolving credit facilities totaling $675 million, with $539.4 million available under the facilities. On July 23, 2020, the remaining borrowings for the $350 million Bridge Facility were repaid.

NJNG satisfies its debt needs by issuing short-term and long-term debt based on its financial profile. The seasonal nature of NJNG’s operations creates large short-term cash requirements, primarily to finance natural gas purchases and customer accounts receivable. NJNG obtains working capital for these requirements, and for the temporary financing of construction and MGP remediation expenditures and energy tax payments, based on its financial profile, through the issuance of commercial paper supported by the NJNG Credit Facility or through short-term bank loans under the NJNG Credit Facility.

NJNG’s commercial paper is sold through several commercial banks under an issuing and paying agency agreement and is supported by the $250 million NJNG Credit Facility. As of September 30, 2020, the unused amount available under the NJNG Credit Facility, including amounts allocated to the backstop under the commercial paper program and the issuance of letters of credit, was $249.3 million.

Short-term borrowings were as follows:

	Three Months Ended			Twelve Months Ended
($ in thousands)	September 30, 2020
NJR
Notes Payable to banks:
Balance at end of period	$	125,350		$	125,350
Weighted average interest rate at end of period	1.49		%	1.49		%
Average balance for the period	$	178,400		$	404,823
Weighted average interest rate for average balance	1.07		%	1.93		%
Month end maximum for the period	$	336,300		$	416,300
NJNG
Commercial Paper and Notes Payable to banks:
Balance at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Average balance for the period	$	—		$	13,940
Weighted average interest rate for average balance	—		%	1.61		%
Month end maximum for the period	$	—		$	62,300

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

NJR

Based on its average borrowings during fiscal 2020, NJR’s average interest rate was 1.93 percent, resulting in interest expense of approximately $7.8 million.

As of September 30, 2020, NJR had seven letters of credit outstanding totaling $10.3 million, which reduced the amount available under the NJR Credit Facility by the same amount. NJR does not anticipate that these letters of credit will be drawn upon by the counterparties.

On October 9, 2019, NJR entered into a $350 million Bridge Facility, which was used primarily to finance the Leaf River acquisition. The Bridge Facility accrued interest at the LIBOR rate for a 1-month interest period plus 0.875 percent during the first 180 days, and 1.075 percent after 180 days, which was dependent on the credit rating of NJNG from Fitch and Moody’s. The occurrence of an event of default under the Bridge Facility would have resulted in all loans and other obligations of NJR becoming immediately due and payable and the Bridge Facility being terminated. Loans under the Bridge Facility were required to be prepaid to the extent of new cash proceeds received upon the issuance of equity of NJR, the incurrence of indebtedness by NJR or its subsidiaries, the disposition of assets by NJR or its subsidiaries or upon other specified events, in each case subject to certain exceptions set forth in the Bridge Facility. The net proceeds from the December 2019 equity issuance were used to pay down the Bridge Facility. On April 23, 2020, the Bridge Facility was amended to clarify that the April 24, 2020 $250 million revolving credit facility was not considered a debt issuance that requires prepayment of the Bridge Facility. On July 23, 2020, the outstanding borrowings were repaid in full.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

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

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

NJNG

As noted above, based on its average borrowings during fiscal 2020, NJNG’s average interest rate was 1.61 percent, resulting in interest expense of approximately $265,000.

As of September 30, 2020, NJNG had two letters of credit outstanding for $731,000, which reduced the amount available under NJNG’s committed credit facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by the counterparties.

Short-Term Debt Covenants

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

•incur additional debt;

•incur liens and encumbrances;

•make dispositions of assets;

•enter into transactions with affiliates; and

•merge, consolidate, transfer, sell or lease all or substantially all of the borrowers’ or guarantors’ assets.

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

Default Provisions

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

•defaults for non-payment;

•defaults for breach of representations and warranties;

•defaults for insolvency;

•defaults for non-performance of covenants;

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

•guarantor defaults.

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

Long-Term Debt

NJR

As of September 30, 2020, NJNG's long-term debt consisted of $1.1 billion in fixed-rate debt issuances secured by the Mortgage Indenture, with maturities ranging from 2024 to 2060, and $63.7 million in finance leases with various maturities ranging from 2021 to 2026.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

As of September 30, 2020, NJR had the following outstanding:

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

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

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

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

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

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

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

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

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

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

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

On May 14, 2020, NJR entered into a Note Purchase Agreement for $260 million of its senior notes, of which $130 million are at a fixed interest rate of 3.5 percent, maturing in 2030, and $130 million are at a fixed interest rate of 3.6 percent, maturing in 2032. On July 23, 2020, NJR issued all $260 million of the senior notes. The senior notes are unsecured and guaranteed by certain unregulated subsidiaries of NJR.

On September 1, 2020, NJR entered into and issued a Note Purchase Agreement for $200 million of its senior notes, of which $120 million are at a fixed interest rate of 3.13 percent, maturing in 2031, and $80 million are at a fixed interest rate of 3.25 percent, maturing in 2033. The senior notes are unsecured and guaranteed by certain unregulated subsidiaries of NJR.

NJNG

As of September 30, 2020, NJNG’s long-term debt consisted of $1.1 billion in fixed-rate debt issuances secured by the Mortgage Indenture, with maturities ranging from 2024 to 2060, and $63.7 million in finance leases with various maturities ranging from 2021 to 2026.

On May 14, 2020, NJNG entered into a Note Purchase Agreement for $125 million of its senior notes, of which $100 million were at an interest rate of 3.13 percent, maturing in 2050, and $25 million were at an interest rate of 3.33 percent, maturing in 2060. On June 30, 2020, NJNG issued $50 million of 3.13 percent senior notes due June 30, 2050. On July 23, 2020, NJNG issued the remaining $50 million of 3.13 percent senior notes due July 23, 2050 and $25 million of 3.33 percent senior notes due July 23, 2060. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

On September 1, 2020, NJNG entered into and issued a Note Purchase Agreement for $75 million of its senior notes, of which $25 million were at an interest rate of 2.87 percent, maturing in 2050, and $50 million were at an interest rate of 2.97 percent, maturing in 2060. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

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

Long-Term Debt Covenants and Default Provisions

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

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

•incur liens and encumbrances;

•make loans and investments;

•make dispositions of assets;

•make dividends or restricted payments;

•enter into transactions with affiliates; and

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

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

The aforementioned covenants are subject to a number of exceptions and qualifications set forth in the applicable Note Purchase Agreements.

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

•failure for 30 days to pay interest when due;

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

•failure to make sinking fund payments when due;

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

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

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

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

Sale Leaseback

NJNG

NJNG received $4 million, $9.9 million and $7.8 million in fiscal 2020, 2019 and 2018, respectively, in connection with the sale leaseback of its natural gas meters. During fiscal 2020, 2019 and 2018, NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1.2 million, $1.1 million and $2.2 million, respectively. NJNG continues to evaluate this sale leaseback program based on current market conditions. As noted, natural gas meters are excepted from the lien on NJNG property under the Mortgage Indenture.

Clean Energy Ventures

During fiscal 2020, Clean Energy Ventures received proceeds of $42.9 million in connection with the sale leaseback of three commercial solar projects. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during fiscal 2019. Clean Energy Ventures entered into transactions to sell certain of its commercial solar assets concurrent with agreements to lease the assets back over five to 15-year terms. These sale leasebacks are financing obligations secured by the solar assets, related future cash flows from SREC and energy sales and a continuing guaranty by NJR. ITCs and other tax benefits associated with these solar projects were transferred to the buyer. Clean Energy Ventures will continue to operate the solar projects and retain ownership of SRECs generated and has the option to renew the lease or repurchase the assets at the end of the lease term per the terms of the arrangement.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Contractual Obligations

The following table is a summary of contractual cash obligations and financial commitments and their applicable payment due dates as of September 30, 2020:

			Up to		1-3		3-5		After
(Thousands)	Total		1 Year		Years		Years		5 Years
Long-term debt (1)	$	3,358,967	$	73,138	$	244,411	$	352,193	$	2,689,225
Finance lease obligations (1)	76,617		54,992		10,626		8,675		2,324
Solar asset financing obligations (1)	108,013		12,928		25,929		21,888		47,268
Operating leases (1)	5,453		1,589		2,727		1,064		73
Short-term debt	125,350		125,350		—		—		—
New Jersey Clean Energy Program (1)	15,569		15,569		—		—		—
Construction obligations	19,341		19,341		—		—		—
Remediation expenditures (2)	150,590		35,609		36,928		18,240		59,813
Natural gas supply purchase obligations-NJNG	4,377		4,377		—		—		—
Demand fee commitments-NJNG	1,156,597		124,660		291,617		184,325		555,995
Natural gas supply purchase obligations-Energy Services	152,870		151,270		1,600		—		—
Demand fee commitments-Energy Services	286,668		98,319		104,847		46,033		37,469
Total contractual cash obligations	$	5,460,412	$	717,142	$	718,685	$	632,418	$	3,392,167

(1)These obligations include an interest component, as defined under the related governing agreements or in accordance with the applicable tax statute.

(2)Expenditures are estimated. See Note 15. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements.

NJR does not expect to be required to make additional contributions to fund the pension plans over the next three fiscal years based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents. In addition, as in the past, we may elect to make discretionary contributions to the plans in excess of the minimum required amount. We made no discretionary contributions to the pension plans in fiscal 2020 and 2019. There are no federal requirements to pre-fund OPEB benefits. However, we are required to fund certain amounts due to regulatory agreements with the BPU. We anticipate that the annual funding level of the OPEB plans will range from $5 million to $10 million annually over each of the next five years. Additional contributions may vary based on market conditions and various assumptions.

As of September 30, 2020, there were NJR guarantees covering approximately $258 million of natural gas purchases and Energy Services demand fee commitments not yet reflected in accounts payable on the Consolidated Balance Sheets.

During fiscal 2020, committed and spent capital expenditures totaled $333.9 million. During fiscal 2021 and 2022, NJNG’s total capital expenditures are projected to be $443.4 million and $370.3 million, respectively. NJNG expects to fund its obligations with a combination of cash flow from operations, cash on hand, issuance of commercial paper, available capacity under its revolving credit facility and the issuance of long-term debt. As of September 30, 2020, NJNG’s future MGP expenditures are estimated to be $150.6 million. For a more detailed description of MGP see Note 15. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements.

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

Clean Energy Ventures’ expenditures include clean energy projects that support our goal to promote renewable energy. Accordingly, Clean Energy Ventures enters into agreements to install solar equipment involving both residential and commercial projects. We estimate the value of solar-related projects placed in service during fiscal 2021 to be between $155 million and $175 million.

Capital expenditures related to clean energy projects are subject to change due to a variety of factors that may affect our ability to commence operations at these projects on a timely basis or at all, including sourcing projects that meet our investment criteria, logistics associated with the start-up of residential and commercial solar projects, such as timing of construction schedules, the permitting and regulatory process, any delays related to electric grid interconnection, economic trends or unforeseen events and the ability to access capital or allocation of capital to other investments or business opportunities.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

During fiscal 2020, capital expenditures related to our storage and transportation investment in the Adelphia Gateway project were $180.1 million, which includes the purchase price of $166 million that was paid upon the close of the acquisition of the related assets in January 2020. We estimate expenditures related to the Adelphia Gateway project to be between $136 million and $156 million in fiscal 2021. Our Storage and Transportation segment had a total of $2.1 million of expenditures related to our investment in the PennEast pipeline project. Expenditures on the PennEast pipeline are expected to total between $7 million and $8 million during fiscal 2021.

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

Off-Balance-Sheet Arrangements

Our off-balance-sheet arrangements consist of guarantees covering approximately $258 million of natural gas purchases, SREC sales and demand fee commitments, and nine outstanding letters of credit totaling $11 million, as previously mentioned. See Note 15. Commitments and Contingent Liabilities and Note 9. Debt for more information.

Cash Flows

Operating Activities

Cash flows from operating activities during fiscal 2020 totaled $213.5 million compared with $194.1 million during fiscal 2019. Operating cash flows are primarily affected by variations in working capital, which can be impacted by several factors, including:

•seasonality of our business;

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

•timing of storage injections and withdrawals;

•the deferral and recovery of natural gas costs;

•changes in contractual assets used to optimize margins related to natural gas transactions;

•broker margin requirements;

•impact of unusual weather patterns on our wholesale business;

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

•volumes of natural gas purchased and sold; and

•timing of SREC deliveries.

The increase of $19.3 million in operating cash flows during fiscal 2020, compared with fiscal 2019, was due primarily to increased margin at our Natural Gas Distribution segment related to increased base rates.

Investing Activities

Cash flows used in investing activities totaled $994 million during fiscal 2020, compared with $287.4 million during fiscal 2019. The increase of $706.6 million was due primarily to the acquisition of Leaf River and Adelphia Gateway and proceeds from the sale of our wind assets in February 2019, that did not recur in fiscal 2020.

Financing Activities

Financing cash flows generally are seasonal in nature and are impacted by the volatility in pricing in the natural gas and other energy markets. NJNG’s inventory levels are built up during its natural gas injection season (April through October) and reduced during withdrawal season (November through March) in response to the supply requirements of its customers. Changes in financing cash flows can also be impacted by natural gas management and marketing activities at Energy Services and clean energy investments at Clean Energy Ventures.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF

OPERATIONS (Continued)                                                                                                                                                             

Cash flows from financing activities during fiscal 2020 totaled $895.9 million, compared with $95.6 million during fiscal 2019. The increase of $800.3 million was due primarily to the issuance of $460 million and $200 million of long-term debt at NJR and NJNG, respectively, and increased short-term debt activity at NJR primarily related to the acquisition of Leaf River and Adelphia Gateway, as well as proceeds of $42.9 million from solar sale leasebacks at Clean Energy Ventures and proceeds from equity offering of $212.9 million.

NJNG received $4 million, $9.9 million and $7.8 million for fiscal 2020, 2019 and 2018, respectively, in connection with the sale leaseback of its natural gas meters. During fiscal 2020, 2019 and 2018, NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1.2 million, $1.1 million and $2.2 million, respectively. NJNG continues to evaluate the natural gas meter sale leaseback program based on current market conditions.

Credit Ratings

The table below summarizes NJNG’s current credit ratings issued by two rating entities, Moody’s and Fitch, as of September 30, 2020:

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

The Fitch ratings and outlook were reaffirmed on March 18, 2020. NJNG's Moody’s and Fitch ratings are investment-grade ratings. NJR is not a rated entity.

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

Although NJNG is not party to any lending agreements that would accelerate the maturity date of any obligation caused by a failure to maintain any specific credit rating, if such ratings are downgraded below investment grade, borrowing costs could increase, as would the costs of maintaining certain contractual relationships, and future financing and our access to capital markets would be reduced. Even if ratings are downgraded without falling below investment grade, NJR and NJNG could face increased borrowing costs under their credit facilities. A rating set forth above is not a recommendation to buy, sell or hold NJR’s or NJNG’s securities and may be subject to revision or withdrawal at any time. Each rating set forth above should be evaluated independently of any other rating.

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

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA                                                                              

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of New Jersey Resources Corporation is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) and 15d-15(f) of the Securities and Exchange Act of 1934, as amended. The Company’s internal control over financial reporting is a process designed to provide reasonable assurance to the Company’s Management and Board of Directors regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles and includes policies and procedures that:

•pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company;

•provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and

•provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company’s assets that could have a material effect on the financial statements.

Under the supervision and with the participation of the Company’s management, including its principal executive officer and principal financial officer, management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting as of September 30, 2020. In making this assessment, management used the criteria for effective internal control over financial reporting described in the Internal Control-Integrated Framework (2013) set forth by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the assessment, management concluded that, as of September 30, 2020, the Company’s internal control over financial reporting was effective to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the Unites States of America.

The conclusion of the Company’s principal executive officer and principal financial officer is based on the recognition that there are inherent limitations in all systems of internal control over financial reporting. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements, errors or fraud. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

The Company’s independent registered public accounting firm, Deloitte & Touche LLP, has issued its report on the effectiveness of the Company’s internal control over financial reporting as of September 30, 2020, which appears herein.

November 30, 2020

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareowners and the Board of Directors of New Jersey Resources Corporation:

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of New Jersey Resources Corporation and subsidiaries (the "Company") as of September 30, 2020 and 2019, and the related consolidated statements of operations, comprehensive income, common stock equity, and cash flows, for each of the three years in the period ended September 30, 2020, and the related notes and the financial statement schedule listed in the Index at Item 15 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of September 30, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2020, in conformity with accounting principles generally accepted in the United States of America.

Change in Accounting Principle

As discussed in Note 2 to the financial statements, the Company has elected to change its method of accounting for investment tax credits at Clean Energy Ventures from the flow through method to the deferral method effective October 1, 2020, resulting in retrospective changes in 2020, 2019, and 2018.

Basis for Opinion

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

Regulation — Impact of Rate-Regulation on Various Account Balances and Disclosures — Refer to Notes 2 and 4 to the financial statements

Critical Audit Matter Description

New Jersey Natural Gas Company (“NJNG”), a subsidiary of the Company, is a regulated gas distribution company that serves customers in central and northern New Jersey. NJNG is subject to regulation by the New Jersey Board of Public Utilities (the “BPU”), which has jurisdiction with respect to the rates of gas distribution companies in New Jersey. Management has determined NJNG meets the requirements under accounting principles generally accepted in the United States of America to prepare its financial statements in accordance with the ASC 980, Regulated Operations.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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. Regulatory decisions can have an impact on the recovery of costs, the rate of return earned on investment, and the timing and amount of assets to be recovered by rates. Decisions to be made by the BPU in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required.

Accounting for the economics of rate-regulation impacts multiple financial statement line items and disclosures, such as regulated property, plant, and equipment, regulatory assets and liabilities, operating revenues and depreciation expense. While NJNG has indicated it expects to recover costs from customers through regulated rates, there is a risk that the BPU will not approve full recovery of such costs or full recovery of all amounts invested in the utility business and a reasonable return on that investment. We identified the impact of rate-regulation as a critical audit matter due to the significant judgments made by management to support its assertions about the impact of regulatory orders on the financial statements, including assessing the probability of both recovery in rates of incurred costs, and refunds to customers. Given that management’s accounting judgments are based on assumptions about the outcome of future decisions by the BPU, auditing these judgments requires specialized knowledge of accounting for rate regulation and the rate setting process due to its inherent complexities.

How the Critical Audit Matter Was Addressed in the Audit

Our audit procedures related to the uncertainty around the impact of regulatory orders on the financial statements, including the probability of recovery in rates of incurred costs and a refund to customers included the following, among others:

•We tested the effectiveness of controls over the relevant regulatory account balances and disclosures, including management’s controls over the monitoring and evaluation of regulatory developments that may affect the probability of recovering costs in future rates or of a future reduction in rates.

•We read relevant regulatory orders issued by the BPU for NJNG and other public utilities in New Jersey, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the probability of recovery in future rates or of a future reduction in rates based on precedence of the BPU’s treatment of similar costs under similar circumstances. We also read the November 13, 2019 BPU order adopting the stipulation of settlement for NJNG’s March 2019 base rate case as well as the publicly available filings made by NJNG and its related attachments. We evaluated the external information and compared that to management’s assertions regarding the probability of recovery or refund of regulatory asset and liability balances for completeness.

•We obtained an analysis from management regarding the probability of recovery for regulatory assets or refund or future reduction in rates for regulatory liabilities in order to assess management’s assertion that amounts are probable of recovery or refund or a future reduction in rates.

•We evaluated the Company’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory developments.

Investments in Equity Investees – Steckman Ridge — Refer to Notes 2 and 7 to the financial statements

Critical Audit Matter Description

The Company, through its subsidiary Steckman Ridge Storage Company, holds a 50 percent equity method investment in Steckman Ridge, a natural gas storage facility located in Bedford County, Pennsylvania. In the fourth quarter of fiscal 2020, a major customer contract expired and was not renewed.

The Company evaluated its investment for an other-than-temporary impairment by comparing the estimated fair value of the investment to the carrying value and determined that an impairment charge was not necessary. The Company estimated the fair value of the investment using a discounted cash flow method. Management made estimates and assumptions related to the price and capacity of future firm natural gas storage contracting, operations and maintenance costs, the nature and timing of major maintenance and capital investment, and the discount rates.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

We identified the evaluation of other-than-temporary impairment for the Steckman Ridge investment as a critical audit matter because of the significant estimates and assumptions management made to estimate the fair value of its investment. This required a high degree of auditor judgment and an increased extent of effort, including the need to involve our internal specialists, when performing audit procedures to evaluate the reasonableness of management’s estimates and assumptions related to the price and capacity of future firm natural gas storage contracting and the discount rate used in the discounted future cash flow method.

How the Critical Audit Matter Was Addressed in the Audit

Our audit procedures related to the price and capacity of future firm natural gas storage contracting and the discount rate used by management to estimate the fair value of the Steckman Ridge investment to evaluate impairment included the following, among others:

•We tested the effectiveness of controls over management’s evaluation of the Steckman Ridge investment for impairment including those related to the price and capacity of future firm natural gas storage contracting and the discount rates.

•We evaluated the reasonableness of the price and capacity of future firm natural gas storage contracting by:

–Making inquiries with operations and executive management teams regarding the viability of recontracting and optimizing the capacity associated with the expired contract.

–Comparing management’s volume assumptions to comparable contractual agreements where applicable, and to information regarding demand in the region.

–Comparing management’s rate assumptions to comparable contractual agreements where applicable and evaluating management’s future price assumptions against relevant market price information.

–Reading internal communications to management and the Board of Directors and other Steckman Ridge member communications to search for contradictory information.

•We evaluated the selection of the discount rate with the assistance of our fair value specialists, by:

–Testing the source information underlying the determination of the discount rate and the mathematical accuracy of the calculation.

–Developing a range of independent estimates and comparing those to the discount rate selected by management.  

Investments in Equity Investees – PennEast — Refer to Notes 2 and 7 to the financial statements

Critical Audit Matter Description

The Company, through its subsidiary NJR Midstream Company, is a 20 percent investor in PennEast Pipeline Company, LLC (“PennEast”), a partnership whose purpose is to construct and operate a 120-mile natural gas pipeline that will extend from northeast Pennsylvania to western New Jersey. In the fourth quarter of fiscal 2019, PennEast received certain adverse court rulings, which remain in effect as of the fiscal 2020 balance sheet date.

The Company evaluated its investment for other-than-temporary impairment by comparing the estimated fair value of the investment to the carrying value and determined that an impairment charge was not necessary. The Company estimated the fair value of its investment using probability-weighted scenarios of discounted future cash flows. Management made significant estimates and assumptions related to development options and legal outcomes, construction costs, timing of capital investments and in-service dates, revenues (including forecasted volumes and rates), and discount rates. The discounted cash flow scenarios contemplate the impact of key assumptions of potential future court decisions and potential future management decisions and requires management to make significant estimates regarding the likelihood of various scenarios and assumptions. Higher probabilities were assumed related to those scenarios where the project is completed.

We identified the evaluation of other-than-temporary impairment for the PennEast investment as a critical audit matter because of the significant estimates and assumptions management makes to estimate the fair value of its investment. This required a high degree of auditor judgment and an increased extent of effort, including the need to involve our fair value specialists, when performing audit procedures to evaluate the reasonableness of management’s estimates and assumptions related to the probabilities associated with the development options and legal outcomes, the forecasted amount and timing of future revenues, and the selection of the discount rate used in the probability-weighted scenarios of discounted future cash flows.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

How the Critical Audit Matter Was Addressed in the Audit

Our audit procedures related to the probabilities associated with the development options and legal outcomes, the forecasted amount and timing of future revenues, and the selection of the discount rate used by management in the probability-weighted scenarios of discounted future cash flows used in the evaluation of impairment for the PennEast investment included the following, among others:

•We tested the effectiveness of controls over management’s evaluation of the PennEast investment for impairment including those related to the probabilities associated with the development options and legal outcomes, the forecasting of future revenues, and the selection of the discount rate.

•We evaluated the reasonableness of the probabilities related to the development options and legal outcomes by making inquiries with legal counsel regarding the likely outcomes of future court rulings, and with engineering, operations, and the executive management team regarding the viability of development options. We compared the results of these legal and management inquiries to internal communications to management, the Board of Directors, and PennEast member partners to search for contradictory information. We also read external information included in press releases, earnings releases, regulatory filings, and other PennEast member communications to search for contradictory information.

•We evaluated the reasonableness of the forecasted amount and timing of future revenues (including forecasted volumes and rates) by:

–Comparing management’s volume assumptions to contractual agreements where applicable, and to information regarding demand and capacity volumes in the region for the remaining volumes.

–Comparing management’s rate assumptions to contractual agreements where applicable and evaluating management’s future price assumptions against relevant market price curves.

–Reading internal communications to management and the Board of Directors and external information included in press releases, earnings releases and other PennEast member communications to search for contradictory information.

•We evaluated the selection of the discount rate with the assistance of our fair value specialists, by:

–Testing the source information underlying the determination of the discount rate and the mathematical accuracy of the calculation.

–Developing a range of independent estimates and comparing those to the discount rate selected by management.

/s/ Deloitte & Touche LLP

Parsippany, New Jersey

November 30, 2020 (September 24, 2021, as to the effects of the change in accounting policy discussed in Note 2)

We have served as the Company's auditor since 1951.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

CONSOLIDATED STATEMENTS OF OPERATIONS

(Thousands, except per share data)
Fiscal years ended September 30,	2020		2019		2018
OPERATING REVENUES
Utility	$	729,923	$	710,793	$	731,865
Nonutility	1,223,745		1,881,252		2,183,244
Total operating revenues	1,953,668		2,592,045		2,915,109
OPERATING EXPENSES
Natural gas purchases:
Utility	275,831		320,256		276,005
Nonutility	1,022,805		1,716,098		1,990,832
Related parties	6,083		7,948		8,505
Operation and maintenance	278,143		268,141		315,215
Regulatory rider expenses	34,529		33,937		38,969
Depreciation and amortization	107,368		81,109		76,571
Total operating expenses	1,724,759		2,427,489		2,706,097
OPERATING INCOME	228,909		164,556		209,012
Other income, net	23,878		11,273		13,047
Interest expense, net of capitalized interest	67,597		47,082		46,286
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	185,190		128,747		175,773
Income tax expense (benefit)	36,494		18,440		(42,232)
Equity in earnings of affiliates	14,311		13,628		13,008
NET INCOME	$	163,007	$	123,935	$	231,013
EARNINGS PER COMMON SHARE
Basic	$1.72		$1.39		$2.63
Diluted	$1.71		$1.38		$2.62
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic	94,798		89,242		87,689
Diluted	95,103		89,596		88,315

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Thousands)
Fiscal years ended September 30,	2020		2019		2018
Net income	$	163,007	$	123,935	$	231,013
Other comprehensive (loss) income, net of tax:
Unrealized (loss) on investments in equity securities, net of tax of $0, $0 and $6,973, respectively	—		—		(19,245)
Reclassifications of losses to net income on investments in equity securities, net of tax of $0, $0 and $(858), respectively	—		—		11,647
Reclassifications of losses to net income on derivatives designated as hedging instruments, net of tax of $(32), $0 and $0, respectively	108		—		—
Loss on derivatives designated as hedging instruments, net of tax of $3,203, $0 and $0, respectively	(10,505)		—		—
Adjustment to postemployment benefit obligation, net of tax of $567, $6,106, and $(573), respectively	(2,131)		(15,731)		1,520
Other comprehensive (loss)	(12,528)		(15,731)		(6,078)
Comprehensive income	$	150,479	$	108,204	$	224,935

See Notes to Consolidated Financial Statements

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands)
Fiscal years ended September 30,	2020		2019		2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	163,007	$	123,935	$	231,013
Adjustments to reconcile net income to cash flows from operating activities
Unrealized gain on derivative instruments	(9,644)		2,881		26,770
Gain on sale of available for sale securities	—		(1,567)		(5,332)
Gain on sale of businesses	—		(645)		(4,663)
Depreciation and amortization	107,368		81,109		76,571
Noncash lease expense	3,851		—		—
Amortization of acquired wholesale energy contracts	4,924		8,424		18,222
Allowance for equity used during construction	(17,053)		(6,492)		(5,531)
Allowance for doubtful accounts	2,238		2,387		2,579
Deferred income taxes	34,346		(2,822)		27,143
Deferred income tax benefit due to tax legislation	—		—		(75,736)
Equivalent value of ITCs recognized on equipment financing	(6,482)		(6,482)		—
Manufactured gas plant remediation costs	(7,651)		(13,878)		(16,171)
Equity in earnings, net of distributions received from equity investees	(5,848)		(4,156)		(1,725)
Cost of removal - asset retirement obligations	(245)		(258)		(298)
Contributions to postemployment benefit plans	(9,032)		(8,157)		(6,359)
Tax benefit of delivered shares from stock based compensation	647		1,290		2,950
Changes in:
Components of working capital	(8,096)		(27,759)		97,004
Other noncurrent assets	(44,129)		8,193		17,860
Other noncurrent liabilities	5,280		38,125		13,989
Cash flows from operating activities	213,481		194,128		398,286
CASH FLOWS USED IN INVESTING ACTIVITIES
Expenditures for:
Utility plant	(290,040)		(304,809)		(206,880)
Solar and wind equipment	(133,841)		(157,828)		(123,421)
Storage and transportation assets and other	(24,228)		(23,100)		(6,644)
Cost of removal	(22,059)		(40,195)		(47,643)
Investments in equity investees	(2,117)		(4,102)		(16,151)
Distributions from equity investees in excess of equity in earnings	1,907		2,428		3,117
Acquisition of assets, net of cash acquired of $5.1 million	(523,647)		—		(10,000)
Proceeds from sale of businesses, net of closing costs	—		205,745		27,916
Proceeds from sale of available for sale securities, net	—		34,484		6,616
Cash flows used in investing activities	(994,025)		(287,377)		(373,090)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Proceeds from long-term debt	660,000		467,900		225,000
Payments of long-term debt	(20,286)		(218,638)		(165,486)
Proceeds from term loan	350,000		—		—
Payments of term loan	(350,000)		—		—
Proceeds from (payments of)short-term debt, net	99,900		(126,500)		(114,050)
Proceeds from sale leaseback transaction - solar	42,927		—		71,538
Proceeds from sale leaseback transaction - natural gas meters	4,000		9,895		7,820
Payments of common stock dividends	(117,804)		(104,059)		(95,835)
Proceeds from waiver discount issuance of common stock	—		57,391		41,677
Proceeds from issuance of common stock	18,080		16,717		17,136
Proceeds from equity offering	212,900		—		—
Tax withholding payments related to net settled stock compensation	(3,813)		(7,104)		(13,755)
Cash flows from (used in) financing activities	895,904		95,602		(25,955)
Change in cash, cash equivalents and restricted cash	115,360		2,353		(759)
Cash, cash equivalents and restricted cash at beginning of period	4,063		1,710		2,469
Cash, cash equivalents and restricted cash at end of period	$	119,423	$	4,063	$	1,710
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	5,065	$	63,795	$	(7,524)
Inventories	(3,254)		14,265		15,464
Recovery of natural gas costs	17,479		(15,733)		30,439
Natural gas purchases payable	(41,326)		(74,031)		51,187
Natural gas purchases payable - related parties	1		(360)		(1)
Prepaid expenses	2,548		(1,193)		2,037
Prepaid and accrued taxes	(2,376)		2,271		1,254
Accounts payable and other	20,390		2,256		40,422
Restricted broker margin accounts	(6,097)		(22,004)		(30,974)
Customers’ credit balances and deposits	(1,182)		(209)		368
Other current assets	656		3,184		(5,668)
Total	$	(8,096)	$	(27,759)	$	97,004
SUPPLEMENTAL DISCLOSURES
Cash paid (received) for:
Interest (net of amounts capitalized)	$	66,146	$	50,371	$	44,821
Income taxes	$	7,594	$	12,647	$	5,577
Accrued capital expenditures	$	19,434	$	30,725	$	30,559
Inception gain on natural gas swap contract recognized as non-cash proceeds from sale of business	$	—	$	—	$	14,579
See Notes to Consolidated Financial Statements

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

CONSOLIDATED BALANCE SHEETS

ASSETS

(Thousands)
September 30,	2020		2019
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	2,800,052	$	2,625,730
Construction work in progress	379,846		237,011
Nonutility plant and equipment, at cost	1,108,512		576,174
Construction work in progress	176,556		62,492
Total property, plant and equipment	4,464,966		3,501,407
Accumulated depreciation and amortization, utility plant	(601,635)		(585,160)
Accumulated depreciation and amortization, nonutility plant and equipment	(140,562)		(106,614)
Property, plant and equipment, net	3,722,769		2,809,633
CURRENT ASSETS
Cash and cash equivalents	117,012		2,676
Customer accounts receivable:
Billed	134,173		139,263
Unbilled revenues	9,226		6,510
Allowance for doubtful accounts	(7,242)		(6,148)
Regulatory assets	36,530		32,871
Natural gas in storage, at average cost	167,504		169,803
Materials and supplies, at average cost	20,406		14,475
Prepaid expenses	6,639		8,333
Prepaid and accrued taxes	24,301		22,602
Derivatives, at fair value	23,310		25,103
Restricted broker margin accounts	69,444		73,723
Other current assets	21,029		22,395
Total current assets	622,332		511,606
NONCURRENT ASSETS
Investments in equity investees	208,375		200,268
Regulatory assets	527,459		496,637
Operating lease assets	131,769		—
Derivatives, at fair value	3,349		7,426
Intangible assets	10,060		14,611
Software costs	4,707		1,702
Other noncurrent assets	85,657		116,059
Total noncurrent assets	971,376		836,703
Total assets	$	5,316,477	$	4,157,942

See Notes to Consolidated Financial Statements

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

CAPITALIZATION AND LIABILITIES

(Thousands, except share data)
September 30,	2020		2019
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding September 30, 2020 — 95,949,183; September 30, 2019 — 89,998,788	$	240,243	$	226,649
Premium on common stock	491,982		291,331
Accumulated other comprehensive loss, net of tax	(44,315)		(31,787)
Treasury stock at cost and other; shares September 30, 2020 — 148,310; September 30, 2019 — 660,734	8,485		(10,436)
Retained earnings	947,501		906,076
Common stock equity	1,643,896		1,381,833
Long-term debt	2,259,466		1,537,177
Total capitalization	3,903,362		2,919,010
CURRENT LIABILITIES
Current maturities of long-term debt	27,236		21,419
Short-term debt	125,350		25,450
Natural gas purchases payable	95,945		137,271
Natural gas purchases payable to related parties	791		790
Accounts payable and other	141,500		129,724
Dividends payable	31,902		28,122
Accrued taxes	2,717		3,394
Regulatory liabilities	26,188		—
New Jersey Clean Energy Program	15,570		15,468
Derivatives, at fair value	33,865		57,623
Operating lease liabilities	6,724		—
Customers’ credit balances and deposits	25,934		27,116
Total current liabilities	533,722		446,377
NONCURRENT LIABILITIES
Deferred income taxes	138,081		145,504
Deferred investment tax credits	3,332		3,653
Deferred gain	1,035		1,554
Derivatives, at fair value	13,352		18,821
Manufactured gas plant remediation	150,590		131,080
Postemployment employee benefit liability	237,221		246,517
Regulatory liabilities	196,450		202,435
Operating lease liabilities	95,030		—
Asset retirement obligation	33,723		31,046
Other noncurrent liabilities	10,579		11,945
Total noncurrent liabilities	879,393		792,555
Commitments and contingent liabilities (Note 15)
Total capitalization and liabilities	$	5,316,477	$	4,157,942

See Notes to Consolidated Financial Statements

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY

(Thousands)	Number of Shares	Common Stock		Premium on Common Stock		Accumulated Other Comprehensive (Loss) Income			Treasury Stock And Other		Retained Earnings		Total
Balance at September 30, 2017	86,556	$	222,258	$	219,696		$	(3,256)	$	(70,039)	$	746,093	$	1,114,752
Net income	—	—		—			—		—		231,013		231,013
Other comprehensive loss	—	—		—			(6,078)		—		—		(6,078)
Common stock issued:
Incentive compensation plan	561	1,403		15,169			—		—		—		16,572
Dividend reinvestment plan (1)	413	—		755			—		16,339		—		17,094
Waiver discount	1,014	2,535		39,142			—		—		—		41,677
Cash dividend declared ($1.11 per share)	—	—		—			—		—		(97,579)		(97,579)
Treasury stock and other	(251)	—		(14)			—		(22,773)		—		(22,787)
Reclassifications of certain income tax effects to retained earnings	—	—		—			(3,276)		—		3,276		—
Balance at September 30, 2018	88,293	226,196		274,748			(12,610)		(76,473)		882,803		1,294,664
Net income	—	—		—			—		—		123,935		123,935
Other comprehensive loss	—	—		—			(15,731)		—		—		(15,731)
Common stock issued:
Incentive compensation plan	182	453		3,334			—		—		—		3,787
Dividend reinvestment plan (1)	351	—		2,718			—		13,945		—		16,663
Waiver discount	1,181	—		10,531			—		46,860		—		57,391
Cash dividend declared ($1.19 per share)	—	—		—			—		—		(106,342)		(106,342)
Treasury stock and other	(8)	—		—			—		5,232		—		5,232
Adoption of ASU 2016-01 (2)	—	—		—			(3,446)		—		3,446		—
Adoption of ASU 2017-05 (2)	—	—		—			—		—		4,970		4,970
Adoption of ASU 2014-09/ASC 606 (2)	—	—		—			—		—		(2,736)		(2,736)
Balance at September 30, 2019	89,999	226,649		291,331			(31,787)		(10,436)		906,076		1,381,833
Net income	—	—		—			—		—		163,007		163,007
Other comprehensive loss	—	—		—			(12,528)		—		—		(12,528)
Common stock issued:
Common stock offering	5,333	13,333		199,567			—		—		—		212,900
Incentive compensation plan	105	261		3,511			—		—		—		3,772
Dividend reinvestment plan (1)	520	—		2,833			—		15,324		—		18,157
Cash dividend declared ($1.27 per share)	—	—		—			—		—		(121,582)		(121,582)
Treasury stock and other	(8)	—		(5,260)			—		3,597		—		(1,663)
Balance at September 30, 2020	95,949	$	240,243	$	491,982		$	(44,315)	$	8,485	$	947,501	$	1,643,896

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

(2)See Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the Accounting Standards Codification section for more details.

See Notes to Consolidated Financial Statements

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Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

1. NATURE OF THE BUSINESS

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

New Jersey Natural Gas Company provides natural gas utility service to approximately 558,000 retail customers throughout Monmouth, Ocean, Morris, Middlesex and Burlington counties in New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment.

NJR Clean Energy Ventures Corporation, the Company's clean energy subsidiary, comprises the Clean Energy Ventures segment and consists of the Company's capital investments in commercial and residential solar projects.

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

NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, formerly the Midstream segment, invests in energy-related ventures through its subsidiaries. The Company holds a 50 percent ownership interest in Steckman Ridge, located in Pennsylvania and 20 percent ownership interest in PennEast, which are accounted for under the equity method of accounting. The Company also operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River, which was acquired on October 11, 2019 and FERC regulated Adelphia Gateway, which was acquired on January 13, 2020. See Note 19. Acquisitions and Dispositions for more information regarding these acquisitions.

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

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The Consolidated Financial Statements include the accounts of the Company and its wholly-owned subsidiaries. All intercompany accounts and transactions have been eliminated.

Other financial investments or contractual interests that lack the characteristics of a voting interest entity, which are commonly referred to as variable interest entities, are evaluated by the Company to determine if the entity has the power to direct business activities and, therefore, would be considered a controlling interest that the Company would have to consolidate. Based on those evaluations, NJR has determined that it does not have any investments in variable interest entities as of September 30, 2020, 2019 and 2018.

Investments in entities over which the Company does not have a controlling financial interest are either accounted for under the equity method or cost method of accounting.

Use of Estimates

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

The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, a reserve is established if a loss is probable and can be reasonably estimated. 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, a reserve is established at 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.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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 Consolidated Financial Statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the balance sheet date and reported amounts of revenue and expenses during the reporting periods presented. The Company considered the impacts of COVID-19 on the assumptions and estimates used and determined that there have been no material adverse impacts on the Company’s results of operations as of September 30, 2020.

Acquisitions

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

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

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various assumptions and valuation methodologies requiring considerable management judgment. The most significant variables in these valuations are discount rates and the number of years on which to base the cash flow projections, as well as other assumptions and estimates used to determine the cash inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets and related cash flows. The valuation of an acquired business is based on available information at the acquisition date and assumptions that are believed to be reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date. See Note 19. Acquisitions and Dispositions for further information.

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

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

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

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Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Our 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.

Natural Gas Purchases

NJNG’s tariff includes a component for BGSS, which is designed to allow it to recover the cost of natural gas through rates charged to its customers and is typically revised on an annual basis. As part of computing its BGSS rate, NJNG projects its cost of natural gas, net of supplier refunds, the impact of hedging activities and cost savings created by BGSS incentive programs. NJNG subsequently recovers or credits the difference, if any, of actual costs compared with those included in current rates. Any underrecoveries or overrecoveries are either credited to customers or deferred and, subject to BPU approval, reflected in the BGSS rates in subsequent years.

Natural gas purchases at Energy Services are composed of natural gas costs to be paid upon completion of a variety of transactions, as well as realized gains and losses from settled derivative instruments and unrealized gains and losses on the change in fair value of derivative instruments that have not yet settled. Changes in the fair value of derivatives that economically hedge the forecasted purchases of natural gas are recognized in natural gas purchases as they occur.

Demand Fees

For the purpose of securing storage and pipeline capacity in support of their respective businesses, the Energy Services and Natural Gas Distribution segments enter into storage and pipeline capacity contracts, which require the payment of associated demand fees and charges that allow them access to a high priority of service in order to maintain the ability to access storage or pipeline capacity during a fixed time period, which generally ranges from one to 10 years. Many of these demand fees and charges are based on established tariff rates as established and regulated by FERC. These charges represent commitments to pay storage providers and pipeline companies for the priority right to transport and/or store natural gas utilizing their respective assets.

The following table summarizes the demand charges, which are net of capacity releases, and are included as a component of natural gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30:

(Millions)	2020		2019		2018
Energy Services	$	121.8	$	120.4	$	153.0
Natural Gas Distribution	131.9		119.1		92.5
Total	$	253.7	$	239.5	$	245.5

Energy Services expenses demand charges over the term of the service being provided.

The Natural Gas Distribution segment’s costs associated with demand charges are included in its weighted average cost of natural gas. The demand charges are expensed based on NJNG’s BGSS sales and recovered as part of its natural gas commodity component of its BGSS tariff.

Operations and Maintenance Expenses

Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of vehicles, tools and equipment, payments to contractors, utility plant maintenance, amortization of software costs for unregulated entities, customer service, professional fees and other outside services, insurance expense, accretion of cost of removal for future retirements of utility assets and other administrative expenses and are expensed as incurred.

Stock-Based Compensation

Stock-based compensation represents costs related to stock-based awards granted to employees and members of NJR’s Board of Directors. NJR recognizes stock-based compensation based upon the estimated fair value of awards. The recognition period for these costs begins at either the applicable service inception date or grant date and continues throughout the requisite service period. The related compensation cost is recognized as O&M expense on the Consolidated Statements of Operations. See Note 10. Stock-Based Compensation for further information.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Sales Tax Accounting

As a result of the adoption of ASC 606, Revenue from Contracts with Customers, as of October 1, 2018, the Company excludes from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales tax on a net basis in operating revenues on the Consolidated Statements of Operations. Prior to October 1, 2018, sales tax was presented in both operating revenues and operating expenses.

Income Taxes

The Company computes income taxes using the asset and liability method, whereby deferred income taxes are generally determined based on the difference between the financial statement and tax basis of assets and liabilities using enacted tax rates in effect in the years in which the differences are expected to reverse. See Note 13. Income Taxes. In addition, the Company evaluates its tax positions to determine the appropriate accounting and recognition of future obligations associated with unrecognized tax benefits.

The Company invests in property that qualifies for federal ITCs and utilizes the ITCs, as allowed, based on the cost and life of the assets. ITCs at NJNG are deferred and amortized as a reduction to the tax provision over the average lives of the related equipment in accordance with regulatory treatment. ITCs at the unregulated subsidiaries of NJR are recognized as a reduction to the carrying value of the related asset when placed in service. ITCs are recognized in earnings as a reduction to depreciation expense over the productive life of the related property.

Projects placed in service through December 31, 2019, qualified for a 30-percent federal ITC. The credit declines to 26 percent for property under construction during 2020, 22 percent for property under construction during 2021 and 10 percent for any property that is under construction before 2022. The Company has taken steps to preserve the ITC at the higher rate for certain solar projects that are completed after the scheduled reduction in rates, in accordance with IRS guidance on safe harbor determination.

Investments in Equity Investees

The Company accounts for its investments in Steckman Ridge and PennEast using the equity method of accounting where it is not the primary beneficiary, as defined under ASC 810, Consolidation, its respective ownership interests are 50 percent or less and/or it has significant influence over operating and management decisions. The Company’s share of earnings is recognized as equity in earnings of affiliates on the Consolidated Statements of Operations.

Equity method investments are reviewed for impairment when changes in facts and circumstances indicate that the current fair value may be less than the asset’s carrying amount. If the Company determines the decline in the value of its equity method investment is other than temporary, an impairment charge is recorded in an amount equal to the excess of the carrying value of the asset over its fair value.

Property Plant and Equipment

Property, plant and equipment is stated at original cost. Costs include direct labor, materials and third-party construction contractor costs, capitalized interest and certain indirect costs related to equipment and employees engaged in construction. Utility plant and nonutility plant for Adelphia Gateway also includes AFUDC. Upon retirement, the cost of depreciable property, plus removal costs less salvage, is charged to accumulated depreciation with no gain or loss recorded.

Depreciation is computed on a straight-line basis over the useful life of the assets for our nonutility entities, and using rates based on the estimated average lives of the various classes of depreciable property for NJNG. The composite rate of depreciation used for NJNG was 2.65 percent of average depreciable property in fiscal 2020, 2.25 percent in fiscal 2019 and 2.29 percent in fiscal 2018. The Company recorded $107.4 million, $81.1 million and $76.6 million in depreciation expense during fiscal 2020, 2019 and 2018, respectively.

During fiscal 2018 and 2019, the estimated useful lives of commercial solar assets ranged from 15 to 25 years. During the fourth quarter of fiscal 2020, the Company reassessed the estimated useful lives of its commercial solar asset fleet. Based upon this review, the Company concluded that the actual lives of certain commercial solar assets were longer than the estimated useful lives used for depreciation purposes. As a result, effective July 1, 2020, the Company changed its estimates of the useful lives of its solar assets to a range of 15 to 35 years. The effects of this change were considered immaterial to the Consolidated Financial Statements.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Property, plant and equipment was comprised of the following as of September 30:

(Thousands)	Estimated
Property Classifications	Estimated Useful Lives	2020		2019
Distribution facilities	38 to 74 years	$	2,688,885	$	2,419,381
Transmission facilities	35 to 56 years	332,947		330,912
Storage facilities	34 to 47 years	79,922		79,916
Solar property	15 to 35 years	674,930		593,867
Storage and transportation property	5 to 50 years	428,491		28,445
All other property	5 to 35 years	259,791		48,886
Total property, plant and equipment		4,464,966		3,501,407
Accumulated depreciation and amortization		(742,197)		(691,774)
Property, plant and equipment, net		$	3,722,769	$	2,809,633

Within storage and transportation property, base gas is required to maintain the necessary pressure and to allow for efficient operation of the Leaf River storage facility. The base gas is determined to be recoverable and is considered part of the facility and thus presented as a component in property, plant and equipment. This natural gas is not depreciated, as it is expected to be recovered and sold. As of September 30, 2020, the base gas had a cost basis of $5.7 million.

Capitalized and Deferred Interest

NJNG’s base rates include the ability to recover AFUDC on its construction work in progress. For all NJNG construction projects, an incremental cost of equity is recoverable during periods when NJNG’s short-term debt balances are lower than its construction work in progress. For more information on AFUDC treatment with respect to certain accelerated infrastructure projects, see Note 4. Regulation - Infrastructure Programs.

Capitalized amounts associated with the debt and equity components of NJNG’s AFUDC are recorded in utility plant on the Consolidated Balance Sheets. Corresponding amounts for the debt component are recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations.

Adelphia Gateway’s base rates include the ability to recover AFUDC on its construction work in progress. Beginning in the fourth quarter of fiscal 2020, capitalized amounts associated with Adelphia Gateway’s AFUDC are recorded in nonutility plant on the Consolidated Balance Sheets. Corresponding amounts are recorded in other income on the Consolidated Statements of Operations.

Capitalized and deferred interest include the following for the fiscal years ended September 30:

($ in thousands)	2020						2019			2018
	NJNG			Adelphia Gateway			NJNG			NJNG
AFUDC:
Debt	$	5,134		$	1,394		$	3,710		$	1,979
Equity	14,599			2,454			6,492			5,531
Total	$	19,733		$	3,848		$	10,202		$	7,510
Weighted average interest rate	6.79		%	8.28		%	6.35		%	5.94		%

Pursuant to a BPU order, NJNG is permitted to recover carrying costs on uncollected balances related to SBC program costs, which include NJCEP, RAC and USF expenditures. The SBC interest rate changes each September based on the August 31 seven-year constant maturity treasury rate plus 60 basis points. The rate was 1.97 percent, 3.30 percent and 3.41 percent for the fiscal years ended September 30, 2020, 2019 and 2018, respectively. Accordingly, other income included $511,000, $760,000 and $411,000 in the fiscal years ended September 30, 2020, 2019 and 2018, respectively.

Clean Energy Ventures capitalizes interest on the allocation of the costs of debt borrowed for the financing of solar investments. Capitalized amounts are included in nonutility plant and equipment on the Consolidated Balance Sheets.

Cash and Cash Equivalents

Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to escrow balances for utility plant projects, which is recorded in other noncurrent assets on the Consolidated Balance Sheets.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, required that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement. The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Consolidated Balance Sheets to the total amounts in the Statements of Cash Flows, as of September 30:

(Thousands)	2020		2019		2018
Balance Sheet
Cash and cash equivalents	$	117,012	$	2,676	$	1,458
Restricted cash in other noncurrent assets	$	2,411	$	1,387	$	252
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	119,423	$	4,063	$	1,710

Loans Receivable

NJNG currently provides loans, with terms ranging from 2 to 10 years, to customers that elect to purchase and install certain energy-efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at fair value on the Consolidated Balance Sheets. The Company recorded $13.7 million and $12.4 million in other current assets and $35.3 million and $38.8 million in other noncurrent assets as of September 30, 2020 and 2019, respectively, on the Consolidated Balance Sheets, related to the loans. If NJNG determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of September 30, 2020 and 2019, the Company has not recorded any impairments for SAVEGREEN loans.

Regulatory Assets & Liabilities

Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment.

Our Natural Gas Distribution segment maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and in accordance with the ASC 980, Regulated Operations. As a result of the impact of the ratemaking process and regulatory actions of the BPU, NJNG is required to recognize the economic effects of rate regulation. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of NJNG’s regulatory assets and liabilities.

In January 2020, NJR acquired Adelphia Gateway an existing 84-mile pipeline in southeastern Pennsylvania, which maintains its accounts in accordance with the FERC Uniform System of Accounts and in accordance with the ASC 980, Regulated Operations. Accordingly, Adelphia Gateway capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of Adelphia Gateway’s regulatory assets and liabilities.

Natural Gas in Storage

Natural gas in storage is reflected at average cost on the Consolidated Balance Sheets and represents natural gas and LNG that will be utilized in the ordinary course of business. The following table summarizes natural gas in storage, at average cost by company, as of September 30:

	2020				2019
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	110,037	27.2		$	117,413	27.0
Energy Services		57,352		34.3		52,390		25.6
Storage and Transportation		115		0.02		—		—
Total		$	167,504	61.52		$	169,803	52.6

Derivative Instruments

The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts and interest rate contracts, as well as its physical commodity contracts related to the purchase and sale of natural gas at Energy Services, as derivatives, and therefore recognizes them at fair value on the Consolidated Balance Sheets. The Company’s unregulated subsidiaries record changes in the fair value of their financial commodity derivatives in natural gas purchases and changes in

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

the fair value of their physical forward contracts in natural gas purchases or operating revenues, as appropriate, on the Consolidated Statements of Operations. Ineffective portions of the cash flow hedges are recognized immediately in earnings.

The ASC 815, Derivatives and Hedging also provides for a NPNS scope exception for qualifying physical commodity contracts for which physical delivery is probable and the quantities delivered are expected to be used or sold over a reasonable period of time in the normal course of business. Effective January 1, 2016, the Company prospectively applies this normal scope exception on a case-by-case basis to physical commodity contracts at NJNG and PPAs at Clean Energy Ventures. When applied, it does not account for these contracts until the contract settles and the related underlying natural gas or power is delivered. Gains and/or losses on NJNG’s derivatives used to economically hedge its regulated natural gas supply obligations, as well as its exposure to interest rate variability, are recoverable through its BGSS, a component of its tariff. Accordingly, the offset to the change in fair value of these derivatives is recorded as a regulatory asset or liability on the Consolidated Balance Sheets. See Note 5. Derivative Instruments for additional details regarding natural gas trading and hedging activities.

Fair values of exchange-traded instruments, including futures and swaps, are based on unadjusted, quoted prices in active markets. The Company’s non-exchange-traded financial instruments, foreign currency derivatives, over-the-counter physical commodity contracts at Energy Services and interest rate contracts are valued using observable, quoted prices for similar or identical assets when available. In establishing the fair value of contracts for which a quoted basis price is not available at the measurement date, management utilizes available market data and pricing models to estimate fair values. Fair values are subject to change in the near term and reflect management’s best estimate based on a variety of factors. Estimating fair values of instruments that do not have quoted market prices requires management’s judgment in determining amounts that could reasonably be expected to be received from, or paid to, a third party in settlement of the instruments. These amounts could be materially different from amounts that might be realized in an actual sale transaction.

During fiscal 2020, the Company entered into treasury lock transactions to fix the benchmark treasury rate associated with debt issuances for NJNG and NJR that occurred during the fiscal year. Settlement of the NJNG treasury locks resulted in a loss, which was recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the debt as a component of interest expense on the Consolidated Statements of Operations. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks resulted in a loss, which was recorded within OCI and will be amortized in earnings over the life of the debt as a component of interest expense on the Consolidated Statements of Operations. Amounts recognized in interest expense for NJNG and NJR related to the amortization of the loss on treasury lock transactions totaled $50,000 and $108,000, respectively, as of September 30, 2020.

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 of the respective software.

The following table presents the software costs included in the Consolidated Financial Statements, as of September 30:

(Thousands)	2020		2019
Balance Sheets
Utility plant, at cost	$	13,452	$	—
Construction work in progress	$	—	$	4,778
Nonutility plant and equipment, at cost	$	316	$	—
Accumulated depreciation and amortization, utility plant	$	(279)	$	—
Accumulated depreciation and amortization, nonutility plant and equipment	$	(5)	$	—
Software costs	$	4,707	$	1,702
Statements of Operations
Operation and maintenance (1)	$	6,720	$	9,062
Depreciation and amortization	$	284	$	—

(1)During fiscal 2020, $63,000 was amortized into O&M.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Investments in Equity Securities

Investments in equity securities were carried at fair value on the Consolidated Balance Sheets. For the fiscal year ended September 30, 2018, total unrealized gains and losses associated with equity securities were included as a part of accumulated other comprehensive income, a component of common stock equity, and reclassifications of realized gains or losses out of other comprehensive income into earnings were recorded in other income, net on the Consolidated Statements of Operations, based on average cost. On October 1, 2018, the Company adopted ASU No. 2016-01, an amendment to ASC 825, Financial Instruments. As a result, both realized and unrealized gains and losses were recorded in other income, net on the Consolidated Statements of Operations, based on average cost.

At September 30, 2018, the Company's investments in equity securities were comprised of an investment in DM Common Units, which had a fair value of $32.9 million. On January 28, 2019, Dominion and DM finalized an agreement and plan of merger and each outstanding DM Common Unit was converted into 0.2492 shares of Dominion common stock. This resulted in the conversion of the Company's 1.84 million DM Common Units into approximately 458,000 Dominion common shares. On March 6, 2019, the Company sold its investment in Dominion and received proceeds of approximately $34.5 million. As a result of the sale, the Company recorded total realized gains of $1.6 million in other income, net on the Consolidated Statements of Operations.

Intangible Assets

Finite-lived intangible assets are stated at cost less accumulated amortization. The Company amortizes intangible assets based upon the pattern in which the economic benefits are consumed over the life of the asset unless a pattern cannot be reliably determined, in which case the Company uses a straight-line amortization method. As of September 30, 2020, intangible assets consist primarily of acquired wholesale natural gas energy contracts totaling $10 million. The wholesale natural gas contracts are being amortized based upon expected cash flows over the respective terms of the agreements.

The estimated future amortization expense as of September 30, is as follows:

(Thousands)
2021	$	5,101
2022	$	2,611
2023	$	2,271
2024	$	77

Long-lived Assets

The Company reviews the recoverability of long-lived assets and finite-lived intangible assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable, such as significant adverse changes in regulation, business climate or market conditions, including prolonged periods of adverse commodity and capacity prices. If there are changes indicating that the carrying value of such assets may not be recoverable, an undiscounted cash flows test is performed. If the sum of the expected future undiscounted cash flows is less than the carrying amount of the asset, an impairment loss is recognized by reducing the recorded value of the asset to its fair value. Factors that the Company analyzes in determining whether an impairment in its long-lived assets exists include: a significant decrease in the market price of a long-lived asset; a significant adverse change in the extent in which a long-lived asset is being used in its physical condition; legal proceedings or other contributing factors; significant business climate changes; accumulations of costs in significant excess of the amounts expected; a current-period operating or cash flow loss combined with a history of such events; and current expectations that more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its estimated useful life. During fiscal 2020 and 2019, there were no events or circumstances that indicated that the carrying value of long-lived assets or finite-lived intangibles were not recoverable.

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt. See Note 9. Debt for the total unamortized debt issuance costs that are recorded as a reduction to long-term debt on the Consolidated Balance Sheets.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Sale Leasebacks

NJNG utilizes sale leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease or repurchase the asset at the end of the term. Proceeds from sale leaseback transactions are accounted for as financing arrangements and are included in long-term debt on the Consolidated Balance Sheets. During fiscal 2020 and 2019, NJNG received $4 million and $9.9 million, respectively, in connection with the sale leaseback of its natural gas meters with terms ranging from seven to 11 years.

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

During fiscal 2020 and 2018, Clean Energy Ventures received proceeds of $42.9 million and $71.5 million, respectively, in connection with the failed sale leaseback of commercial solar assets. The proceeds received were recognized as a financing obligation on the Consolidated Balance Sheets. Clean Energy Ventures did not enter into any sale leaseback transactions for its commercial solar assets during fiscal 2019. Clean Energy Ventures simultaneously entered into agreements to lease the assets back over a term of five- to 15-years. The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from SRECs 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 Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease.

Environmental Contingencies 

Loss contingencies are recorded as liabilities when it is probable a liability has been incurred and the amount of the loss is reasonably estimable in accordance with accounting standards for contingencies. Estimating probable losses requires an analysis of uncertainties that often depend upon judgments about potential actions by third parties. Accruals for loss contingencies are recorded based on an analysis of potential results.

With respect to environmental liabilities and related costs, NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG’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. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries. NJNG will continue to seek recovery of MGP-related costs through the 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. See Note 15. Commitments and Contingent Liabilities for more details.

Pension and Postemployment Plans

The Company has two noncontributory defined pension plans covering eligible employees, including officers. Benefits are based on each employee’s years of service and compensation. The Company’s funding policy is to contribute annually to these plans at least the minimum amount required under the Employee Retirement Income Security Act, as amended, and not more than can be deducted for federal income tax purposes. Plan assets consist of equity securities, fixed-income securities and short-term investments. The Company did not make any discretionary contributions to the pension plans in fiscal 2020, 2019 and 2018, respectively.

The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds. The Company contributed $8.4 million, $7.9 million and $6.2 million in aggregate to these plans in

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

fiscal 2020, 2019 and 2018, respectively, which is recorded in postemployment employee benefit liability on the Consolidated Balance Sheets. See Note 11. Employee Benefit Plans, for a more detailed description of the Company’s pension and postemployment plans.

Asset Retirement Obligations

The Company recognizes ARO related to the costs associated with cutting and capping NJNG’s main and service natural gas distribution mains, which is required by New Jersey law when taking such natural gas distribution mains out of service. The Company also recognizes ARO associated with Clean Energy Ventures’ solar assets when there are decommissioning provisions in lease agreements that require removal of the asset at the end of the lease term.

ARO are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations. Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets.

Estimating future removal costs requires management to make significant judgments because most of the removal obligations span long time frames and removal may be conditioned upon future events. Asset removal technologies are also constantly changing, which makes it difficult to estimate removal costs. Accordingly, inherent in the estimate of ARO are various assumptions including the ultimate settlement date, expected cash outflows, inflation rates, credit-adjusted risk-free rates and consideration of potential outcomes where settlement of the ARO can be conditioned upon events. In the latter case, the Company develops possible retirement scenarios and assigns probabilities based on management’s reasonable judgment and knowledge of industry practice. Accordingly, ARO are subject to change.

Accumulated Other Comprehensive Income

The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects, as of September 30:

(Thousands)	Investments in Equity Securities		Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2018	$	3,446	$	—	$	(16,056)		$	(12,610)
Other comprehensive income, net of tax
Other comprehensive (loss), before reclassifications, net of tax of $0, $0, $6,557 and $6,557, respectively	—		—		(16,978)			(16,978)
Amounts reclassified from accumulated other comprehensive (loss), net of tax of $0, $0, $(451) and $(451), respectively	—		—		1,247		(1)	1,247
Net current-period other comprehensive income, net of tax of $0, $0, $6,106 and $6,106, respectively	—		—		(15,731)			(15,731)
Reclassifications of certain income tax effects to retained earnings (2)	(3,446)		—		—			(3,446)
Balance at September 30, 2019	$	—	$	—	$	(31,787)		$	(31,787)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $0, $3,203, $1,235, $4,438, respectively	—		(10,505)		(4,882)			(15,387)
Amounts reclassified from accumulated other comprehensive loss, net of tax of $0, $(32), $(668), $(700), respectively	—		108		2,751		(1)	2,859
Net current-period other comprehensive income, net of tax of $0, $3,171, $567, $3,738, respectively	—		(10,397)		(2,131)			(12,528)
Balance at September 30, 2020	$	—	$	(10,397)	$	(33,918)		$	(44,315)

(1)Included in the computation of net periodic pension cost, a component of O&M expense on the Consolidated Statements of Operations. For more details, see Note 11. Employee Benefit Plans.

(2)Due to the adoption of ASU No. 2016-01, an amendment to ASC 825, Financial Instruments. See Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the Accounting Standards Codification section for more details.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Foreign Currency Transactions

The market area of Energy Services includes Canadian delivery points and as a result, Energy Services incurs certain natural gas commodity costs and demand fees denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of natural gas purchases on the Consolidated Statements of Operations. Gains and losses recognized for the fiscal years ended September 30, 2020, 2019 and 2018, are considered immaterial.

Reclassification

Certain prior period amounts have been reclassified to conform to the current period presentation. Amounts related to energy and other taxes have been reclassified to O&M on the Consolidated Statements of Operations. Software costs previously recorded in other non-current assets have been reclassified to utility plant and software costs, and prepaid expenses previously recorded in other current assets have been reclassified on the Consolidated Balance Sheets. Certain amounts related to software costs previously reported in cash flows from operating activities have been reclassified to cash flows used in investing activities and prepaid expenses were reclassified within working capital on the Consolidated Statements of Cash Flows.

Change in Accounting Policy

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

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

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the fiscal years ended September 30, 2020, 2019 and 2018 are as follows:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Depreciation and amortization	$	119,894	(12,526)	$	107,368
Total operating expenses	$	1,737,285	(12,526)	$	1,724,759
Operating income	$	216,383	12,526	$	228,909
Income before income taxes and equity in earnings of affiliates	$	172,664	12,526	$	185,190
Income tax (benefit) expense	$	(6,944)	43,438	$	36,494
Net income	$	193,919	(30,912)	$	163,007
Weighted average shares outstanding
Diluted	95,107		(4)	95,103
Earnings per common share
Basic	$	2.05	(0.33)	$	1.72
Diluted	$	2.04	(0.33)	$	1.71
September 30, 2019
Depreciation and amortization	$	91,730	(10,621)	$	81,109
Total operating expenses	$	2,438,110	(10,621)	$	2,427,489
Operating income	$	153,935	10,621	$	164,556
Income before income taxes and equity in earnings of affiliates	$	118,126	10,621	$	128,747
Income tax (benefit) expense	$	(37,751)	56,191	$	18,440
Net income	$	169,505	(45,570)	$	123,935
Weighted average shares outstanding
Diluted	89,616		(20)	89,596
Earnings per common share
Basic	$	1.90	(0.51)	$	1.39
Diluted	$	1.89	(0.51)	$	1.38
September 30, 2018
Depreciation and amortization	$	85,701	(9,130)	$	76,571
Total operating expenses	$	2,715,227	(9,130)	$	2,706,097
Operating income	$	199,882	9,130	$	209,012
Income before income taxes and equity in earnings of affiliates	$	166,643	9,130	$	175,773
Income tax benefit	$	(53,785)	11,553	$	(42,232)
Net income	$	233,436	(2,423)	$	231,013
Earnings per common share
Basic	$	2.66	(0.03)	$	2.63
Diluted	$	2.64	(0.02)	$	2.62

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The cumulative effect of the change in accounting policy on the Unaudited Condensed Consolidated Balance Sheets as of September 30, 2020 and 2019 are as follows:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Assets
Nonutility plant and equipment, at cost	$	1,430,723	(322,211)	$	1,108,512
Accumulated depreciation and amortization, nonutility plant and equipment	$	(202,507)	61,945	$	(140,562)
Property, plant and equipment, net	$	3,983,035	(260,266)	$	3,722,769
Other noncurrent assets	$	78,716	6,941	$	85,657
Total noncurrent assets	$	964,435	6,941	$	971,376
Total assets	$	5,569,802	(253,325)	$	5,316,477
Capitalization
Retained earnings	$	1,148,297	(200,796)	$	947,501
Common stock equity	$	1,844,692	(200,796)	$	1,643,896
Total capitalization	$	4,104,158	(200,796)	$	3,903,362
Liabilities
Deferred income taxes	$	190,610	(52,529)	$	138,081
Total noncurrent liabilities	$	931,922	(52,529)	$	879,393
Total capitalization and liabilities	$	5,569,802	(253,325)	$	5,316,477
September 30, 2019
Assets
Nonutility plant and equipment, at cost	$	861,904	(285,730)	$	576,174
Accumulated depreciation and amortization, nonutility plant and equipment	$	(156,033)	49,419	$	(106,614)
Property, plant and equipment, net	$	3,045,944	(236,311)	$	2,809,633
Other noncurrent assets	$	94,791	21,268	$	116,059
Total noncurrent assets	$	815,435	21,268	$	836,703
Total assets	$	4,372,985	(215,043)	$	4,157,942
Capitalization
Retained earnings	$	1,075,960	(169,884)	$	906,076
Common stock equity	$	1,551,717	(169,884)	$	1,381,833
Total capitalization	$	3,088,894	(169,884)	$	2,919,010
Liabilities
Deferred income taxes	$	190,663	(45,159)	$	145,504
Total noncurrent liabilities	$	837,714	(45,159)	$	792,555
Total capitalization and liabilities	$	4,372,985	(215,043)	$	4,157,942

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Cash Flows as of September 30, 2020, 2019 and 2018 are as follow:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Depreciation and amortization	$	119,894	(12,526)	$	107,368
Deferred income taxes	$	(9,092)	43,438	$	34,346
September 30, 2019
Depreciation and amortization	$	91,730	(10,621)	$	81,109
Deferred income taxes	$	(59,013)	56,191	$	(2,822)
September 30, 2018
Depreciation and amortization	$	85,701	(9,130)	$	76,571
Deferred income taxes	$	15,590	11,553	$	27,143

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Common Stock Equity as of September 30, 2020, 2019 and 2018 are as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Retained Earnings
Balance at September 30, 2017	$	867,984	(121,891)	$	746,093
Net Income	$	233,436	(2,423)	$	231,013
Balance at September 30, 2018	$	1,007,117	(124,314)	$	882,803
Net Income	$	169,505	(45,570)	$	123,935
Balance at September 30, 2019	$	1,075,960	(169,884)	$	906,076
Net Income	$	193,919	(30,912)	$	163,007
Balance at September 30, 2020	$	1,148,297	(200,796)	$	947,501
Total Common stock equity
Balance at September 30, 2017	$	1,236,643	(121,891)	$	1,114,752
Net Income	$	233,436	(2,423)	$	231,013
Balance at September 30, 2018	$	1,418,978	(124,314)	$	1,294,664
Net Income	$	169,505	(45,570)	$	123,935
Balance at September 30, 2019	$	1,551,717	(169,884)	$	1,381,833
Net Income	$	193,919	(30,912)	$	163,007
Balance at September 30, 2020	$	1,844,692	(200,796)	$	1,643,896

Recently Adopted Updates to the Accounting Standards Codification

Leases

In February 2016, the FASB issued ASU No. 2016-02, an amendment to ASC 842, Leases, which, along with other ASU's containing minor amendments and technical corrections, provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with an original term greater than one year are recorded on the balance sheet with a lessee recognizing a lease liability reflecting its obligation under the lease agreement and a right-of-use asset representing its right to use the leased asset over the lease term. The subsequent measurement of the lease depends on whether the lease is classified as an operating lease (resulting in the recognition of a straight-line lease cost) or a finance lease (resulting in the recognition of interest and asset amortization expense). Additional disclosures are required to provide transparency as to the amount, timing and uncertainty of cash flows arising from leasing activities.

In January 2018, the FASB issued ASU No. 2018-01, a further amendment to ASC 842, Leases, which was introduced by ASU No. 2016-02, as discussed above. This update provides an optional practical expedient that allows companies to not evaluate existing or expired land easements that were not previously accounted for under Topic 840 as leases as of October 1, 2019. The Company adopted this practical expedient. In July 2018, the FASB issued ASU No. 2018-11, which provides an optional transition method to ASC 842 that allows the Company to apply the new lease accounting requirements as of the effective date of the new standard, with the comparative periods remaining under the legacy ASC 840 requirements with a cumulative effect adjustment, if any, being made to the opening balance of retained earnings in the period of adoption. The Company elected this transition method and did not have any cumulative impact to the opening balance of retained earnings.

The Company elected various practical expedients permitted by ASC 842. This includes the package of practical expedients whereby the Company was not required to reassess all of its leases identified, lease classifications and initial direct costs associated with leases. The Company also elected to not separate nonlease components from lease components for certain classes of leases, such as office buildings, solar land leases and office equipment, and elected to exclude short-term leases from the recognition requirements of ASC 842 for all classes of assets. The Company adopted ASC 842 and all related amendments on October 1, 2019, using the modified retrospective transition method.

The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property leases, including land and office facility leases and office equipment and the sale leaseback of its natural gas meters. The total right-of-use assets and operating lease liabilities recorded upon adoption were $67.1 million. Upon the acquisition of Leaf River, on October 11, 2019, the Company adopted ASC 842 for Leaf River which resulted in the recognition of an additional right-of-use asset and lease liability of $21.6 million.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Derivatives and Hedging

In August 2017, the FASB issued ASU No. 2017-12, an amendment to ASC 815, Derivatives and Hedging, which, along with other ASU's containing minor amendments and technical corrections, is intended to make targeted improvements to the accounting for hedging activities by better aligning an entity’s risk management activities and financial reporting for hedging relationships. These amendments modify the accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Additionally, the amendments are intended to simplify the application of the hedge accounting guidance and provide relief to companies by easing certain hedge documentation requirements. The Company adopted this guidance on October 1, 2019. As October 1, 2019, the Company did not apply hedge accounting to its risk management activities, therefore the amendments did not have an impact on its financial position, results of operations or cash flows.

In October 2018, the FASB issued ASU No. 2018-16, an amendment to ASC 815, Derivatives and Hedging, which permits the use of the Overnight Index Swap rate based on the Secured Overnight Financing Rate as an additional acceptable U.S. benchmark interest rate for hedge accounting purposes. The Company adopted this guidance on October 1, 2019. As the Company did not apply hedge accounting to any of its risk management activities as of October 1, 2019, the amendments did not have an impact on its financial position, results of operations or cash flows.

Stock Compensation

In June 2018, the FASB issued ASU No. 2018-07, an amendment to ASC 718, Compensation - Stock Compensation, which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from non-employees. The Company adopted this guidance on October 1, 2019. There was no impact to the Company's financial position, results of operations or cash flows.

Financial Instruments

In March 2020, the FASB issued ASU No. 2020-03, Codification Improvements to Financial Instruments. This accounting standard provides clarification of guidance for financial instruments and makes narrow scope amendments related to various issues. The Company adopted this standard effective upon issuance. There was no impact to the Company's financial position, results of operations or cash flows as a result of its adoption.

Reference Rate Reform

In March 2020, the FASB issued ASU No. 2020-04, an amendment to ASC 848, Reference Rate Reform, which provides relief for companies preparing for discontinuation of interest rates such as LIBOR. The amendments in this update provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met. The amendments in this update apply only to contracts and hedging relationships that reference LIBOR or another reference rate expected to be discontinued due to reference rate reform. The amendments in this update are elective and are effective upon the ASU issuance through December 31, 2022. There was no impact to the Company's financial position, results of operations or cash flows as a result of its adoption.

Other Recent Updates to the Accounting Standards Codification

Financial Instruments

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

The Company completed its evaluation of ASU No. 2016-13 and subsequent amendments related to this topic and adopted this new guidance beginning October 1, 2020, using the modified retrospective method. The adoption did not result in a cumulative effect adjustment to retained earnings and did not have a material impact to our consolidated financial statements.

If implementation resulted in a material impact to amounts associated with NJNG accounts receivable and unbilled revenue within the scope of the new standard and that were considered incremental costs caused by COVID-19, the Company

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

could elect to defer those costs as a regulatory asset in accordance with the July 2, 2020 BPU order which authorized New Jersey utilities to create a regulatory asset for incremental COVID-19 related costs. See Note 4. Regulation for further detail.

Fair Value

In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective or retrospective basis depending on the specific amendments’ transition requirements. The Company is currently evaluating the impact of the adoption of this ASU but does not expect that its pending adoption will have a material effect on its consolidated financial statements. The Company does not have either Level 3 fair value measurements or transfers between Level 1 or Level 2 in its current portfolios, and therefore, does not expect this ASU to have an impact on the Company's financial statements and disclosures.

Compensation - Retirement Benefits

In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures and adds new disclosure requirements identified as relevant. The guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. Upon adoption, the amended presentation and disclosure guidance will be applied on a retrospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on the Company's disclosures upon adoption but it is not expecting this ASU to materially affect the financial statements and disclosures.

Income Taxes

In December 2019, the FASB issued ASU No. 2019-12, an amendment to ASC 740, Income Taxes, which is intended to simplify the accounting for income taxes and changes the accounting for certain income tax transactions, among other minor improvements. The guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Investments - Equity Method and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, Investments - Equity Securities (Topic 321), Investments - Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815): Clarifying the Interactions between Topic 321, Topic 323, and Topic 815. The update states that an entity is required to evaluate observable transactions that necessitate applying or discontinuing the equity method of accounting, when applying the measurement alternative in Topic 321. This evaluation occurs prior to applying or upon ceasing the equity method. The update also states that when applying paragraph 815-10-15-141(a) for forward contracts and purchased options, an entity is not required to assess whether the underlying securities will be accounted for under the equity method in accordance with Topic 323 or fair value method under Topic 825 upon settlement or exercise. The guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of this ASU but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

3. REVENUE

Revenue is recognized when a performance obligation is satisfied by transferring control of a product or service to a customer. Revenue is measured based on consideration specified in a contract with a customer using the output method of progress. The Company elected to apply the invoice practical expedient for recognizing revenue, whereby the amounts invoiced to customers represent the value to the customer and the Company’s performance completion as of the invoice date. Therefore we do 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 Consolidated Statements of Operations.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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

Revenue Recognized Over Time:
Segment	Performance Obligation	Description
Natural Gas Distribution	Natural gas utility sales	NJNG's performance obligation is to provide natural gas to residential, commercial and industrial customers as demanded, based on regulated tariff rates, which are established by the BPU. Revenues from the sale of natural gas are recognized in the period that 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 and wind 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. All wind assets were sold as of February 7, 2019. 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 RECs, 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	Wholesale natural gas services	The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers on a monthly basis in line with the terms of the contract and based on the services provided. Payment is due each month for the previous month's invoiced services.
Storage and Transportation	Natural gas services	The performance obligation of our Storage and Transportation segment is to provide the customer with storage and transportation services. Storage and Transportation generates revenues from firm storage contracts and transportation contracts, related usage fees for the use of storage space, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as our customers receive the benefits of our service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement.
Home Services and Other	Service contracts	Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Revenue Recognized at a Point in Time:
Storage and Transportation	Natural gas services	The performance obligation of our Storage and Transportation segment is to provide the customer with storage and transportation services. Storage and Transportation generates revenues from hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Hub services revenues are recognized as services are performed.
Home Services and Other	Installations	Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators, for 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 fiscal 2020 are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Natural gas utility sales	$	695,858	—		—	—	—	$	695,858
Wholesale natural gas services	—		—		24,511	44,728	—	69,239
Service contracts	—		—		—	—	32,455	32,455
Installations and maintenance	—		—		—	—	18,562	18,562
Renewable Energy Certificates	—		1,384		—	—	—	1,384
Electricity sales	—		20,099		—	—	—	20,099
Eliminations (1)	—		—		—	(2,713)	(1,207)	(3,920)
Revenues from contracts with customers	695,858		21,483		24,511	42,015	49,810	833,677
Alternative revenue programs (2)	15,750		—		—	—	—	15,750
Derivative Instruments	18,315		81,134	(3)	1,005,908	—	—	1,105,357
Eliminations (1)	—		—		(1,116)	—	—	(1,116)
Revenues out of scope	34,065		81,134		1,004,792	—	—	1,119,991
Total operating revenues	$	729,923	102,617		1,029,303	42,015	49,810	$	1,953,668
2019
Natural gas utility sales	$	680,151	—		—	—	—	$	680,151
Wholesale natural gas services	—		—		31,459	—	—	31,459
Service contracts	—		—		—	—	31,499	31,499
Installations and maintenance	—		—		—	—	19,403	19,403
Electricity sales	—		22,121		—	—	—	22,121
Eliminations (1)	—		—		—	—	(2,302)	(2,302)
Revenues from contracts with customers	680,151		22,121		31,459	—	48,600	782,331
Alternative revenue programs (2)	10,364		—		—	—	—	10,364
Derivative Instruments	20,278		75,978	(3)	1,711,332	—	—	1,807,588
Eliminations (1)	—		—		(8,238)	—	—	(8,238)
Revenues out of scope	30,642		75,978		1,703,094	—	—	1,809,714
Total operating revenues	$	710,793	98,099		1,734,553	—	48,600	$	2,592,045

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

(2)Includes CIP revenue.

(3)Includes SREC revenue.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the fiscal years ended September 30, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Residential	$	490,233	10,233	—	—	48,867	$	549,333
Commercial and industrial	129,946		11,250	24,511	42,015	943	208,665
Firm transportation	69,357		—	—	—	—	69,357
Interruptible and off-tariff	6,322		—	—	—	—	6,322
Revenues out of scope	34,065		81,134	1,004,792	—	—	1,119,991
Total operating revenues	$	729,923	102,617	1,029,303	42,015	49,810	$	1,953,668
2019
Residential	$	440,787	9,003	—	—	47,655	$	497,445
Commercial and industrial	171,357		13,118	31,459	—	945	216,879
Firm transportation	61,370		—	—	—	—	61,370
Interruptible and off-tariff	6,637		—	—	—	—	6,637
Revenues out of scope	30,642		75,978	1,703,094	—	—	1,809,714
Total operating revenues	$	710,793	98,099	1,734,553	—	48,600	$	2,592,045

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 Consolidated Balance Sheets during fiscal 2020 are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of October 1, 2019	$	139,263	$	6,510	$	27,116
(Decrease) Increase	(5,090)		2,716		(1,182)
Balance as of September 30, 2020	$	134,173	$	9,226	$	25,934

The following table provides information about receivables and revenue earned on contracts in progress in excess of billings, which are included within accounts receivable, billed and unbilled, and customers’ credit balances and deposits, respectively, on the Consolidated Balance Sheets as of September 30:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Customer accounts receivable
Billed	$	52,134	5,282	70,457	3,905	2,395	$	134,173
Unbilled	7,842		1,384	—	—	—	9,226
Customers' credit balances and deposits	(25,934)		—	—	—	—	(25,934)
Total	$	34,042	6,666	70,457	3,905	2,395	$	117,465
2019
Customer accounts receivable
Billed	$	36,302	3,233	97,301	—	2,427	$	139,263
Unbilled	6,510		—	—	—	—	6,510
Customers' credit balances and deposits	(27,114)		—	—	—	(2)	(27,116)
Total	$	15,698	3,233	97,301	—	2,425	$	118,657

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

4. REGULATION

The EDECA is the legal framework for New Jersey’s public utility and wholesale energy landscape. NJNG is required, pursuant to a written order by the BPU under EDECA, to open its residential markets to competition from third-party natural gas suppliers. Customers can choose the supplier of their natural gas commodity in NJNG’s service territory.

As required by EDECA, NJNG’s rates are segregated into two primary components: the commodity portion, which represents the wholesale cost of natural gas, including the cost for interstate pipeline capacity to transport the natural gas to NJNG’s service territory; and the delivery portion, which represents the transportation of the commodity portion through NJNG’s natural gas distribution system to the end-use customer. NJNG does not earn utility gross margin on the commodity portion of its natural gas sales. NJNG earns utility gross margin through the delivery of natural gas to its customers, regardless of whether it or a third-party supplier provides the wholesale natural gas commodity.

Under EDECA, the BPU is required to audit the state’s energy utilities every two years. The primary purpose of the audit is to ensure that utilities and their affiliates offering unregulated retail services do not have an unfair competitive advantage over nonaffiliated providers of similar retail services. A combined competitive services and management audit of NJNG commenced in August 1, 2013. A draft management audit report was accepted by the BPU on July 23, 2014, for public comment. To date, NJNG has implemented all audit recommendations with the approval of BPU staff and is waiting for final BPU approval.

NJNG is subject to cost-based regulation; therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility capital investments based on the BPU’s approval. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets, and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.

NJNG’s recovery of costs is facilitated through its base rates, BGSS and other regulatory tariff riders. NJNG is required to make an annual filing to the BPU by June 1 of each year for review of its BGSS, CIP and other programs and related rates. Annual rate changes are requested to be effective at the beginning of the following fiscal year. The current base rates include a weighted average cost of capital of 6.95 percent and a return on common equity of 9.6 percent. In addition, NJNG is permitted to request approval of certain rate or program changes. All rate and program changes are subject to proper notification and BPU review and approval.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are composed of the following:

(Thousands)	2020		2019
Regulatory assets-current
New Jersey Clean Energy Program	$	15,570	$	15,468
Conservation Incentive Program	19,120		3,371
Underrecovered natural gas costs	—		9,506
Derivatives at fair value, net	—		4,526
Other current regulatory assets	1,682		—
Total current regulatory assets	$	36,372	$	32,871
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	36,516	$	38,351
Liability for future expenditures	150,590		131,080
Deferred income taxes	28,241		19,631
Derivatives at fair value, net	1		486
SAVEGREEN	21,281		10,201
Postemployment and other benefit costs	188,170		212,461
Deferred storm damage costs	6,515		8,687
Cost of removal	75,080		65,660
Other noncurrent regulatory assets	20,068		10,080
Total noncurrent regulatory assets	$	526,462	$	496,637
Regulatory liability-current
Overrecovered natural gas costs	$	25,914	$	—
Derivatives at fair value, net	274		—
Total current regulatory liabilities	$	26,188	$	—
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	195,425	$	200,417
Derivatives at fair value, net	352		—
New Jersey Clean Energy Program	—		197
Other noncurrent regulatory liabilities	509		1,821
Total noncurrent regulatory liabilities	$	196,286	$	202,435

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

Regulatory assets at Adelphia Gateway, not included in the table above, total $158,000 and $997,000 in current and noncurrent, respectively, and is comprised primarily of the tax benefit associated with the equity component of AFUDC as of September 30, 2020. Recovery of regulatory assets is subject to FERC approval.

New Jersey Clean Energy Program

The NJCEP is a statewide program that encourages energy efficiency and renewable energy. Funding amounts are determined by the BPU’s Office of Clean Energy and all New Jersey utilities are required to share in the annual funding obligation. The current NJCEP program is for the State of New Jersey’s fiscal year ending June 2021. NJNG recovers the costs associated with its portion of the NJCEP obligation through its NJCEP rider, with interest.

Over and Underrecovered Natural Gas Costs

NJNG recovers its cost of natural gas through the BGSS rate component of its customers’ bills. NJNG’s cost of natural gas includes the purchased cost of the natural gas commodity, fees paid to pipelines and storage facilities, adjustments as a result of BGSS incentive programs and hedging transactions. Overrecovered natural gas costs represent a regulatory liability that generally occurs when NJNG’s BGSS rates are higher than actual costs and requests approval to be returned to customers including interest, when applicable, in accordance with NJNG’s approved BGSS tariff. Conversely, underrecovered natural gas costs generally occur during periods when NJNG’s BGSS rates are lower than actual costs, in which case NJNG records a regulatory asset and requests amounts to be recovered from customers in the future.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Derivatives

Derivatives are utilized by NJNG to manage the price risk associated with its natural gas purchasing activities and to participate in certain BGSS incentive programs. The gains and losses associated with NJNG’s derivatives are recoverable through its BGSS, as noted above, without interest. See Note 5. Derivative Instruments.

Conservation Incentive Program

The CIP permits NJNG to recover utility gross margin variations related to customer usage resulting from customer conservation efforts and mitigates the impact of weather on its margin. Such utility gross margin variations are recovered in the year following the end of the CIP usage year, without interest, and are subject to additional conditions, including an earnings test, a revenue test and an evaluation of BGSS-related savings. This program has no expiration date.

Environmental Remediation Costs

NJNG is responsible for the cleanup of certain former gas manufacturing facilities. Actual expenditures are recovered from customers, with interest, over seven-year rolling periods, through a RAC rate rider. Recovery for NJNG’s estimated future liability will be requested and/or recovered when actual expenditures are incurred. See Note 15. Commitments and Contingent Liabilities.

Deferred Income Taxes

Upon adoption of a 1993 provision of ASC 740, Income Taxes, NJNG recognized a transition adjustment and corresponding regulatory asset representing the difference between NJNG’s existing deferred tax amounts compared with the deferred tax amounts calculated in accordance with the change in method prescribed by ASC 740. NJNG recovers the regulatory asset associated with these tax impacts through future base rates, without interest.

SAVEGREEN

NJNG administers certain programs that supplement the state’s NJCEP and that allow NJNG to promote clean energy to its residential and commercial customers, as described further below. NJNG will recover related expenditures and a weighted average cost of capital on the unamortized balance through a tariff rider, with interest, as approved by the BPU, over a two- to 10-year period depending upon the specific program incentive.

Postemployment and Other Benefit Costs

Postemployment and Other Benefit Costs represents NJNG’s underfunded postemployment benefit obligations, as well as a fiscal 2010 tax charge resulting from a change in the deductibility of federal subsidies associated with Medicare Part D, both of which are deferred as regulatory assets and are recoverable, without interest, in base rates. The BPU approved the recovery of the tax charge through NJNG’s base rates effective October 2016 over a seven-year amortization period. See Note 11. Employee Benefit Plans.

Deferred Storm Damage Costs

Portions of NJNG’s distribution system incurred significant damage as a result of Post-Tropical Cyclone Sandy in October 2012. NJNG deferred the uninsured incremental O&M costs associated with its restoration efforts, which were approved for recovery by the BPU through NJNG’s base rates, without interest, effective October 2016 over a seven-year amortization period.

Cost of Removal

NJNG accrues and collects for cost of removal in base rates on its utility property, without interest. These costs are recorded in accumulated depreciation for regulatory reporting purposes, and actual costs of removal, without interest, will be recovered in subsequent rates, pursuant to the BPU order. Consistent with GAAP, amounts recorded within accumulated depreciation for regulatory accounting purposes are reclassified out of accumulated depreciation to either a regulatory asset or a regulatory liability depending on whether actual cost of removal is still subject to collection or amounts overcollected will be refunded back to customers. NJNG’s prior regulatory liability represented customer collections in excess of actual expenditures, which the Company returned to customers as a reduction to depreciation expense.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Other Regulatory Assets

Other regulatory assets consist primarily of deferred costs associated with certain components of NJNG’s SBC, as discussed further in the regulatory proceedings section, and NJNG’s compliance with federal- and state-mandated PIM provisions. NJNG’s related costs to maintain the operational integrity of its distribution and transmission main are recoverable, without interest, subject to BPU review and approval. As of September 30, 2020, NJNG recorded $1.8 million of PIM in other regulatory assets, which is being recovered through base rates over a seven-year amortization period effective October 2016.

The following is a description of certain regulatory proceedings during fiscal 2019 and 2020:

In March 2019, NJNG filed a base rate case with the BPU requesting a natural gas revenue increase of $128.2 million, including a change in the Company’s overall rate of return on rate base to 7.87 percent. NJNG is also seeking permission to request recovery for SRL in a future filing, upon completion of the project. On July 2, 2019, the Company filed an update with actual information through May 31, 2019, which reflected a revenue increase of $129.8 million. In September 2019, the Company filed a second update with actual information through August 31, 2019, which reflected a revenue increase of $134.3 million. On November 13, 2019, the BPU issued an order adopting a stipulation of settlement approving a $62.2 million increase to base rates, which were effective on November 15, 2019. The increase includes an overall rate of return on rate base of 6.95 percent, return on common equity of 9.6 percent, a common equity ratio of 54 percent and a depreciation rate of 2.78 percent.

BGSS and CIP

BGSS rates are normally revised on an annual basis. In addition, to manage the fluctuations in wholesale natural gas costs, NJNG has the ability to make two interim filings during each fiscal year to increase residential and small commercial customer BGSS rates on a self-implementing and provisional basis. NJNG is also permitted to refund or credit back a portion of the commodity costs to customers at any time given five days’ notice when the natural gas commodity costs decrease in comparison to amounts projected or to amounts previously collected from customers. Concurrent with the annual BGSS filing, NJNG files for an annual review of its CIP. NJNG’s annual BGSS and CIP filings are summarized as follows:

•2018 BGSS/CIP filing — In April 2019, the BPU approved NJNG’s annual petition on a final basis to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well as changes to the CIP rates, which resulted in a $30.9 million annual recovery decrease effective October 2018.

•On December 28, 2018, NJNG notified the BPU that it will increase the BGSS rate, effective February 1, 2019, resulting in an estimated $10.9 million increase to the revenues credited to BGSS from February through September 30, 2019.

•2019 BGSS/CIP filing — On March 27, 2020, the BPU approved, on a final basis, NJNG’s annual petition to modify its BGSS, balancing charge and CIP rates. The rate changes resulted in a $17.6 million decrease to the annual revenues credited to BGSS and a $15.6 million annual increase related to its balancing charge, as well as changes to CIP rates, which resulted in a $10.6 million annual recovery increase, effective October 1, 2019.

•2020 BGSS/CIP filing — On September 9, 2020, the BPU approved NJNG’s annual petition to modify its BGSS, balancing charge and CIP rates for residential and small commercial customers. The rate changes will result in a $20.4 million decrease to the annual revenues credited to BGSS, a $3.8 million annual decrease related to its balancing charge, as well as changes to CIP rates, which will result in a $16.5 million annual recovery increase, effective October 1, 2020.

BGSS Incentive Programs

NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of utility gross margin-sharing programs that include off-system sales, capacity release and storage incentive programs. The Company is permitted to annually propose a process to evaluate and discuss alternative incentive programs, should performance of the existing incentives or market conditions warrant re-evaluation.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Energy Efficiency Programs

SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives, which are designed to encourage the installation of high efficiency heating and cooling equipment and other upgrades to promote energy efficiency to its residential and commercial customers while stimulating state and local economies through the creation of jobs. Depending on the specific initiative or approval, NJNG recovers costs associated with the programs over a three- to 10-year period through a tariff rider mechanism. As of September 30, 2020, the BPU approved total SAVEGREEN investments of approximately $354.3 million, including $135 million that was approved in September 2018, for a continuation of existing EE programs and the implementation of new programs through December 2021.

On September 25, 2020, NJNG filed a petition with the BPU for an additional three-year SAVEGREEN program consisting of approximately $127 million of direct investment, $113 million in financing options, and approximately $23 million in operation and maintenance expenses, to be effective July 1, 2021. SAVEGREEN investments and costs are filed with the BPU on an annual basis. NJNG’s annual EE filings are summarized as follows:

•2018 EE filing — On December 18, 2018, the BPU approved a decrease in NJNG's EE recovery rate reflecting actual costs incurred through September 30, 2018, which resulted in an annual recovery of approximately $8.8 million, effective January 1, 2019.

•2019 EE filing — On October 25, 2019, the BPU approved an increase in NJNG's EE recovery rate, which resulted in an annual recovery of approximately $11.3 million, effective November 1, 2019.

•2020 EE filing — On May 29, 2020, NJNG filed a petition with the BPU to minimally decrease its EE recovery rate. Throughout the course of the proceeding, the Company updated the filing for additional actual information. Based on the updated information, the BPU approved the request to maintain its existing rate, which will result in an annual recovery of approximately $11.4 million, effective November 1, 2020.

Societal Benefits Charge

The SBC is comprised of three primary riders that allow NJNG to recover costs associated with USF, which is a permanent statewide program for all natural gas and electric utilities for the benefit of income-eligible customers, MGP remediation and the NJCEP. NJNG has submitted the following filings to the BPU, which include a report of program expenditures incurred each program year:

•2018 SBC filing — In September 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which resulted in a $1 million annual increase, effective October 1, 2018. In March 2019, the BPU approved NJNG’s annual SBC application requesting recovery of remediation expenses incurred through June 30, 2018, an increase in the RAC of approximately $1.4 million annually, and an increase to the NJCEP factor, which resulted in an annual increase of approximately $1.9 million, effective April 1, 2019.

•2019 SBC filing — On June 24, 2019, NJNG filed its annual USF compliance filing proposing an increase to the statewide USF rate, which will result in the annual recovery increasing by $1.2 million, effective October 1, 2019. On September 27, 2019, NJNG filed its annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $1.4 million annually and an increase to the NJCEP factor, which resulted in an annual increase of approximately $3.3 million, effective April 1, 2020. On March 16, 2020, a stipulation was signed in NJNG's annual SBC application which included an increase in the RAC rate of $1.2 million annually and a decrease to the NJCEP factor of $600,000. The BPU approved the stipulation on September 9, 2020, effective October 1, 2020.

•2020 USF filing — On June 25, 2020, NJNG filed its annual USF compliance filing proposing a decrease to the statewide USF rate, decreasing the annual recovery by approximately $400,000. On September 23, 2020, the BPU approved the decrease, effective October 1, 2020.

•2020 SBC filing — On September 29, 2020, NJNG filed its annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $1.3 million annually and an increase to the NJCEP factor, which will result in an annual increase of approximately $6 million, effective April 1, 2021.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Infrastructure Programs

NJNG has significant annual capital expenditures associated with the management of its natural gas distribution and transmission system, including new utility plant for customer growth and its associated PIM and infrastructure programs. NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability of NJNG’s natural gas distribution system, including SAFE and NJ RISE.

SAFE/NJ RISE

The SAFE program replaces portions of NJNG’s natural gas distribution unprotected steel, cast iron infrastructure and associated services to improve the safety and reliability of the natural gas distribution system. SAFE I was approved to invest up to $130 million, exclusive of AFUDC, over a four-year period. SAFE II was approved to invest up to $200 million, excluding AFUDC, over a five-year period. NJNG will recover approximately $157.5 million through annual rate filings, with the remainder recovered through subsequent rate cases. As a condition of approval of the program, NJNG was required to file a base rate case no later than November 2019 and satisfied this requirement with its March 29, 2019 base rate case filing.

NJ RISE consists of six capital investment projects estimated to cost $102.5 million over a five-year period, excluding AFUDC, for natural gas distribution storm-hardening and mitigation projects, along with incremental depreciation expense. NJ RISE includes a weighted average cost of capital that ranges from 6.74 percent to 6.9 percent and a return on equity of 9.75 percent. Requests for recovery of future NJ RISE capital costs will occur in conjunction with SAFE II.

On September 17, 2018, the BPU approved NJNG’s petition requesting a base rate increase of $6.8 million annually for the recovery of SAFE II and NJ RISE capital investment costs related to the 12 months ending June 30, 2018, effective October 1, 2018. On September 27, 2019, the BPU approved NJNG’s annual petition requesting a base rate increase of $7.8 million, effective October 1, 2019.

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

Southern Reliability Link

The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG’s service territory. All approvals required for the completion of the project have been received and construction began in December 2018.

Infrastructure Investment Program

On February 28, 2019, NJNG filed a petition with the BPU seeking authority to implement a five-year IIP. The IIP consists of two components, transmission and distribution investments and information technology replacement and enhancements. The total investment for the IIP is approximately $507 million. Upon approval from the BPU, investments will be recovered through annual filings to adjust base rates. On October 28, 2020, the BPU approved the Company’s transmission and distribution component of the IIP for $150 million over five years, effective November 1, 2020. The recovery of information technology replacement and enhancements, that was included in the original IIP filing, will be included as part of base rate filings as projects are placed in service.

Other Filings

COVID-19

On July 2, 2020, the BPU issued an order which authorized New Jersey utilities to create a regulatory asset by deferring incremental COVID-19 related costs and required a related quarterly report be filed for the COVID-19-related costs and savings incurred. Utilities must file petition by later of December 31, 2021, or within 60 days of the close of the regulatory asset period and rate recovery can be addressed in the filing or the utility may request consideration be deferred to future rate case. Any potential rate recovery and the appropriate period of recovery, will be addressed through that filing, or may request a deferral of rate recovery for a future base rate case.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The Tax Act

On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. As a result, NJNG recorded a regulatory liability, which included the revaluation of its deferred income taxes and the accounting of the income tax effects on the revaluation.

On January 31, 2018, the BPU issued an Order which directed New Jersey utilities to submit filings to the BPU by March 2, 2018, to propose the prospective change in base rates as a result of the Tax Act to be effective April 1, 2018, the method to return to customers the overcollection of taxes in base rates from January 1, 2018, through March 31, 2018, and an outline of the method by which the excess deferred taxes would be returned to customers. The excess deferred taxes are primarily related to timing differences associated with utility plant depreciation and are subject to IRS normalization rules, which require amortization over the remaining life of the utility plant.

As a result of the changes associated with the Tax Act, NJNG recorded a decrease in its net deferred tax liability of $228.4 million, which included $164.3 million for the revaluation of its deferred income taxes and $64.1 million for the accounting of the income tax effects on the revaluation of those deferred income taxes. These amounts were recorded as a regulatory liability on the Consolidated Balance Sheets. On March 1, 2018, NJNG submitted its required filing to the BPU proposing a $19.7 million base rate reduction and customer refunds of approximately $31 million, which is inclusive of state sales tax and interest at the Company’s short-term debt rate as specified in the Company’s last base rate case. On March 26, 2018, the BPU approved, on an interim basis, the $19.7 million rate reduction, effective April 1, 2018. On May 22, 2018, the BPU approved final rates and customer refunds of the $31 million. These credits were returned to customer accounts in June 2018. As of September 30, 2020, the regulatory liability included excess deferred income taxes of $195 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles.

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 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 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 Consolidated Balance Sheets, with changes in value recognized in current-period earnings.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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

NJNG’s physical and financial commodity derivatives, except for those designated as NPNS, are recognized at fair value on the Consolidated Balance Sheets. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Consolidated Balance Sheets. Effective January 1, 2016, the Company prospectively applies the NPNS scope exception on a case-by-case basis to certain qualifying physical commodity contracts. Contracts that are designated as NPNS are recognized in regulatory assets or liabilities on the Consolidated Balances Sheets upon settlement. The average cost of natural gas is charged to expense in the current-period earnings based on the BGSS factor times the therm sales.

In June 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with a $125 million debt issuance that was finalized in May 2018. This debt issuance coincided with the maturity of NJNG's $125 million, 5.6 percent notes that came due May 15, 2018. This treasury lock was settled on March 13, 2018, which coincided with the pricing of the new debt being issued. Settlement of the treasury lock resulted in a $2.6 million loss, which was recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the $125 million, 4.01 percent notes that were issued on May 11, 2018.

During fiscal 2020, NJNG entered into treasury lock transactions to fix the benchmark treasury rate associated with a $75 million debt tranche that was issued in September 2020. Settlement of the treasury locks resulted in a $6.6 million loss, which was recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the debt as a component of interest expense on the Consolidated Statements of Operations, which totaled $50,000, as of September 30, 2020.

Clean Energy Ventures

The Company elects NPNS accounting treatment on qualifying PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative. Contracts designated as NPNS are accounted for 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 certain contracts to be normal.

Home Services and Other

On January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on its $100 million variable rate term loan, which fixed the variable rate at 2.84 percent. The swap terminated on August 16, 2019, which coincided with the maturity of the debt. The change in the fair value and the settlement of the interest rate swap was recorded as a component of interest expense on the Consolidated Statements of Operations.

During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with $260 million debt issuance that was finalized in July 2020 and a $200 million debt issuance that was finalized in September 2020. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks resulted in a loss of $13.7 million, which was recorded within OCI and will be amortized in earnings over the life of the debt as a component of interest expense on the Consolidated Statements of Operations, which totaled $108,000, net of tax, as of September 30, 2020.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Fair Value of Derivatives

The following table reflects the fair value of the Company’s derivative assets and liabilities recognized on the Consolidated Balance Sheets as of September 30:

			Fair Value
			2020						2019
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	78		$	76		$	67		$	245
Financial commodity contracts	Derivatives - current		71			282			382			570
Energy Services:
Physical commodity contracts	Derivatives - current		6,454			20,438			6,847			27,540
	Derivatives - noncurrent		1,264			12,003			1,710			12,641
Financial commodity contracts	Derivatives - current		16,671			12,965			17,806			29,057
	Derivatives - noncurrent		2,037			1,346			5,716			6,105
Foreign currency contracts	Derivatives - current		36			104			1			211
	Derivatives - noncurrent		48			3			—			75
Total fair value of derivatives			$	26,659		$	47,217		$	32,529		$	76,444

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 Consolidated Balance Sheets.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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 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 September 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222
As of September 30, 2019:
Derivative assets:
Energy Services
Physical commodity contracts		$	8,557		$	(2,906)		$	(200)		$	5,451
Financial commodity contracts		23,522			(19,646)			—			3,876
Foreign currency contracts		1			(1)			—			—
Total Energy Services		$	32,080		$	(22,553)		$	(200)		$	9,327
Natural Gas Distribution
Physical commodity contracts		$	67		$	(9)		$	—		$	58
Financial commodity contracts		382			(382)						—
Total Natural Gas Distribution		$	449		$	(391)		$	—		$	58
Derivative liabilities:
Energy Services
Physical commodity contracts		$	40,181		$	(2,906)		$	—		$	37,275
Financial commodity contracts		35,162			(19,646)			(15,516)			—
Foreign currency contracts		286			(1)			—			285
Total Energy Services		$	75,629		$	(22,553)		$	(15,516)		$	37,560
Natural Gas Distribution
Physical commodity contracts		$	245		$	(9)		$	—		$	236
Financial commodity contracts		570			(382)			(188)			—
Total Natural Gas Distribution		$	815		$	(391)		$	(188)		$	236

(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.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical natural gas to be used for storage injection and its subsequent sale at a later date. The gains (losses) on the financial transactions that are economic hedges of the cost of the purchased natural gas are recognized prior to the gains (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 (losses) on the financial derivative instruments and gains (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 reflects the effect of derivative instruments on the Consolidated Statements of Operations as of September 30:

(Thousands)	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income on Derivatives
Derivatives not designated as hedging instruments:		2020		2019		2018
Energy Services:
Physical commodity contracts	Operating revenues	$	1,163	$	(5,732)	$	(9,311)
Physical commodity contracts	Natural gas purchases	(3,366)		(521)		(197)
Financial commodity contracts	Natural gas purchases	58,949		(643)		(24,622)
Foreign currency contracts	Natural gas purchases	(41)		(283)		(379)
Home Services and Other:
Interest rate contracts	Interest expense	—		(233)		334
Total unrealized and realized (losses) gains		$	56,705	$	(7,412)	$	(34,175)

NJNG’s derivative contracts are part of the Company’s risk management activities that relate to its natural gas purchases, BGSS incentive programs and debt financing. These transactions are entered into pursuant to regulatory approval. At settlement, the resulting gains and/or losses are payable to or recoverable from utility customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings.

The following table reflects the gains (losses) associated with NJNG’s derivative instruments as of September 30:

(Thousands)	2020		2019		2018
Natural Gas Distribution:
Physical commodity contracts	$	2,077	$	5,926	$	1,232
Financial commodity contracts	(3,903)		(7,700)		1,844
Interest rate contracts	—		—		8,467
Total unrealized and realized (losses) gains	$	(1,826)	$	(1,774)	$	11,543

NJR designates its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges are recorded in OCI and upon settlement of the contracts, realized gains and (losses) are reclassified from OCI to interest expense on the Consolidated Statements of Operations.

The following table reflects the effect of derivative instruments designated as cash flow hedges in OCI as of September 30:

(Thousands)	Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives				Location of Gain (Loss) Reclassified from OCI into Income	Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income
Derivatives in cash flow hedging relationships:	2020		2019			2020		2019
Interest rate contracts	$	(13,568)	$	—	Interest expense	$	140	$	—

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

NJNG and Energy Services had the following outstanding long (short) derivatives as of September 30:

		Volume (Bcf)
	Transaction Type	2020	2019
Natural Gas Distribution	Futures	23.7	27.6
	Physical Commodity	6.0	11.6
Energy Services	Futures	(27.5)	(29.6)
	Swaps	(1.8)	(5.0)
	Options	—	1.0
	Physical Commodity	5.0	44.5

Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $5.1 million and $6.2 million and 960,000 and 796,000 SRECs that were open, as of September 30, 2020 and 2019, 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 as of September 30, by segment, are as follows:

(Thousands)	Balance Sheet Location	2020		2019
Natural Gas Distribution	Restricted broker margin accounts	$	13,525	$	1,982
Energy Services	Restricted broker margin accounts	$	55,919	$	71,741

Wholesale Credit Risk

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

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of September 30, 2020. 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		$	132,105
Noninvestment grade		8,527
Internally-rated investment grade		24,647
Internally-rated noninvestment grade		12,471
Total		$	177,750

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

Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company’s credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on September 30, 2020 and 2019, were considered immaterial. These amounts differ from the respective net derivative liabilities reflected on the Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.

6. FAIR VALUE

Fair Value of Assets and Liabilities

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

As of September 30, the estimated fair value of long-term debt at NJNG and NJR, including current maturities, excluding finance leases and debt issuance costs, is as follows (1):

(Thousands)	2020		2019
NJNG (2) (3)
Carrying value	$	1,092,845	$	892,845
Fair market value	$	1,271,715	$	984,129
NJR (4)
Carrying value	$	1,010,000	$	550,000
Fair market value	$	1,146,033	$	584,735

(1)See Note 9. Debt for a reconciliation to long-term and short-term debt.

(2)Excludes finance leases of $74.2 million and $35.4 million as of September 30, 2020 and September 30, 2019, respectively.

(3)Excludes NJNG's debt issuance costs of $9.2 million and $9 million as of September 30, 2020 and September 30, 2019, respectively.

(4)Excludes NJR's debt issuance costs of $3.4 million and $2 million as of September 30, 2020 and September 30, 2019, respectively.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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 Consolidated Balance Sheets. The estimated fair value of solar asset financing obligations as of September 30, 2020 and September 30, 2019 was $149.2 million and $98.6 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 September 30, 2020, NJR 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, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs.

The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and includes the following:

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

Level 2Other significant observable inputs, such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:

•widely accepted and public;

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

•observable and published.

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

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

Financial derivative portfolios of NJNG and Energy Services consist mainly of futures, options and swaps. The Company primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market; therefore, the primary sources for its price inputs are CME, NYMEX and ICE. Energy Services uses Platts and Natural Gas Exchange for Canadian delivery points. However, Energy Services also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the transportation cost to the final delivery location is not significant to the overall valuation. If required, Energy Services’ policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or other pricing services.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The Company also has other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When the Company determines fair values, measurements are adjusted, as needed, for credit risk associated with its counterparties, as well as its own credit risk. The Company determines these adjustments by using historical default probabilities that correspond to the applicable S&P issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.

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 September 2020:
Assets
Physical commodity contracts		$	—		$	7,796		$	—	$	7,796
Financial commodity contracts		18,279			500			—		18,779
Financial commodity contracts - foreign exchange		—			84			—		84
Money market funds		112,291			—			—		112,291
Other		1,840			—			—		1,840
Total assets at fair value		$	132,410		$	8,380		$	—	$	140,790
Liabilities
Physical commodity contracts		$	—		$	32,517		$	—	$	32,517
Financial commodity contracts		14,593			—			—		14,593
Financial commodity contracts - foreign exchange		—			107			—		107
Total liabilities at fair value		$	14,593		$	32,624		$	—	$	47,217
As of September 30, 2019:
Assets
Physical commodity contracts		$	—		$	8,624		$	—	$	8,624
Financial commodity contracts		20,028			3,876			—		23,904
Financial commodity contracts - foreign exchange		—			1			—		1
Other (1)		1,706			—			—		1,706
Total assets at fair value		$	21,734		$	12,501		$	—	$	34,235
Liabilities
Physical commodity contracts		$	—		$	40,426		$	—	$	40,426
Financial commodity contracts		35,732			—			—		35,732
Financial commodity contracts - foreign exchange		—			286			—		286
Total liabilities at fair value		$	35,732		$	40,712		$	—	$	76,444

(1)Includes money market funds.

See Note 5. Derivative Instruments for additional details.

7. INVESTMENTS IN EQUITY INVESTEES

As of September 30, the Company’s investments in equity method investees includes the following:

(Thousands)	2020		2019
Steckman Ridge (1)	$	112,378	$	114,428
PennEast (2)	95,997		85,840
Total	$	208,375	$	200,268

(1)Includes loans with a total outstanding principal balance of $70.4 million for both fiscal 2020 and 2019, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

(2)Includes a deferred tax component related to AFUDC equity of $4.6 million and $4.1 million for September 30, 2020 and September 30, 2019, respectively.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Steckman Ridge

The Company holds a 50 percent equity method investment in Steckman Ridge, a jointly owned and controlled natural gas storage facility located in Bedford County, Pennsylvania. Due to the anticipated expiration of a customer contract, the Company evaluated its investment in Steckman Ridge for other-than-temporary impairment and determined an impairment charge was not necessary.

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

PennEast

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

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

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

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

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

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

On June 29, 2020, the Supreme Court requested that the Solicitor General of the U.S. file a brief that expresses the views on the question of the use of eminent domain to acquire state owned lands for pipeline construction. 

The Company evaluated its investment in PennEast for other-than-temporary impairment and determined an impairment charge was not necessary. The Company estimated the fair value of its investment in PennEast using probability-weighted scenarios of discounted future cash flows. Management made significant estimates and assumptions related to development options and legal outcomes, construction costs, timing of capital investments and in-service dates, revenues and discount rates. Higher probabilities were assumed related to those scenarios where the project is completed. The discounted cash flow scenarios contemplated the impact of key assumptions of future court decisions and future management decisions and requires management to make significant estimates regarding the likelihood of various scenarios and assumptions. It is reasonably possible that future unfavorable developments, such as a reduced likelihood of success from development options and legal outcomes, estimated increases in construction costs, increases in the discount rate, or further significant delays, could result in

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

an impairment of our equity method investment. Also, the use of alternate judgments and assumptions could result in a different calculation of fair value, which could ultimately result in the recognition of an other-than-temporary impairment charge in the Consolidated Financial Statements.

8. EARNINGS PER SHARE

The following table presents the calculation of the Company’s basic and diluted earnings per share for the fiscal years ended September 30:

(Thousands, except per share amounts)	2020		2019		2018
Net income, as reported	$	163,007	$	123,935	$	231,013
Basic earnings per share
Weighted average shares of common stock outstanding-basic	94,798		89,242		87,689
Basic earnings per common share	$1.72		$1.39		$2.63
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	94,798		89,242		87,689
Incremental shares (1)	305		354		626
Weighted average shares of common stock outstanding-diluted	95,103		89,596		88,315
Diluted earnings per common share (2)	$1.71		$1.38		$2.62

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

(2)There were anti-dilutive shares of 74,000 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement for fiscal 2020. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for fiscal 2019 and 2018.

9. DEBT

NJNG and NJR finance working capital requirements and capital expenditures through the issuance of various long-term debt and other financing arrangements, including unsecured credit and private placement debt shelf facilities. Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Long-term Debt

The following table presents the long-term debt of the Company as of September 30:

(Thousands)			2020		2019
NJNG
First mortgage bonds:		Maturity date:
3.00%	Series OO	August 1, 2041	46,500		46,500
3.15%	Series PP	April 15, 2028	50,000		50,000
3.58%	Series QQ	March 13, 2024	70,000		70,000
4.61%	Series RR	March 13, 2044	55,000		55,000
2.82%	Series SS	April 15, 2025	50,000		50,000
3.66%	Series TT	April 15, 2045	100,000		100,000
3.63%	Series UU	June 21, 2046	125,000		125,000
4.01%	Series VV	May 11, 2048	125,000		125,000
3.50%	Series WW	April 1, 2042	10,300		10,300
3.38%	Series XX	April 1, 2038	10,500		10,500
2.45%	Series YY	April 1, 2059	15,000		15,000
3.76%	Series ZZ	July 17, 2049	100,000		100,000
3.86%	Series AAA	July 17, 2059	85,000		85,000
2.75%	Series BBB	August 1, 2039	9,545		9,545
3.00%	Series CCC	August 1, 2043	41,000		41,000
3.13%	Series DDD	June 30, 2050	50,000		—
3.13%	Series EEE	July 23, 2050	50,000		—
3.33%	Series FFF	July 23, 2060	25,000		—
2.87%	Series GGG	September 1, 2050	25,000		—
2.97%	Series HHH	September 1, 2060	50,000		—
Finance lease obligation-buildings		June 30, 2037	47,597		5,637
Finance lease obligation-meters		Various dates	26,562		29,744
Less: Debt issuance costs			(9,195)		(9,027)
Less: Current maturities of long-term debt			(10,416)		(10,420)
Total NJNG long-term debt			1,147,393		908,779
NJR
3.25%	Unsecured senior notes	September 17, 2022	50,000		50,000
3.20%	Unsecured senior notes	August 18, 2023	50,000		50,000
3.48%	Unsecured senior notes	November 7, 2024	100,000		100,000
3.54%	Unsecured senior notes	August 18, 2026	100,000		100,000
3.96%	Unsecured senior notes	June 8, 2028	100,000		100,000
3.29%	Unsecured senior notes	July 17, 2029	150,000		150,000
3.60%	Unsecured senior notes	July 23, 2032	130,000		—
3.50%	Unsecured senior notes	July 23, 2030	130,000		—
3.25%	Unsecured senior notes	September 1, 2033	80,000		—
3.13%	Unsecured senior notes	September 1, 2031	120,000		—
Less: Debt issuance costs			(3,424)		(2,004)
Less: Current maturities of long-term debt			—		—
Total NJR long-term debt			1,006,576		547,996
Clean Energy Ventures
Solar asset financing obligation		Various dates	122,317		91,401
Less: Current maturities of long-term debt			(16,820)		(10,999)
Total Clean Energy Ventures long-term debt			105,497		80,402
Total long-term debt			$	2,259,466	$	1,537,177

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Annual long-term debt redemption requirements, excluding finance leases, debt issuance costs and solar asset financing obligations, as of September 30, are as follows:

(Thousands)	NJR		NJNG
2021	$	—	$	—
2022	$	50,000	$	—
2023	$	50,000	$	—
2024	$	100,000	$	70,000
2025	$	—	$	50,000
Thereafter	$	810,000	$	972,845

NJNG

First Mortgage Bonds

NJNG and Trustee entered into the Mortgage Indenture, dated September 1, 2014, which secures all of the outstanding First Mortgage Bonds issued by NJNG. The Mortgage Indenture provides a direct first mortgage lien upon substantially all of the operating properties and franchises of NJNG (other than excepted property, such as cash on hand, choses-in-action, securities, rent, natural gas meters and certain materials, supplies, appliances and vehicles), subject only to certain permitted encumbrances. The Mortgage Indenture contains provisions subjecting after-acquired property (other than excepted property and subject to pre-existing liens, if any, at the time of acquisition) to the lien thereof.

NJNG’s Mortgage Indenture does not restrict NJNG’s ability to pay dividends. New Jersey Administrative Code 14:4-4.7 states that a public utility cannot issue dividends, without regulatory approval, if its equity to total capitalization ratio falls below 30 percent. As of September 30, 2020, NJNG’s equity to total capitalization ratio is 53.1 percent and has the ability to issue up to $1.1 billion of FMB under the terms of the Mortgage Indenture.

On April 18, 2019, NJNG completed the remarketing of three FMBs, in the amount of $35.8 million, with a weighted average interest rate of 3.02 percent. The bonds have maturity dates ranging from April 2038 to April 2059. The bonds were previously purchased in lieu of redemption and were being held by the Company.

On July 17, 2019, NJNG entered into a Note Purchase Agreement, under which NJNG issued $100 million of 3.76 percent senior notes due July 17, 2049 and $85 million of 3.86 percent senior notes due July 17, 2059. The senior notes are secured by an equal principal amount of NJNG's FMBs issued under NJNG's Mortgage Indenture.

On August 1, 2019, NJNG completed a remarketing of three existing variable rate FMBs, with a total principal amount of $97 million, which fixed the interest rates of the bonds. NJNG remarketed $46.5 million at 3 percent due August 1, 2041, $41 million at 3 percent due August 2043 and $9.5 million at 2.75 percent due August 1, 2039. EDA Bonds are special, limited obligations of the EDA payable solely from payments made by NJNG pursuant to a Loan Agreement and are secured by the pledge of $97 million principal amount of the FMB issued by the Company.

On May 14, 2020, NJNG entered into a Note Purchase Agreement for $125 million of its senior notes, of which $100 million were at an interest rate of 3.13 percent, maturing in 2050, and $25 million were at an interest rate of 3.33 percent, maturing in 2060. On June 30, 2020, NJNG issued $50 million of 3.13 percent senior notes due June 30, 2050. On July 23, 2020, NJNG issued the remaining $50 million of 3.13 percent senior notes due July 23, 2050 and $25 million of 3.33 percent senior notes due July 23, 2060. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

On September 1, 2020, NJNG entered into and issued a Note Purchase Agreement for $75 million of its senior notes, of which $25 million were at an interest rate of 2.87 percent, maturing in 2050, and $50 million were at an interest rate of 2.97 percent, maturing in 2060. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

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Sale Leasebacks

NJNG has entered into a sale leaseback for its headquarters building, which has a 16-year term that expires in June 30, 2037. The present value of the agreement’s lease payments is reflected as a finance lease liability, which are included in utility plant and long-term debt, respectively, on the Consolidated Balance Sheets.

NJNG received $4 million, $9.9 million and $7.8 million for fiscal 2020, 2019 and 2018, respectively, in connection with the sale leaseback of its natural gas meters. NJNG records a finance lease liability that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease. During fiscal 2020, 2019 and 2018, NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1.2 million, $1.1 million and $2.2 million, respectively.

Contractual commitments for finance lease payments, as of the fiscal years ended September 30, are as follows:

(Thousands)	senior note
2021		$	54,992
2022		6,004
2023		4,622
2024		5,279
2025		3,396
Thereafter		2,324
Subtotal		76,617
Less: Interest component		(2,458)
Total		$	74,159

NJR

On July 17, 2019, NJR entered into a Note Purchase Agreement for $150 million of 3.29 percent senior notes due on July 17, 2029. NJR issued $50 million of these senior notes on July 17, 2019 and issued the remaining $100 million of these senior notes on August 15, 2019.

On January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on its $100 million variable rate term loan, which fixed the variable rate at 2.84 percent. The swap terminated on August 16, 2019, which coincided with the maturity of the debt. NJR had no long-term variable-rate debt outstanding as of September 30, 2020 and 2019.

On May 14, 2020, NJR entered into a Note Purchase Agreement for $260 million of its senior notes, of which $130 million are at a fixed interest rate of 3.5 percent, maturing in 2030, and $130 million are at a fixed interest rate of 3.6 percent, maturing in 2032. On July 23, 2020, NJR issued all $260 million of the senior notes. The senior notes are unsecured and guaranteed by certain unregulated subsidiaries of NJR.

On September 1, 2020, NJR entered into and issued a Note Purchase Agreement for $200 million of its senior notes, of which $120 million are at a fixed interest rate of 3.13 percent, maturing in 2031, and $80 million are at a fixed interest rate of 3.25 percent, maturing in 2033. The senior notes are unsecured and guaranteed by certain unregulated subsidiaries of NJR.

Clean Energy Ventures

Clean Energy Ventures received proceeds of $42.9 million and $71.5 million in fiscal 2020 and 2018, respectively, in connection with the sale leaseback of commercial solar assets. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during fiscal 2019. Clean Energy Ventures enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over a period of five to 15 years. These sale leasebacks arrangements did not qualify for sale treatment and, therefore, are accounted for as a financing arrangement, which are typically secured by the renewable energy facility asset and its future cash flows from SREC and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer. Clean Energy Ventures continues to operate the solar assets, including related expenses, and retain the revenue generated from SRECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the contract term.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Contractual commitments for the solar financing obligation payments, as of the fiscal years ended September 30, are as follows:

(Thousands)	Lease Payments
2021		$	12,928
2022		12,926
2023		13,003
2024		12,904
2025		8,985
Thereafter		47,268
Subtotal		108,014
Less: Interest component		(23,052)
Total		$	84,962

Short-term Debt

A summary of NJR’s and NJNG’s short-term bank facilities as of September 30, are as follows:

(Thousands)	2020			2019			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	425,000		$	425,000		December 2023
Notes outstanding at end of period	$	125,350		$	25,450
Weighted average interest rate at end of period	1.49		%	3.04		%
Amount available at end of period (2)	$	289,356		$	394,800
Bank revolving credit facilities (1)	$	250,000		$	—		April 2021
Notes outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (2)	$	250,000		$	—
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		December 2023
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2)Letters of credit outstanding total $10.3 million and $4.8 million as of September 30, 2020 and 2019, respectively, which reduces amount available by the same amount.

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

(4)Letters of credit outstanding total $731,000 as of September 30, 2020 and 2019, which reduces amount available by the same amount.

Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit. Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.

On October 9, 2019, NJR entered into a $350 million Bridge Facility, which was used primarily to finance the Leaf River acquisition. The Bridge Facility accrued interest at the LIBOR rate for a 1-month interest period plus 0.875 percent during the first 180 days, and 1.075 percent after 180 days. Loans under the Bridge Facility were required to be prepaid to the extent of new cash proceeds received upon the issuance of equity of NJR, the incurrence of indebtedness by NJR or its subsidiaries, the disposition of assets by NJR or its subsidiaries or upon other specified events, in each case subject to certain exceptions set forth in the Bridge Facility. As of September 30, 2020, the loan was repaid in full.

NJR

On April 24, 2020, NJR entered into a 364-day $250 million revolving credit facility with an interest rate based on LIBOR plus 1.625 percent. After six months, all outstanding amounts under the credit facility would convert to a term loan and would be due on April 23, 2021. In connection with entry into this credit facility, as of September 30, 2020, all outstanding borrowings under NJR's December 13, 2019, $150 million revolving line of credit facility were repaid. On October 24, 2020, there was no balance outstanding on the $250 million credit facility. As a result, the credit facility was considered terminated.

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On June 25, 2018, the $425 million NJR Credit Facility was amended to permit liens and the disposition of assets relating to sale leaseback or other similar tax equity financing arrangements of meter assets or of solar facilities. These transactions are permissible so long as NJR is in compliance with certain covenants both before and after such incurrence, and if no event of default may be caused by such sale leaseback or similar arrangement.

On December 5, 2018, NJR entered into an Amended and Restated Credit Agreement governing a $425 million NJR Credit Facility. The NJR Credit Facility expires on December 5, 2023, subject to two mutual options for a one-year extension beyond that date. The NJR Credit Facility permits the borrowing of revolving loans and swingline loans, as well as the issuance of letters of credit. The NJR Credit Facility also includes an accordion feature, which would allow NJR, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit Facility in minimum increments of $50 million increments up to a maximum of $250 million. Certain of NJR’s unregulated subsidiaries have guaranteed all of NJR’s obligations under the NJR Credit Facility. The credit facility is used primarily to finance its share repurchases, to satisfy Energy Services’ short-term liquidity needs and to finance, on an initial basis, unregulated investments.

As of September 30, 2020, NJR had seven letters of credit outstanding totaling $10.3 million on behalf of Energy Services and Clean Energy Ventures. These letters of credit reduce the amount available under NJR’s committed credit facility by the same amount. NJR does not anticipate that these letters of credit will be drawn upon by the counterparties, and they will be renewed as necessary.

Energy Services’ letters of credit are used for margin requirements for natural gas transactions, collateral and security deposit for retail natural gas sales and expire on dates ranging from December 2020 to September 2021.

Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.

NJNG

On December 5, 2018, NJNG entered into an Amended and Restated Credit Agreement governing a $250 million, NJNG Credit Facility. The NJNG Credit Facility expires on December 5, 2023, subject to two mutual options for a one-year extension beyond that date. The NJNG Credit Facility permits the borrowing of revolving loans and swingline loans, as well as the issuance of letters of credit. The NJNG Credit Facility also includes an accordion feature, which would allow NJNG, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJNG Credit Facility in minimum increments of $50 million up to a maximum of $100 million.

As of September 30, 2020, NJNG has two letters of credit outstanding for $731,000. NJNG’s letters of credit are used as collateral for remediation projects and expire in August 11, 2021. These letters of credit reduce the amount available under NJNG’s committed credit facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by the counterparty and they will be renewed as necessary.

10. STOCK-BASED COMPENSATION

In January 2017, the NJR 2017 Stock Award and Incentive Plan replaced the NJR 2007 Stock Award and Incentive Plan. Shares have been issued in the form of performance share units, restricted stock units, deferred retention stock units and unrestricted common stock to non-employee directors. As of September 30, 2020, 3,189,550 shares remain available for future issuance.

The following table summarizes all stock-based compensation expense recognized during the following fiscal years:

(Thousands)	2020		2019		2018
Stock-based compensation expense:
Performance share awards	$	1,943	$	5,804	$	3,526
Restricted and non-restricted stock	2,868		2,492		2,191
Deferred retention stock	1,725		1,500		7,128
Compensation expense included in operation and maintenance expense	6,536		9,796		12,845
Income tax benefit (1)	(1,900)		(2,848)		(3,734)
Total, net of tax	$	4,636	$	6,948	$	9,111

(1)Excludes additional tax benefit related to delivered shares of $647,000, $1.3 million and $3 million as of September 30, 2020, 2019 and 2018, respectively.

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Performance Share Units

In fiscal 2020, the Company granted to certain officers 33,123 performance shares, which are market condition awards that vest on September 30, 2022, subject to the Company meeting certain conditions. In fiscal 2020, the Company also granted to certain officers 48,941 performance shares, of which 30,473 vest on September 30, 2022 and 18,468 vest annually over a three-year period beginning in September 2020, both of which are subject to the Company meeting certain performance conditions.

In fiscal 2019, the Company granted to certain officers 36,392 performance shares, which are market condition awards that vest on September 30, 2021, subject to the Company meeting certain conditions. In fiscal 2019, the Company also granted to certain officers 63,870 performance shares, of which 33,844 vest on September 30, 2021 and 30,026 vest annually over a three-year period beginning in September 2019, both of which are subject to the Company meeting certain performance conditions.

In fiscal 2018, the Company granted to certain officers 31,836 performance shares, which are market condition awards that vested on September 30, 2020, subject to the Company meeting certain conditions. In fiscal 2018, the Company also granted to certain officers 59,341 performance shares, of which 29,608 vested in September 30, 2020 and 29,733 vest annually over a three-year period beginning in September 2018, both of which were subject to the Company meeting certain performance conditions. The vesting of these awards are shown in the table below.

There is approximately $2.4 million of deferred compensation related to unvested performance shares that is expected to be recognized over the weighted average period of 1.7 years.

The following table summarizes the performance share activity under the stock award and incentive plans for the past three fiscal years:

	Shares (1)	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Non-vested and outstanding at September 30, 2017	156,587		$30.12		—
Granted	91,177		$44.67		—
Vested (2)	(100,146)		$29.49		$	4,714
Cancelled/forfeited	(2,442)		$31.45		—
Non-vested and outstanding at September 30, 2018	145,176		$39.67		—
Granted	100,262		$47.98		—
Vested (3)	(103,009)		$38.52		$	4,622
Cancelled/forfeited	(11,920)		$44.34		—
Non-vested and outstanding at September 30, 2019	130,509		$46.53		—
Granted	82,064		$40.61		—
Vested (4)	(55,025)		$44.27		$	2,083
Cancelled/forfeited	(1,817)		$44.38		—
Non-vested and outstanding at September 30, 2020	155,731		$44.22		—

(1)The number of common shares issued related to certain performance shares may range from zero to 150 percent of the number of shares shown in the table above based on the Company’s achievement of performance goals.

(2)As certified by the Company’s Leadership and Compensation Committee on November 13, 2018, the number of common shares related to performance shares earned was 99 percent, or 38,660 shares, the number of common shares earned related to NFE performance was 121 percent or 39,694 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 36,998 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

(3)As certified by the Company’s Leadership and Compensation Committee on November 12, 2019, the number of common shares earned related to TSR performance was 119 percent or 43,641 shares, the number of common shares earned related to NFE performance was 117 percent or 26,413 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 24,468 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

(4)As certified by the Company’s Leadership and Compensation Committee on November 9, 2020, there were no common shares earned related to TSR performance, the number of common shares earned related to NFE performance was 114 percent or 28,513 shares and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 11,139 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

The Company measures compensation expense related to performance shares based on the fair value of these awards at their date of grant. In accordance with ASC 718, Compensation - Stock Compensation, compensation expense for market condition grants are recognized for awards granted, and are not adjusted based on actual achievement of the performance goals. The Company estimated the fair value of these grants on the date of grant using a lattice model. Performance condition grants

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

are initially fair valued at the Company’s stock price on grant date, and are subsequently adjusted for actual achievement of the performance goals.

Restricted Stock Units

In fiscal 2020, the Company granted 42,478 shares of restricted stock units that vest annually over a three-year period beginning October 2020. In fiscal 2019, the Company granted 29,222 shares of restricted stock that vest annually over a three-year period beginning in October 2019. In fiscal 2019, the Company also granted 6,062 shares of restricted stock that vest annually over a three-year period beginning April 2020. In fiscal 2018, the Company granted 27,949 shares of restricted stock that vest annually over a three-year period beginning in October 2018. There is approximately $1 million of deferred compensation related to unvested restricted stock shares that is expected to be recognized over the weighted average period of 1.8 years.

The following table summarizes the restricted stock activity under the stock award and incentive plans for the past three fiscal years:

	Shares	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Non-vested and outstanding at September 30, 2017	51,154		$32.40		—
Granted	27,949		$45.00		—
Vested	(33,815)		$31.23		$	1,438
Cancelled/forfeited	(1,120)		$33.54		—
Non-vested and outstanding at September 30, 2018	44,168		$41.24		—
Granted	35,284		$48.24		—
Vested	(20,748)		$39.26		$	935
Cancelled/forfeited	(548)		$42.96		—
Non-vested and outstanding at September 30, 2019	58,156		$46.18		—
Granted	42,478		$40.61		—
Vested	(25,973)		$44.71		$	1,073
Cancelled/forfeited	(1,175)		$43.62		—
Non-vested and outstanding at September 30, 2020	73,486		$43.52		—

Deferred Retention Stock Units

Deferred retention stock awards are granted upon approval by the Board of Directors, which generally occurs subsequent to the fiscal year end. Deferred retention stock awards vest immediately when granted, with shares delivered at a future date in accordance with the terms of the underlying agreements. The expense for these awards is recognized in the fiscal year in which services are rendered. The following table summarizes the deferred retention stock award under the stock award and incentive plans for the past three fiscal years:

	Shares	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Outstanding at September 30, 2017	672,578		$29.54		—
Granted/Vested	24,167		$45.00		—
Delivered	(452,694)		$29.42		$	19,581
Forfeited	(1,969)		$35.56
Outstanding at September 30, 2018	242,082		$32.99		—
Granted/Vested	167,407		$47.95		—
Delivered	(158,733)		$30.32		$	7,145
Forfeited	(7,195)		$44.41		—
Outstanding at September 30, 2019	243,561		$44.67		—
Granted/Vested	42,358		$40.72		—
Delivered	(57,673)		$35.25		$	2,423
Outstanding at September 30, 2020	228,246		$46.32		—

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Non-Employee Director Stock

Effective January 2020, non-employee director compensation includes an annual equity retainer that is awarded at the time of the Company’s annual meeting of shareowners. The shares vest upon the earlier of the first anniversary of the grant date or the date of the Company’s next annual meeting of shareowners following the grant date and are subsequently amortized to expense over a 12-month period. During fiscal years 2019 and 2018, the equity portion of non-employee director compensation was awarded in shares of NJR common stock. The shares vested immediately and were subsequently amortized to expense over a 12-month period. The following summarizes non-employee director share awards for the past three fiscal years:

	2020		2019	2018
Shares granted	27,696	(1)	26,165	26,524
Weighted average grant date fair value	$42.88		$44.80	$39.85

(1)$311,000 of expense remains as of September 30, 2020, to be recognized through December 31, 2020.

11. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

The Company has two trusteed, noncontributory defined benefit retirement plans covering eligible regular represented and non-represented employees with more than one year of service. Defined benefit plan benefits are based on years of service and average compensation during the highest 60 consecutive months of employment. The Company also provides postemployment medical and life insurance benefits to employees who meet certain eligibility requirements.

All represented employees of NJRHS hired on or after October 1, 2000, non-represented employees hired on or after October 1, 2009 and NJNG represented employees hired on or after January 1, 2012, are covered by an enhanced defined contribution plan instead of the defined benefit plan. Participation in the postemployment medical and life insurance plan was also frozen to new employees as of the same dates, with the exception of new NJRHS represented employees, for which benefits were frozen beginning April 3, 2012.

The Company maintains an unfunded nonqualified PEP that was established to provide employees with the full level of benefits as stated in the qualified plan without reductions due to various limitations imposed by the provisions of federal income tax laws and regulations. There were no plan assets in the nonqualified plan due to the nature of the plan.

In April 2018, the Company implemented a voluntary early retirement program open to certain eligible employees. As of September 30, 2018, pension and postemployment benefit costs related to the special termination benefits were $4.2 million and other severance benefits were $2.2 million. For the amounts incurred, NJNG recognized an expense of approximately $5.1 million and Home Services and other recognized an expense of approximately $1.3 million, as a component of O&M in the Consolidated Statements of Operations.

The Company’s funding policy for its pension plans is to contribute at least the minimum amount required by the Employee Retirement Income Security Act of 1974, as amended. In fiscal 2020 and 2019, the Company had no minimum funding requirements. The Company made no discretionary contributions to the pension plans in fiscal 2020 or 2019. The Company does not expect to be required to make additional contributions to fund the pension plans over the following two fiscal years based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents.

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. The Company contributed $8.4 million and $7.9 million, in fiscal 2020 and 2019, respectively, and estimates that it will contribute between $5 million and $10 million over each of the next five years. Additional contributions may be required based on market conditions and changes to assumptions.

The Affordable Care Act was enacted in March 2010 and created an excise tax applicable to high-cost health plans, commonly known as the Cadillac Tax. Employers who sponsor health plans that have an annual cost that exceeded an amount defined by the law would pay a 40 percent tax on the excess plan costs beginning in 2022. The 2020 federal spending package permanently eliminated the Affordable Care Act-mandated Cadillac tax on high-cost employer-sponsored health coverage. Due to the repeal, the Company's OPEB liability was revalued for these changes. The Company applied a practical expedient to remeasure the plan assets and obligations as of December 31, 2019, which was the nearest calendar month-end date. The impact of the revaluation of the OPEB liability was recorded as of January 1, 2020 and is incorporated within actuarial assumptions at September 30, 2020.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The following summarizes the changes in the funded status of the plans and the related liabilities recognized on the Consolidated Balance Sheets as of September 30:

	Pension (1)				OPEB
(Thousands)	2020		2019		2020		2019
Change in Benefit Obligation
Benefit obligation at beginning of year	$	360,477	$	298,575	$	260,003	$	196,785
Service cost	8,223		7,381		4,854		4,404
Interest cost	10,587		12,173		7,026		8,324
Plan participants’ contributions (2)	25		43		194		210
Actuarial loss (gain)	29,738		52,549		(23,226)		54,700
Benefits paid, net of retiree subsidies received	(11,886)		(10,244)		(2,989)		(4,420)
Benefit obligation at end of year	$	397,164	$	360,477	$	245,862	$	260,003
Change in plan assets
Fair value of plan assets at beginning of year	$	288,634	$	279,410	$	83,925	$	77,980
Actual return on plan assets	30,632		19,194		6,872		2,499
Employer contributions	596		231		8,436		7,926
Benefits paid, net of plan participants’ contributions (2)	(11,894)		(10,201)		(2,827)		(4,479)
Fair value of plan assets at end of year	$	307,968	$	288,634	$	96,406	$	83,926
Funded status	$	(89,196)	$	(71,843)	$	(149,456)	$	(176,077)
Amounts recognized on Consolidated Balance Sheets
Postemployment employee (liability)
Current	$	(531)	$	(603)	$	(900)	$	(800)
Noncurrent	(88,665)		(71,240)		(148,556)		(175,277)
Total	$	(89,196)	$	(71,843)	$	(149,456)	$	(176,077)

(1)Includes the Company’s PEP.

(2)Prior to July 1, 1998, employees were eligible to elect an additional participant contribution to enhance their benefits and contributions made during the periods were insignificant.

The actuarial loss on the Company’s pension is primarily due to a decrease in the discount rate used to measure the benefit obligation. The actuarial gain related to the OPEB plans is primarily due to the remeasurement of the plan assets and obligations due to the removal of the Cadillac tax, partially offset by a decrease in the discount rate. The Company recognizes a liability for its underfunded benefit plans as required by ASC 715, Compensation - Retirement Benefits. The Company records the offset to regulatory assets for the portion of liability relating to NJNG and to accumulated other comprehensive income for the portion of the liability related to its unregulated operations.

The following table summarizes the amounts recognized in regulatory assets and accumulated other comprehensive income as of September 30:

	Regulatory Assets				Accumulated Other Comprehensive Income (Loss)
	Pension		OPEB		Pension		OPEB
Balance at September 30, 2018	$	66,233	$	68,685	$	14,633	$	7,659
Amounts arising during the period:
Net actuarial loss	38,137		48,452		14,271		9,264
Amounts amortized to net periodic costs:
Net actuarial (loss)	(4,662)		(5,820)		(1,103)		(648)
Prior service credit	(102)		312		—		53
Balance at September 30, 2019	$	99,606	$	111,629	$	27,801	$	16,328
Amounts arising during the period:
Net actuarial loss (gain)	11,953		(21,974)		7,731		(1,614)
Amounts amortized to net periodic costs:
Net actuarial (loss)	(7,893)		(6,536)		(2,528)		(907)
Prior service (cost) credit	(102)		182		—		16
Balance at September 30, 2020	$	103,564	$	83,301	$	33,004	$	13,823

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The amounts in regulatory assets and accumulated other comprehensive income not yet recognized as components of net periodic benefit cost as of September 30 are:

	Regulatory Assets								Accumulated Other Comprehensive Income (Loss)
	Pension				OPEB				Pension				OPEB
(Thousands)	2020		2019		2020		2019		2020		2019		2020		2019
Net actuarial loss	$	103,197	$	99,139	$	83,600	$	112,109	$	33,004	$	27,801	$	13,847	$	16,367
Prior service cost (credit)	367		467		(299)		(480)		—		—		(24)		(39)
Total	$	103,564	$	99,606	$	83,301	$	111,629	$	33,004	$	27,801	$	13,823	$	16,328

To the extent the unrecognized amounts in accumulated other comprehensive income or regulatory assets exceed 10 percent of the greater of the benefit obligation or the fair value of plan assets, an amortized amount over the average expected future working lifetime of the active plan participants is recognized. Amounts included in regulatory assets and accumulated other comprehensive income expected to be recognized as components of net periodic benefit cost in fiscal 2021 are as follows:

	Regulatory Assets				Accumulated Other Comprehensive Income (Loss)
(Thousands)	Pension		OPEB		Pension		OPEB
Net actuarial loss	$	8,269	$	6,846	$	3,178	$	1,064
Prior service cost (credit)	102		(166)		—		(13)
Total	$	8,371	$	6,680	$	3,178	$	1,051

The accumulated benefit obligation for the pension plans, including the PEP, exceeded the fair value of plan assets. The projected benefit and accumulated benefit obligations and the fair value of plan assets as of September 30, are as follows:

	Pension
(Thousands)	2020		2019
Projected benefit obligation	$	397,164	$	360,477
Accumulated benefit obligation	$	352,320	$	319,527
Fair value of plan assets	$	307,968	$	288,634

The components of the net periodic cost for pension benefits, including the Company’s PEP, and OPEB costs (principally health care and life insurance) for employees and covered dependents for fiscal years ended September 30, are as follows:

	Pension						OPEB
(Thousands)	2020		2019		2018		2020		2019		2018
Service cost	$	8,223	$	7,381	$	8,139	$	4,854	$	4,404	$	4,607
Interest cost	10,587		12,173		10,493		7,026		8,324		6,365
Expected return on plan assets	(20,579)		(19,054)		(19,639)		(6,510)		(5,515)		(5,352)
Recognized actuarial loss	10,424		5,765		7,537		7,442		6,466		4,660
Prior service cost (credit) amortization	102		102		106		(197)		(365)		(365)
Net periodic benefit cost	8,757		$	6,367	$	6,636	$	12,615	$	13,314	9,915
Special termination benefit	—		—		3,730		—		—		490
Net periodic benefit cost recognized as expense	$	8,757	$	6,367	$	10,366	$	12,615	$	13,314	$	10,405

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Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Assumptions

The weighted average assumptions used to determine the Company’s benefit costs during the fiscal years below and obligations as of September 30, are as follows:

	Pension								OPEB
	2020		2019			2018			2020		2019			2018
Benefit costs:
Discount rate	3.37/3.35%	(1)	4.36/4.35%		(1)	4.04/4.03%		(1)	3.48/3.44%	(1)	4.38/4.37%		(1)	4.12/4.08%		(1)
Expected asset return	7.25		7.00	%		7.50	%		7.25		7.00	%		7.50	%
Compensation increase	3.00/3.50%	(1)	3.25/3.50%		(1)	3.25/3.50%		(1)	3.00/3.50%	(1)	3.25/3.50%		(1)	3.25/3.50%		(1)
Obligations:
Discount rate	2.95/2.92%	(1)	3.37/3.35%		(1)	4.36/4.35%			3.08/3.03%	(1)	3.48/3.44%		(1)	4.38/4.37%		(1)
Compensation increase	3.00/3.50%	(1)	3.00/3.50%		(1)	3.25/3.50%		(1)	3.00/3.50%	(1)	3.00/3.50%		(1)	3.25/3.50%		(1)

(1)Percentages for represented and nonrepresented plans, respectively.

When measuring its projected benefit obligations, the Company uses an aggregate discount rate at which its obligation could be effectively settled. The Company determines a single weighted average discount rate based on a yield curve comprised of rates of return on a population of high quality debt issuances (AA- or better) whose cash flows (via coupons or maturities) match the timing and amount of its expected future benefit payments. The Company measures its service and interest costs using a disaggregated, or spot rate, approach. The Company applies the duration-specific spot rates from the full yield curve, as of the measurement date, to each year’s future benefit payments, which aligns the timing of the plans’ separate future cash flows to the corresponding spot rates on the yield curve.

Information relating to the assumed HCCTR used to determine expected OPEB benefits as of September 30, and the effect of a 1 percent change in the rate, are as follows:

($ in thousands)	2020		2019		2018
HCCTR	7.6%		7.6%		7.9%
Ultimate HCCTR	4.5%		4.5%		4.5%
Year ultimate HCCTR reached	2026		2026		2024
Effect of a 1 percentage point increase in the HCCTR on:
Year-end benefit obligation	$	49,106	$	49,061	$	36,260
Total service and interest cost	$	2,799	$	2,923	$	2,482
Effect of a 1 percentage point decrease in the HCCTR on:
Year-end benefit obligation	$	(38,844)	$	(38,747)	$	(28,743)
Total service and interest costs	$	(2,151)	$	(2,250)	$	(1,937)

The Company’s investment objective is a long-term real rate of return on assets before permissible expenses that is approximately 5 percent greater than the assumed rate of inflation, as measured by the consumer price index. The expected long-term rate of return is based on the asset categories in which the Company invests and the current expectations and historical performance for these categories.

The mix and targeted allocation of the pension and OPEB plans’ assets are as follows:

	2021		Assets at
	Target		September 30,
Asset Allocation	Allocation		2020		2019
U.S. equity securities	34	%	38	%	37	%
International equity securities	17		18		17
Fixed income	38		39		42
Other assets	11		5		4
Total	100	%	100	%	100	%

The Company adopted the revised mortality assumptions published by the Society of Actuaries for its pension and other postemployment benefit obligations, which reflected increased life expectancies in the U.S. The adoption of the new mortality projection scale, MP-2019 and the Pri-2012 mortality study, did not materially impact the projected benefit obligation for the plans.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following fiscal years:

(Thousands)	Pension		OPEB
2021	$	12,799	$	6,179
2022	$	13,765	$	6,837
2023	$	14,512	$	7,420
2024	$	15,345	$	7,988
2025	$	16,267	$	8,625
2026 - 2030	$	95,969	$	52,480

The Company’s OPEB plans provide prescription drug benefits that are actuarially equivalent to those provided by Medicare Part D. Therefore, under the Medicare Prescription Drug, Improvement and Modernization Act of 2003, the Company qualifies for federal subsidies.

The following estimated subsidy payments are expected to be paid during the following fiscal years:

	Estimated Subsidy
(Thousands)	Payment
2021		$	292
2022		$	316
2023		$	349
2024		$	384
2025		$	420
2026 - 2030		$	2,789

Pension and OPEB assets held in the master trust, measured at fair value, as of September 30, are summarized as follows:

(Thousands)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Total
As of September 2020:	Pension				OPEB
Assets
Money market funds	$	—	$	—	$	15	$	15
Registered Investment Companies:
Equity Funds:
Large Cap Index	95,542		95,542		29,908		29,908
Extended Market Index	21,085		21,085		6,470		6,470
International Stock	56,912		56,912		17,390		17,390
Fixed Income Funds:
Emerging Markets	16,008		16,008		4,958		4,958
Core Fixed Income	—		—		11,146		11,146
Opportunistic Income	—		—		7,128		7,128
Ultra Short Duration	—		—		7,057		7,057
High Yield Bond Fund	26,303		26,303		8,223		8,223
Long Duration Fund	77,036		77,036		—		—
Total assets at in the fair value hierarchy	$	292,886	292,886		$	92,295	92,295
Investments measured at net asset value
Common collective trusts			15,082				4,111
Total assets at fair value			$	307,968			$	96,406

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

(Thousands)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Total
As of September 30, 2019:	Pension				OPEB
Assets
Money market funds	$	—	$	—	$	21	$	21
Registered Investment Companies:
Equity Funds:
Large Cap Index	89,374		89,374		25,474		25,474
Extended Market Index	16,548		16,548		5,036		5,036
International Stock	49,929		49,929		14,564		14,564
Fixed Income Funds:
Emerging Markets	15,794		15,794		4,764		4,764
Core Fixed Income	—		—		10,570		10,570
Opportunistic Income	—		—		6,365		6,365
Ultra Short Duration	—		—		6,340		6,340
High Yield Bond Fund	24,328		24,328		7,350		7,350
Long Duration Fund	80,041		80,041		—		—
Total assets at in the fair value hierarchy	$	276,014	276,014		$	80,484	80,484
Investments measured at net asset value
Common collective trusts			12,620				3,442
Total assets at fair value			$	288,634			$	83,926

The Plan had no Level 2 or Level 3 fair value measurements during fiscal 2020 and 2019, and there have been no changes in valuation methodologies as of September 30, 2020. The Plan held assets that are valued using net asset value as a practical expedient, which are excluded from the fair value hierarchy.

The following is a description of the valuation methodologies used for assets measured at fair value:

Money Market funds — Represents bank balances and money market funds that are valued based on the net asset value of shares held at year end.

Registered Investment Companies — Equity and fixed income funds valued at the net asset value of shares held by the plan at year end as reported on the active market on which the individual securities are traded.

Common collective trusts — The NAV for common collective trusts is provided by the trustee and is used as a practical expedient to estimate fair value. The NAV is based on the value of the underlying assets owned by the fund less liabilities.

The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Furthermore, while the Plan believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.

Defined Contribution Plan

The Company offers a Savings Plan to eligible employees. The Company matches 80 percent of participants’ contributions up to 6 percent of base compensation. Represented NJRHS employees, non-represented employees hired on or after October 1, 2009, and NJNG represented employees hired on or after January 1, 2012, are eligible for an employer special contribution of between 3.5 percent and 4.5 percent of base compensation, depending on years of service, into the Savings Plan on their behalf. The amount expensed and contributed for the matching provision of the Savings Plan was $4.5 million in fiscal 2020, $3.9 million in fiscal 2019 and $3.9 million in fiscal 2018. The amount contributed for the employer special contribution of the Savings Plan was $1.6 million in fiscal 2020, $1.3 million in fiscal 2019 and $959,000 in fiscal 2018.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

12. ASSET RETIREMENT OBLIGATIONS

The Company recognizes ARO when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. Accordingly, the Company recognizes ARO related to the costs associated with cutting and capping its main and service natural gas distribution pipelines of NJNG, which is required by New Jersey law when taking such natural gas distribution pipeline out of service. The Company also recognizes ARO related to Clean Energy Ventures’ solar assets when there are decommissioning provisions in Clean Energy Ventures’ lease agreements that require removal of the asset.

Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets. Accretion amounts associated with Clean Energy Ventures’ ARO are recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations.

The following is an analysis of the change in the Company’s ARO for the fiscal years ended September 30:

(Thousands)	2020				2019
	NJNG		NJRCEV		NJNG		NJRCEV
Balance at October 1	$	26,944	$	4,102	$	25,640	$	3,048
Accretion	1,476		196		1,427		150
Additions	—		1,306		135		904
Change in estimated useful life	—		(1,160)		—		—
Change in assumptions	1,104		—		—		—
Retirements	(244)		—		(258)		—
Other	—		—		—		—
Balance at period end	$	29,280	$	4,444	$	26,944	$	4,102

Accretion for the next five years, for the fiscal years ended September 30, is estimated to be as follows:

	Estimated
(Thousands)	Accretion
2021	$	1,717
2022	1,789
2023	1,869
2024	1,948
2025	2,029
Total	$	9,352

13. INCOME TAXES

The income tax benefit from operations for the fiscal years ended September 30, consists of the following:

(Thousands)	2020		2019		2018
Current:
Federal	$	(2,164)	$	10,933	$	(2,848)
State	6,763		3,530		4,563
Deferred:
Federal	28,817		4,103		(40,138)
State	3,400		4,003		7,181
Investment/production tax credits	(322)		(4,129)		(10,990)
Income tax expense (benefit)	$	36,494	$	18,440	$	(42,232)

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

As of September 30, the temporary differences, which give rise to deferred tax assets (liabilities), consist of the following:

(Thousands)	2020		2019
Deferred tax assets
Investment tax credits (1)	$	194,840	$	156,153
	—		—
Federal net operating losses (2)	24,091		24,173
State net operating losses	33,233		25,302
Fair value of derivatives	13,979		9,673
Postemployment benefits	8,544		9,192
Incentive compensation	7,071		7,231
Amortization of intangibles	5,892		4,991
Overrecovered natural gas costs	7,244		—
Other	2,370		7,139
Total deferred tax assets	$	297,264	$	243,854
Less: Valuation allowance	(17,639)		(4,035)
Total deferred tax assets net of valuation allowance	$	279,625	$	239,819
Deferred tax liabilities
Property related items	$	(359,604)	$	(313,246)
Remediation costs	(10,207)		(10,720)
Investments in equity investees	(23,395)		(21,730)
Underrecovered natural gas costs	—		(2,657)
Conservation incentive plan	(5,345)		(942)
Other	(6,639)		(4,776)
Total deferred tax liabilities	$	(405,190)	$	(354,071)
Total net deferred tax liabilities	$	(125,565)	$	(114,252)

(1)Includes $898,000 and $2 million for NJNG for fiscal 2020 and 2019, respectively, which is being amortized over the life of the related assets.

(2)See discussion of federal net operating loss utilization in the Other Tax Items section of this note.

A reconciliation of the U.S. federal statutory rate to the effective rate from operations for the fiscal years ended September 30, is as follows:

(Thousands)	2020			2019			2018
Statutory income tax expense	$	41,896		$	29,898		$	45,961
Change resulting from:
Investment/production tax credits	(322)			(4,129)			(10,990)
Cost of removal of assets placed in service prior to 1981	(5,362)			(6,349)			(5,829)
AFUDC equity	(4,933)			(2,313)			(2,117)
State income taxes, net of federal benefit	11,965			6,262			7,322
NJ Unitary method change	(15,345)			—			—
Valuation allowance	13,604			—			—
Tax Act - utility excess deferred income taxes amortized (1)	(3,573)			(3,573)			(1,786)
Tax Act - nonutility excess deferred income taxes (1)	—			—			(59,627)
Tax Act - utility excess deferred income taxes refunded to customers (1)	—			—			(14,323)
Other	(1,436)			(1,356)			(843)
Income tax expense (benefit)	$	36,494		$	18,440		$	(42,232)
Effective income tax rate (2) (3)	18.3		%	14.0		%	(23.9)		%

(1)For a more detailed description, see The Tax Act section of this note.

(2)The U.S. federal statutory rate was 21 percent for both fiscal 2020 and 2019 and 24.5 percent for fiscal 2018.

(3)The effective tax rate without the impact of the Tax Act would have been 12.4 percent for fiscal 2018.

The Company and one or more of its subsidiaries files or expects to file income and/or franchise tax returns in the U.S. Federal jurisdiction and in the states of Colorado, Connecticut, Delaware, Louisiana, Maryland, New Jersey, North Carolina, Pennsylvania, Texas, Mississippi and Virginia. The Company neither files in, nor believes it has a filing requirement in, any foreign jurisdictions other than Canada. Due to certain available tax treaty benefits, the Company incurs no tax liability in Canada.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

The Company’s federal income tax returns through fiscal 2014 have either been reviewed by the IRS, or the related statute of limitations has expired and all matters have been settled. Federal income tax returns for periods subsequent to fiscal 2014 are open to examination or are currently under examination by the IRS. For all periods subsequent to those ended September 30, 2016, the Company’s state income tax returns are statutorily open to examination in all applicable states with the exception of Colorado, New Jersey and Texas. In Colorado, New Jersey and Texas, all periods subsequent to September 30, 2015 are statutorily open to examination.

In May 2019, the Company received a favorable ruling from the IRS regarding a change to its tax method of accounting for the capitalization of certain costs associated with self-constructed property placed in service during fiscal years prior to September 30, 2015. The self-constructed property to which these costs relate is considered qualified energy property as defined under the Internal Revenue Code. As such, the Company is eligible to claim a 30 percent ITC on the increase in the depreciable cost basis of the property through the filing of an amended tax return in the year of change. As a result of the favorable IRS ruling, the Company recorded an addition to its contra asset, which is amortized over the life of the productive assets.

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

As of September 30, 2020, the Company evaluated certain tax benefits that have been recorded in the financial statements and concluded that a portion of the tax benefits are uncertain at this time. As a result, the Company recorded a reserve that is netted against deferred income taxes on the Consolidated Balance Sheets. The tax benefits relate to fiscal tax years open to examination by the IRS and may be subject to subsequent adjustment. The reserve for uncertain tax benefits for the fiscal year ended September 30, is as follows:

(Thousands)	2020		2019
Balance at October 1,	$	4,930	$	—
Additions based on tax positions related to the current fiscal period	—		4,930
Balance at period end	$	4,930	$	4,930

CARES Act

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

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

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

Other Tax Items

As of September 30, 2020 and 2019, the Company has federal income tax net operating losses of approximately $134 million. Federal net operating losses can generally be carried back two years and forward 20 years and will begin to expire in fiscal 2036, with the remainder expiring by 2038. The Company expects to exercise its ability to carryback federal net operating losses to offset taxable income in prior periods.

For the net operating losses it expects to carryback, the Company estimated the portion considered refundable and recorded receivables of approximately $22.8 million as of September 30, 2020 and 2019, as a component of other noncurrent assets on the Consolidated Balance Sheets. Upon filing amended federal income tax returns to carryback its remaining federal net operating losses totaling $24.1 million, the Company will reduce its taxable income in those periods and recapture federal investment tax credits of the same amount that were previously utilized to offset taxable income.

In addition, as of September 30, 2020 and 2019, the Company has tax credit carryforwards of approximately $195.2 million and $154.2 million, respectively, which each have a life of 20 years. When the Company carries back the federal net operating losses noted above, it expects to recapture investment tax credits totaling $24.1 million. These recaptured tax credits are in addition to the $195.2 million and will be carried forward to offset future taxable income. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2034.

As of September 30, 2020 and 2019, the Company has state income tax net operating losses of approximately $487.7 million and $340 million, respectively. These state net operating losses have varying carry-forward periods dictated by the state in which they were incurred; these state carry-forward periods range from seven to 20 years and would begin to expire in fiscal 2021, with the majority expiring after 2035. The Company expects to utilize this entire carryforward, other than as described below.

On February 7, 2019, Clean Energy Ventures finalized the sale of its remaining wind assets. As a result of the sale, it is more likely than not that certain state net operating loss carryforwards will not be realizable prior to their expiration and recorded a valuation allowance related to state net operating loss carryforwards in Montana, Iowa and Kansas.

As a result of changes to filing requirements in the State of New Jersey that require tax returns filed for periods ending on or after July 31, 2019, be filed on a combined basis when part of an affiliated group, the Company recorded a benefit from income taxes, resulting from the re-measurement of deferred income tax attributes. The Company also evaluated its New Jersey state net operating loss carryforwards on a post-apportionment basis and determined it is more likely than not that a portion of these net operating loss carryforwards may not be realizable prior to their expiration. As a result, the Company recorded a valuation allowance associated with New Jersey state net operating loss carryforwards.

As of September 30, 2020 and 2019, the Company had a valuation allowance of $17.6 million and $4 million related to state net operating loss carryforwards.

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 will decline to 26 percent for property under construction during 2020, and to 22 percent for property under construction during 2021. For any property that is under construction before 2022, but not placed in service before 2024, the ITC will be reduced to 10 percent.

The Tax Act

On December 22, 2017, the President signed into law the Tax Act. The law made several changes to the Internal Revenue Code of 1986, as amended, the most impactful to the Company of which was a reduction in the federal corporate income tax rate from 35 percent to 21 percent that became effective January 1, 2018. Since the Company's fiscal year end is September 30, it is required by the Internal Revenue Code to calculate a statutory rate based upon the federal tax rates in effect before and after the effective date of the change in the taxable year that includes the effective date. Accordingly, the Company applied a federal statutory tax rate of 24.5 percent during fiscal 2018 and as of October 1, 2018, used the enacted rate of 21 percent. As a result of the changes associated with the Tax Act during fiscal 2019, the Company recognized a tax benefit of $59.6 million.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

As a result of the changes associated with the Tax Act, NJNG recorded a decrease in its net deferred tax liability of $228.4 million, which included $164.3 million for the revaluation of its deferred income taxes and $64.1 million for the accounting of the income tax effects on the revaluation of those deferred income taxes. These amounts were recorded as a regulatory liability on the Consolidated Balance Sheets. On May 22, 2018, the BPU approved a refund of $31 million, which included approximately $20.1 million of the initial revaluation of excess deferred income taxes, $9 million for the overcollection of taxes from customers from January 1, 2018 through March 31, 2018, and interest on the overcollected taxes at the Company's short-term debt rate. These credits were returned to customer accounts in June 2018.

During fiscal 2018, NJNG credited approximately $17 million to income tax (benefit) provision on the Consolidated Statements of Operations, which includes $14.3 million attributable to the remeasurement of deferred income taxes, $1.8 million for the amortization of excess deferred income taxes primarily related to timing differences associated with utility plant depreciation and $880,000 related to the revaluation of deferred income taxes not included in base rates. As of September 30, 2020, the regulatory liability included excess deferred income taxes of $195 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles.

14. LEASES

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and leased 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. The Company’s land leases and office equipment 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. For more information on the adoption of ASC 842, Leases, see Note 2. Summary of Significant Accounting Policies.

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. These variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use asset and lease 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.

The Company’s solar land lease terms are primarily between 15 and 35 years, which includes options to extend the terms for multiple additional 5 to 10 years each. The Company’s office leases vary in duration, ranging from 1 to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of 7 years with purchase options available prior to the end of the 7 year term. Equipment leases include general office equipment that also vary in duration, most are for a term of 5 years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The expense related to the leases subject to the short-term lease recognition exemption are recognized on a straight-line basis, with such amounts disclosed in the financial statement notes below.

The Company has lease agreements with lease and nonlease components and has elected the practical expedient to combine lease and nonlease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not significant to the Company. The Company’s lease agreements do not contain any

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material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

The following table presents the Company's lease costs included in the Consolidated Statements of Operations for the fiscal year ended September 30:

(Thousands)	Income Statement Location	2020
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	5,007
Interest on lease liabilities	Interest expense, net of capitalized interest	1,511
Total finance lease cost		6,518
Operating lease cost	Operation and maintenance, net of capitalized costs	$	6,404
Short-term lease cost	Operation and maintenance	1,041
Variable lease cost	Operation and maintenance	1,025
Total lease cost		$	14,988

The following table presents supplemental cash flow information related to leases for the fiscal year ended September 30:

(Thousands)	2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	8,804
Operating cash flows from finance leases	$	1,189
Financing cash flows from finance leases	$	6,985

Assets obtained or modified through amendments in exchange for operating lease liabilities during fiscal 2020 were $76.6 million. Assets obtained or modified through amendments in exchange for finance lease liabilities during fiscal 2020, were $49.7 million.

The following table presents the balance and classifications of our right of use assets and lease liabilities included in the Consolidated Balance Sheets for the fiscal year ended September 30:

(Thousands)	Balance Sheet Location	2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	131,769
Finance lease assets	Utility plant	71,085
Total lease assets		$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	6,724
Finance lease liabilities	Current maturities of long-term debt	10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	95,030
Finance lease liabilities	Long-term debt	63,743
Total lease liabilities		$	175,913

As of September 30, 2020, the weighted average remaining lease term for the operating and finance leases is 25.5 and 11.5 years, respectively. The weighted average discount rate used in the valuation of the operating and finance lease liabilities and right-of-use assets over the remaining lease term is 3.18 percent and 2.5 percent, respectively.

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The following table presents the Company's maturities of lease liabilities as of September 30, 2020:

(Thousands)	Operating Leases		Finance Leases
2021	$	6,706	$	54,992
2022	6,634		6,004
2023	6,590		4,622
2024	6,210		5,279
2025	5,646		3,396
Thereafter	122,085		2,324
Total future lease payments	153,871		76,617
Less: Liability accretion	(52,117)		(2,458)
Total lease liability	$	101,754	$	74,159

The following table reflects the Company's future minimum lease payments due under non-cancelable operating leases for continuing operations as of September 30, 2019, under ASC 840 and is being presented for comparative purposes. These commitments relate principally to commercial solar land leases, equipment and real property leases, including land and office facility leases, natural gas meters and office equipment.

(Thousands)	Operating Leases		Finance Leases
2020	$	4,411	$	11,707
2021	$	4,698	$	6,603
2022	$	4,609	$	7,494
2023	$	4,579	$	3,995
2024	$	4,199	$	4,652
Thereafter	$	54,405	$	4,173

On August 14, 2020, the Company entered into a partial termination agreement of its lease contracts associated with its natural gas cavern storage. As a result of the partial termination, the Company paid $28.5 million to the lease owners receiving in return a 50 year non-compete agreement. The Company treated these Leaf River lease arrangements as one combined contract and its termination was recognized as remeasurement of the remaining lease assets that will be amortized over the remaining part of the lease lives.

15. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through October 2036, for the supply, transportation and storage of natural gas. These contracts include annual fixed charges of approximately $124.7 million at current contract rates and volumes, which are recoverable through BGSS.

For the purpose of securing storage and pipeline capacity, our Energy Services segment enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by Energy Services to maintain the ability to access such natural gas storage or pipeline capacity, during a fixed time period, which generally ranges from one to 10 years. Demand charges are established by interstate storage and pipeline operators and are regulated by FERC. These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and/or transport natural gas utilizing their respective assets.

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Commitments as of September 30, 2020, for natural gas purchases and future demand fees for the next five fiscal year periods, are as follows:

(Thousands)	2021		2022		2023		2024		2025		Thereafter
Energy Services:
Natural gas purchases	$	151,270	$	1,600	$	—	$	—	$	—	$	—
Storage demand fees	21,857		13,028		8,632		3,748		2,488		942
Pipeline demand fees	76,462		53,451		29,736		22,687		17,110		36,527
Sub-total Energy Services	$	249,589	$	68,079	$	38,368	$	26,435	$	19,598	$	37,469
NJNG:
Natural gas purchases	$	4,377	$	—	$	—	$	—	$	—	$	—
Storage demand fees	36,096		32,122		20,303		12,768		6,830		3,530
Pipeline demand fees	88,564		131,578		107,614		85,118		79,609		552,465
Sub-total NJNG	$	129,037	$	163,700	$	127,917	$	97,886	$	86,439	$	555,995
Total	$	378,626	$	231,779	$	166,285	$	124,321	$	106,037	$	593,464

As of September 30, 2020, the Company’s future minimum lease payments under various operating leases will not be more than $1.4 million annually for the next five years and $73,000 in the aggregate for all years thereafter.

Guarantees

As of September 30, 2020, there were NJR guarantees covering approximately $258 million of Energy Services’ natural gas purchases and demand fee commitments not yet reflected in accounts payable on the Consolidated Balance Sheets.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of certain former MGP sites, dating back to gas operations in the late 1800s and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the NJDEP, and participating in various studies and investigations by outside consultants, to determine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action, where warranted, under NJDEP regulations.

NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester, Toms River, and Freehold, New Jersey, collectively, the "former MGP sites", including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future expenditures at the former MGP sites for which it is responsible, including potential liabilities for further and continued natural resource damages, may be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites. As we have not yet completed the remedial investigation of the site, the total amount of potential costs of all remedial actions at the MGP site in Freehold, New Jersey, cannot be reasonably estimated at this time.

The estimated total future expenditures for all former MGP sites will range from approximately $143.1 million to $181.7 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, the Company accrues at the lower end of the range. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Consolidated Balance Sheets of $150.6 million as of September 30, 2020 and $131.1 million as of September 30, 2019, based on the most likely amount. The remediation liability at September 30, 2020 includes adjustments for actual expenditures during fiscal 2020. 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. As of September 30, 2019, costs associated with preliminary assessment activities were considered immaterial and included as a component of NJNG’s annual SBC application to recover remediation expenses. 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 is included in the MGP

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remediation liability and corresponding regulatory asset on the Consolidated Balance Sheet at September 30, 2020. NJNG will continue to gather information to determine whether the obligation exists to undertake remedial action.

NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. On September 9, 2020,the BPU approved NJNG's an increase in the RAC, which increased the annual recovery from $8.5 million to $9.7 million and is effective October 1, 2020. As of September 30, 2020, $36.5 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Consolidated Balance Sheets. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination.

General

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

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

16. COMMON STOCK EQUITY

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

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

On September 18, 2020, the Company amended our forward sale agreements to extend the maturity date of such forward sales agreements from September 30, 2020 to September 10, 2021. As of September 30, 2020, if the Company elected to net settle the forward sale agreement, the Company would receive approximately $14.3 million under a cash settlement or would receive 543,150 common shares under a net share settlement.

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

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17. 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 storage and transportation 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:

(Thousands)
Fiscal Years Ended September 30,	2020		2019		2018
Operating revenues
Natural Gas Distribution
External customers	$	729,923	$	710,793	$	731,865
Clean Energy Ventures
External customers	102,617		98,099		71,375
Energy Services
External customers (1)	1,029,303		1,734,553		2,064,477
Intercompany	1,116		8,238		48,327
Storage and Transportation
External customers (1)	42,015		—		—
Intercompany	2,713		—		—
Subtotal	1,907,687		2,551,683		2,916,044
Home Services and Other
External customers	49,810		48,600		47,392
Intercompany	1,207		2,302		2,665
Eliminations	(5,036)		(10,540)		(50,992)
Total	$	1,953,668	$	2,592,045	$	2,915,109
Depreciation and amortization
Natural Gas Distribution	$	71,883	$	57,980	$	53,208
Clean Energy Ventures	25,329		22,376		22,747
Energy Services (2)	123		118		76
Storage and Transportation	9,293		6		6
Subtotal	106,628		80,480		76,037
Home Services and Other	1,032		914		780
Eliminations	(292)		(285)		(246)
Total	$	107,368	$	81,109	$	76,571
Interest income (3)
Natural Gas Distribution	$	538	$	994	$	614
Clean Energy Ventures	240		—		—
Energy Services	99		78		240
Storage and Transportation	3,510		4,000		3,374
Subtotal	4,387		5,072		4,228
Home Services and Other	8,633		1,942		1,476
Eliminations	(10,061)		(5,391)		(5,090)
Total	$	2,959	$	1,623	$	614

(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 Consolidated Statements of Operations.

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

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(Thousands)
Fiscal Years Ended September 30,	2020		2019		2018
Interest expense, net of capitalized interest
Natural Gas Distribution	$	30,975	$	26,134	$	25,299
Clean Energy Ventures	20,253		14,846		18,320
Energy Services	3,276		5,205		3,945
Storage and Transportation	13,124		2,185		1,667
Subtotal	67,628		48,370		49,231
Home Services and Other	10,327		1,535		7
Eliminations	(10,358)		(2,823)		(2,952)
Total	$	67,597	$	47,082	$	46,286
Income tax provision (benefit)
Natural Gas Distribution	$	27,021	$	9,434	$	(1,910)
Clean Energy Ventures	11,034		7,270		(68,379)
Energy Services	(3,615)		(1,573)		24,996
Storage and Transportation	4,247		2,254		(8,548)
Subtotal	38,687		17,385		(53,841)
Home Services and Other	(2,478)		1,428		11,944
Eliminations	285		(373)		(335)
Total	$	36,494	$	18,440	$	(42,232)
Equity in earnings of affiliates
Storage and Transportation	$	15,903	$	15,832	$	16,165
Eliminations	(1,592)		(2,204)		(3,157)
Total	$	14,311	$	13,628	$	13,008
Net financial earnings (loss)
Natural Gas Distribution	$	126,902	$	78,062	$	84,048
Clean Energy Ventures	22,111		31,903		73,426
Energy Services	(7,873)		2,918		60,378
Storage and Transportation	18,311		14,689		24,367
Subtotal	159,451		127,572		242,219
Home Services and Other	5,784		1,911		(3,829)
Eliminations	98		(93)		(327)
Total	$	165,333	$	129,390	$	238,063
Capital expenditures
Natural Gas Distribution	$	290,040	$	345,004	$	254,523
Clean Energy Ventures	133,841		157,828		123,421
Storage and Transportation	20,998		20,616		5,431
Subtotal	444,879		523,448		383,375
Home Services and Other	3,230		2,484		1,213
Total	$	448,109	$	525,932	$	384,588
Investments in equity investees
Storage and Transportation	$	2,117	$	4,102	$	16,151
Total	$	2,117	$	4,102	$	16,151

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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:

(Thousands)	2020		2019		2018
Consolidated net financial earnings	$	165,333	$	129,390	$	238,063
Less:
Unrealized (gain) loss on derivative instruments and related transactions	(9,644)		2,881		26,770
Tax effect	2,296		(711)		(4,512)
Effects of economic hedging related to natural gas inventory	12,690		4,309		(22,570)
Tax effect	(3,016)		(1,024)		7,362
Consolidated net income	$	163,007	$	123,935	$	231,013

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. Additionally, realized derivative gains and losses are also included in current-period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical natural gas flows. Included in the tax effects are current and deferred income tax expense corresponding with the non-GAAP measure. Also included in the tax effects during fiscal 2018, are the impacts of the Tax Act and resulting revaluation of the deferred income taxes that arose from derivative and hedging activity as measured under NFE. The revaluation caused the effective tax rate on reconciling items to differ from the statutory rate in effect for the year. The Company also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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

(Thousands)	2020		2019		2018
Assets at end of period:
Natural Gas Distribution	$	3,531,477	$	3,064,309	$	2,663,054
Clean Energy Ventures (1)	814,277		694,439		740,704
Energy Services	244,836		290,847		396,852
Storage and Transportation	844,799		240,955		242,069
Subtotal	5,435,389		4,290,550		4,042,679
Home Services and Other	138,375		104,411		114,732
Intercompany assets (2)	(257,287)		(237,019)		(171,107)
Total	$	5,316,477	$	4,157,942	$	3,986,304

(1)Includes assets held for sale of $206.9 million for September 30, 2018.

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

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18. 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 September 30, 2020, Energy Services has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2020.

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

Demand fees, net of eliminations, associated with Steckman Ridge during the fiscal years ended September 30, are as follows:

(Thousands)	2020		2019		2018
Natural Gas Distribution	$	5,900	$	5,814	$	5,730
Energy Services	183		2,134		2,775
Total	$	6,083	$	7,948	$	8,505

The following table summarizes demand fees payable to Steckman Ridge as of September 30:

(Thousands)	2020		2019
Natural Gas Distribution	$	775	$	775
Energy Services	16		15
Total	$	791	$	790

NJNG and Energy Services have entered into various asset management agreements, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. As of September 30, 2020, NJNG and Energy Services had three asset management agreements with expiration dates ranging from October 31, 2020 through October 31, 2021.

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

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

19. ACQUISITIONS AND DISPOSITIONS

Acquisitions

Adelphia Gateway

On January 13, 2020, Adelphia Gateway, an indirect wholly-owned subsidiary of NJR, acquired all of Talen’s membership interests in IEC, an existing 84-mile pipeline in southeastern Pennsylvania, including related assets and rights of way, for a base purchase price of $166 million. In November 2017, the Company made an initial payment of $10 million towards the base purchase price, which was included in other noncurrent assets on the Consolidated Balance Sheets. The remaining purchase price of $156 million was paid upon the close of the acquisition of the related assets. As additional consideration, Adelphia Gateway will pay Talen specified amounts of up to $23 million contingent upon the achievement of certain regulatory approvals and binding natural gas capacity commitments. On December 20, 2019, FERC issued Adelphia Gateway’s Certificate of Public Convenience and Necessity. Adelphia Gateway has agreed to provide firm natural gas transportation service for 10 years following the closing to two power generators owned by affiliates of Talen that are currently served by the pipeline.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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

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

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

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

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

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

Leaf River

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

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

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

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

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

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

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

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

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

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

Dispositions

Clean Energy Ventures

On June 1, 2018, Clean Energy Ventures completed the sale of its membership interest in its 9.7 MW wind farm in Two Dot, Montana to NorthWestern Energy for a total purchase price of $18.5 million. The transaction generated a pre-tax gain of approximately $951,000 which is recognized as a reduction to O&M on the Consolidated Statements of Operations.

On February 7, 2019, Clean Energy Ventures finalized the sale of its remaining wind assets to a subsidiary of Skyline Renewables LLC for a total purchase price of $208.6 million. The transaction generated a pre-tax gain of $645,000, which was recognized as a reduction to O&M expense on the Consolidated Statements of Operations.

Energy Services

On February 28, 2018, NJR sold all of the issued and outstanding shares of capital stock of NJRRS, which was a component of the Energy Services segment. The Company received $9.5 million in cash and a natural gas swap contract with a fair value of $14.6 million, which was recorded in derivatives, at fair value on the Consolidated Balance Sheets. The sale generated a pre-tax gain of $3.7 million, which was recognized as a reduction to O&M on the Consolidated Statements of Operations.

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New Jersey Resources Corporation

Part II

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)                                                        

20. SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)

A summary of financial data for each quarter of fiscal 2020 and 2019 follows. Due to the seasonal nature of the Company’s businesses, quarterly amounts vary significantly during the fiscal year. In the opinion of management, the information furnished reflects all adjustments necessary for a fair presentation of the results of the interim periods.

	First		Second		Third		Fourth
(Thousands, except per share data)	Quarter		Quarter		Quarter		Quarter
2020
Operating revenues	$	615,036	$	639,614	$	298,974	$	400,044
Operating income (loss)	$	104,618	$	98,483	$	(16,847)	$	42,655
Net income (loss)	$	75,752	$	73,846	$	(19,298)	$	32,707
Earnings (loss) per share (1)
Basic	$0.82		$0.78		$(0.20)		$0.34
Diluted	$0.82		$0.77		$(0.20)		$0.34
2019
Operating revenues	$	811,767	$	866,255	$	434,942	$	479,081
Operating income (loss) (2)	$	91,273	$	79,606	$	(1,372)	$	(4,951)
Net income (loss)	$	75,371	$	73,671	$	(13,080)	$	(12,027)
Earnings (loss) per share (1)
Basic	$0.87		$0.83		$(0.15)		$(0.16)
Diluted	$0.87		$0.83		$(0.15)		$(0.17)

(1)The sum of quarterly amounts may not equal the annual amounts due to rounding.

(2)Quarterly amounts have been reclassified to conform to the current period presentation due to the adoption of ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits. See Note 2. Summary of Significant Accounting Policies.

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XML

Cover Page	Sep. 24, 2021
Cover [Abstract]
Document Type	8-K
Document Period End Date	Sep. 24, 2021
Entity Registrant Name	NEW JERSEY RESOURCES CORPORATION
Entity Incorporation, State or Country Code	NJ
Entity File Number	001-08359
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
Written Communications	false
Soliciting Material	false
Pre-commencement Tender Offer	false
Pre-commencement Issuer Tender Offer	false
Title of 12(b) Security	Common Stock - $2.50 par value
Trading Symbol	NJR
Security Exchange Name	NYSE
Entity Emerging Growth Company	false
Entity Central Index Key	0000356309
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY

XML

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
OPERATING REVENUES
Utility	$ 729,923	$ 710,793	$ 731,865
Nonutility	1,223,745	1,881,252	2,183,244
Total operating revenues	1,953,668	2,592,045	2,915,109
Natural gas purchases:
Related parties	6,083	7,948	8,505
Operation and maintenance	278,143	268,141	315,215
Regulatory rider expenses	34,529	33,937	38,969
Depreciation and amortization	107,368	81,109	76,571
Total operating expenses	1,724,759	2,427,489	2,706,097
OPERATING INCOME	228,909	164,556	209,012
Other income, net	23,878	11,273	13,047
Interest expense, net of capitalized interest	67,597	47,082	46,286
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES	185,190	128,747	175,773
Income tax expense (benefit)	36,494	18,440	(42,232)
Equity in earnings of affiliates	14,311	13,628	13,008
NET INCOME	$ 163,007	$ 123,935	$ 231,013
EARNINGS PER COMMON SHARE
Basic (in dollars per share)	$ 1.72	$ 1.39	$ 2.63
Diluted (in dollars per share)	$ 1.71	$ 1.38	$ 2.62
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic (in shares)	94,798	89,242	87,689
Diluted (in shares)	95,103	89,596	88,315
Utility
Natural gas purchases:
Gas purchases	$ 275,831	$ 320,256	$ 276,005
Nonutility
Natural gas purchases:
Gas purchases	$ 1,022,805	$ 1,716,098	$ 1,990,832

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Net income	$ 163,007	$ 123,935	$ 231,013
Other comprehensive (loss) income, net of tax:
Unrealized (loss) on investments in equity securities, net of tax of $0, $0 and $6,973, respectively	0	0	(19,245)
Reclassifications of losses to net income on investments in equity securities, net of tax of $0, $0 and $(858), respectively	0	0	11,647
Reclassifications of losses to net income on derivatives designated as hedging instruments, net of tax of $(32), $0 and $0, respectively	108	0	0
Loss on derivatives designated as hedging instruments, net of tax of $3,203, $0 and $0, respectively	(10,505)	0	0
Adjustment to postemployment benefit obligation, net of tax of $567, $6,106, and $(573), respectively	(2,131)	(15,731)	1,520
Other comprehensive (loss)	(12,528)	(15,731)	(6,078)
Comprehensive income	$ 150,479	$ 108,204	$ 224,935

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Tax on unrealized gain (loss) on available for sale securities	$ 0	$ 0	$ 6,973
Tax on reclassifications of available for sale securities	0	0	(858)
Tax on reclassifications of losses to net income on derivatives	(32)	0	0
Tax on loss on deriviatives	3,203	0	0
Tax on adjustment to postemployment benefit obligation	$ 567	$ 6,106	$ (573)

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CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 163,007	$ 123,935	$ 231,013
Adjustments to reconcile net income to cash flows from operating activities
Unrealized gain on derivative instruments	(9,644)	2,881	26,770
Gain on sale of available for sale securities	0	(1,567)	(5,332)
Gain on sale of businesses	0	(645)	(4,663)
Depreciation and amortization	107,368	81,109	76,571
Noncash lease expense	3,851	0	0
Amortization of acquired wholesale energy contracts	4,924	8,424	18,222
Allowance for equity used during construction	(17,053)	(6,492)	(5,531)
Allowance for doubtful accounts	2,238	2,387	2,579
Deferred income taxes	34,346	(2,822)	27,143
Deferred income tax benefit due to tax legislation	0	0	(75,736)
Equivalent value of ITCs recognized on equipment financing	(6,482)	(6,482)	0
Manufactured gas plant remediation costs	(7,651)	(13,878)	(16,171)
Equity in earnings, net of distributions received from equity investees	(5,848)	(4,156)	(1,725)
Cost of removal - asset retirement obligations	(245)	(258)	(298)
Contributions to postemployment benefit plans	(9,032)	(8,157)	(6,359)
Tax benefit of delivered shares from stock based compensation	647	1,290	2,950
Changes in:
Components of working capital	(8,096)	(27,759)	97,004
Other noncurrent assets	(44,129)	8,193	17,860
Other noncurrent liabilities	5,280	38,125	13,989
Cash flows from operating activities	213,481	194,128	398,286
Expenditures for:
Cost of removal	(22,059)	(40,195)	(47,643)
Investments in equity investees	(2,117)	(4,102)	(16,151)
Distributions from equity investees in excess of equity in earnings	1,907	2,428	3,117
Acquisition of assets, net of cash acquired of $5.1 million	(523,647)	0	(10,000)
Proceeds from sale of businesses, net of closing costs	0	205,745	27,916
Proceeds from sale of available for sale securities, net	0	34,484	6,616
Cash flows used in investing activities	(994,025)	(287,377)	(373,090)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Proceeds from long-term debt	660,000	467,900
Proceeds from long-term debt			225,000
Payments of long-term debt	(20,286)	(218,638)
Payments of long-term debt			(165,486)
Proceeds from term loan	350,000	0	0
Payments of term loan	(350,000)	0	0
Proceeds from (payments of)short-term debt, net	99,900	(126,500)	(114,050)
Proceeds from sale leaseback transaction - solar	42,927	0	71,538
Proceeds from sale leaseback transaction - natural gas meters	4,000	9,895	7,820
Payments of common stock dividends	(117,804)	(104,059)	(95,835)
Proceeds from waiver discount issuance of common stock	0	57,391	41,677
Proceeds from issuance of common stock	18,080	16,717	17,136
Proceeds from equity offering	212,900	0	0
Tax withholding payments related to net settled stock compensation	(3,813)	(7,104)	(13,755)
Cash flows from (used in) financing activities	895,904	95,602	(25,955)
Change in cash, cash equivalents and restricted cash	115,360	2,353	(759)
Cash, cash equivalents and restricted cash at beginning of period	4,063	1,710	2,469
Cash, cash equivalents and restricted cash at end of period	119,423	4,063	1,710
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	5,065	63,795	(7,524)
Inventories	(3,254)	14,265	15,464
Recovery of natural gas costs	17,479	(15,733)	30,439
Natural gas purchases payable	(41,326)	(74,031)	51,187
Natural gas purchases payable - related parties	1	(360)	(1)
Prepaid expenses	2,548	(1,193)	2,037
Prepaid and accrued taxes	(2,376)	2,271	1,254
Accounts payable and other	20,390	2,256	40,422
Restricted broker margin accounts	(6,097)	(22,004)	(30,974)
Customers’ credit balances and deposits	(1,182)	(209)	368
Other current assets	656	3,184	(5,668)
Total	8,096	27,759	(97,004)
Cash paid (received) for:
Interest (net of amounts capitalized)	66,146	50,371	44,821
Income taxes	7,594	12,647	5,577
Accrued capital expenditures	19,434	30,725	30,559
Inception gain on natural gas swap contract recognized as non-cash proceeds from sale of business	0	0	14,579
Utility plant
Expenditures for:
Payments to acquire PP&E	(290,040)	(304,809)	(206,880)
Solar and wind equipment
Expenditures for:
Payments to acquire PP&E	(133,841)	(157,828)	(123,421)
Storage and transportation assets and other
Expenditures for:
Payments to acquire PP&E	$ (24,228)	$ (23,100)	$ (6,644)

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CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) $ in Millions	12 Months Ended
	Sep. 30, 2020 USD ($)
Statement of Cash Flows [Abstract]
Cash acquired	$ 5.1

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CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$ 2,800,052	$ 2,625,730
Construction work in progress	379,846	237,011
Nonutility plant and equipment, at cost	1,108,512	576,174
Construction work in progress	176,556	62,492
Total property, plant and equipment	4,464,966	3,501,407
Accumulated depreciation and amortization, utility plant	(601,635)	(585,160)
Accumulated depreciation and amortization, nonutility plant and equipment	(140,562)	(106,614)
Property, plant and equipment, net	3,722,769	2,809,633
CURRENT ASSETS
Cash and cash equivalents	117,012	2,676
Customer accounts receivable:
Billed	134,173	139,263
Unbilled revenues	9,226	6,510
Allowance for doubtful accounts	(7,242)	(6,148)
Regulatory assets	36,530	32,871
Natural gas in storage, at average cost	167,504	169,803
Materials and supplies, at average cost	20,406	14,475
Prepaid expenses	6,639	8,333
Prepaid and accrued taxes	24,301	22,602
Derivatives, at fair value	23,310	25,103
Restricted broker margin accounts	69,444	73,723
Other current assets	21,029	22,395
Total current assets	622,332	511,606
NONCURRENT ASSETS
Investments in equity investees	208,375	200,268
Regulatory assets	527,459	496,637
Operating lease assets	131,769	0
Derivatives, at fair value	3,349	7,426
Intangible assets	10,060	14,611
Software costs	4,707	1,702
Other noncurrent assets	85,657	116,059
Total noncurrent assets	971,376	836,703
Total assets	5,316,477	4,157,942
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares; outstanding September 30, 2020 — 95,949,183; September 30, 2019 — 89,998,788	240,243	226,649
Premium on common stock	491,982	291,331
Accumulated other comprehensive loss, net of tax	(44,315)	(31,787)
Treasury stock at cost and other; shares September 30, 2020 — 148,310; September 30, 2019 — 660,734	8,485	(10,436)
Retained earnings	947,501	906,076
Common stock equity	1,643,896	1,381,833
Long-term debt	2,259,466	1,537,177
Total capitalization	3,903,362	2,919,010
CURRENT LIABILITIES
Current maturities of long-term debt	27,236	21,419
Short-term debt	125,350	25,450
Natural gas purchases payable	95,945	137,271
Natural gas purchases payable to related parties	791	790
Accounts payable and other	141,500	129,724
Dividends payable	31,902	28,122
Accrued taxes	2,717	3,394
Regulatory liabilities	26,188	0
New Jersey Clean Energy Program	15,570	15,468
Derivatives, at fair value	33,865	57,623
Operating lease liabilities	6,724	0
Customers’ credit balances and deposits	25,934	27,116
Total current liabilities	533,722	446,377
NONCURRENT LIABILITIES
Deferred income taxes	138,081	145,504
Deferred investment tax credits	3,332	3,653
Deferred gain	1,035	1,554
Derivatives, at fair value	13,352	18,821
Manufactured gas plant remediation	150,590	131,080
Postemployment employee benefit liability	237,221	246,517
Regulatory liabilities	196,450	202,435
Operating lease liabilities	95,030	0
Asset retirement obligation	33,723	31,046
Other noncurrent liabilities	10,579	11,945
Total noncurrent liabilities	879,393	792,555
Commitments and contingent liabilities
Total capitalization and liabilities	$ 5,316,477	$ 4,157,942

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CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Sep. 30, 2020	Sep. 30, 2019
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 2.50	$ 2.50
Common stock, shares authorized (in shares)	150,000,000	150,000,000
Common stock, shares outstanding (in shares)	95,949,183	89,998,788
Treasury stock at cost and other (in shares)	148,310	660,734

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CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY - USD ($) $ in Thousands		Total	Cumulative Effect, Period of Adoption, Adjustment	Common Stock	Premium on Common Stock	Accumulated Other Comprehensive (Loss) Income	Accumulated Other Comprehensive (Loss) Income Cumulative Effect, Period of Adoption, Adjustment	Treasury Stock And Other	Retained Earnings	Retained Earnings Cumulative Effect, Period of Adoption, Adjustment
Beginning Balance (in shares) at Sep. 30, 2017				86,556,000
Beginning Balance at Sep. 30, 2017		$ 1,114,752		$ 222,258	$ 219,696	$ (3,256)		$ (70,039)	$ 746,093
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		231,013							231,013
Other comprehensive income (loss)		(6,078)				(6,078)
Common stock issued:
Incentive compensation plan (in shares)				561,000
Incentive compensation plan		16,572		$ 1,403	15,169
Dividend reinvestment plan (in shares)	[1]			413,000
Dividend reinvestment plan	[1]	17,094			755			16,339
Waiver discount (in shares)				1,014,000
Waiver discount		41,677		$ 2,535	39,142
Cash dividend declared ($0.3125 per share in 2020, $1.19 per share in 2019, and $1.11 per share in 2018)		(97,579)							(97,579)
Treasury stock and other (in shares)				(251,000)
Treasury stock and other		(22,787)			(14)			(22,773)
Reclassifications of certain income tax effects to retained earnings						(3,276)			3,276
Ending Balance (in shares) at Sep. 30, 2018				88,293,000
Ending Balance at Sep. 30, 2018		1,294,664		$ 226,196	274,748	(12,610)		(76,473)	882,803
Ending Balance (Accounting Standards Update 2016-01) at Sep. 30, 2018	[2]						$ (3,446)			$ 3,446
Ending Balance (Accounting Standards Update 2017-05) at Sep. 30, 2018	[2]		$ 4,970							4,970
Ending Balance (Accounting Standards Update 2014-09) at Sep. 30, 2018	[2]		$ (2,736)							$ (2,736)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		123,935							123,935
Other comprehensive income (loss)		(15,731)				(15,731)
Common stock issued:
Incentive compensation plan (in shares)				182,000
Incentive compensation plan		3,787		$ 453	3,334
Dividend reinvestment plan (in shares)	[1]			351,000
Dividend reinvestment plan	[1]	16,663			2,718			13,945
Waiver discount (in shares)				1,181,000
Waiver discount		57,391			10,531			46,860
Cash dividend declared ($0.3125 per share in 2020, $1.19 per share in 2019, and $1.11 per share in 2018)		(106,342)							(106,342)
Treasury stock and other (in shares)				(8,000)
Treasury stock and other		$ 5,232						5,232
Ending Balance (in shares) at Sep. 30, 2019		89,998,788		89,999,000
Ending Balance at Sep. 30, 2019		$ 1,381,833		$ 226,649	291,331	(31,787)		(10,436)	906,076
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		163,007							163,007
Other comprehensive income (loss)		(12,528)				(12,528)
Common stock issued:
Common stock offering (in shares)				5,333,000
Common stock offering		212,900		$ 13,333	199,567
Incentive compensation plan (in shares)				105,000
Incentive compensation plan		3,772		$ 261	3,511
Dividend reinvestment plan (in shares)	[1]			520,000
Dividend reinvestment plan	[1]	18,157			2,833			15,324
Cash dividend declared ($0.3125 per share in 2020, $1.19 per share in 2019, and $1.11 per share in 2018)		(121,582)							(121,582)
Treasury stock and other (in shares)				(8,000)
Treasury stock and other		$ (1,663)			(5,260)			3,597
Ending Balance (in shares) at Sep. 30, 2020		95,949,183		95,949,000
Ending Balance at Sep. 30, 2020		$ 1,643,896		$ 240,243	$ 491,982	$ (44,315)		$ 8,485	$ 947,501

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

[2] See Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the Accounting Standards Codification section for more details.

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CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Stockholders' Equity [Abstract]
Cash dividends declared per share (in usd per share)	$ 1.27	$ 1.19	$ 1.11

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NATURE OF THE BUSINESS

12 Months Ended

Sep. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

NATURE OF THE BUSINESS

1. NATURE OF THE BUSINESS

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

New Jersey Natural Gas Company provides natural gas utility service to approximately 558,000 retail customers throughout Monmouth, Ocean, Morris, Middlesex and Burlington counties in New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment.

NJR Clean Energy Ventures Corporation, the Company's clean energy subsidiary, comprises the Clean Energy Ventures segment and consists of the Company's capital investments in commercial and residential solar projects.

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

NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, formerly the Midstream segment, invests in energy-related ventures through its subsidiaries. The Company holds a 50 percent ownership interest in Steckman Ridge, located in Pennsylvania and 20 percent ownership interest in PennEast, which are accounted for under the equity method of accounting. The Company also operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River, which was acquired on October 11, 2019 and FERC regulated Adelphia Gateway, which was acquired on January 13, 2020. See Note 19. Acquisitions and Dispositions for more information regarding these acquisitions.

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

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

12 Months Ended

Sep. 30, 2020

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The Consolidated Financial Statements include the accounts of the Company and its wholly-owned subsidiaries. All intercompany accounts and transactions have been eliminated.

Other financial investments or contractual interests that lack the characteristics of a voting interest entity, which are commonly referred to as variable interest entities, are evaluated by the Company to determine if the entity has the power to direct business activities and, therefore, would be considered a controlling interest that the Company would have to consolidate. Based on those evaluations, NJR has determined that it does not have any investments in variable interest entities as of September 30, 2020, 2019 and 2018.

Investments in entities over which the Company does not have a controlling financial interest are either accounted for under the equity method or cost method of accounting.

Use of Estimates

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

The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, a reserve is established if a loss is probable and can be reasonably estimated. 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, a reserve is established at 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 Consolidated Financial Statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the balance sheet date and reported amounts of revenue and expenses during the reporting periods presented. The Company considered the impacts of COVID-19 on the assumptions and estimates used and determined that there have been no material adverse impacts on the Company’s results of operations as of September 30, 2020.

Acquisitions

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

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

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various assumptions and valuation methodologies requiring considerable management judgment. The most significant variables in these valuations are discount rates and the number of years on which to base the cash flow projections, as well as other assumptions and estimates used to determine the cash inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets and related cash flows. The valuation of an acquired business is based on available information at the acquisition date and assumptions that are believed to be reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date. See Note 19. Acquisitions and Dispositions for further information.

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

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

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

Our 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.

Natural Gas Purchases

NJNG’s tariff includes a component for BGSS, which is designed to allow it to recover the cost of natural gas through rates charged to its customers and is typically revised on an annual basis. As part of computing its BGSS rate, NJNG projects its cost of natural gas, net of supplier refunds, the impact of hedging activities and cost savings created by BGSS incentive programs. NJNG subsequently recovers or credits the difference, if any, of actual costs compared with those included in current rates. Any underrecoveries or overrecoveries are either credited to customers or deferred and, subject to BPU approval, reflected in the BGSS rates in subsequent years.

Natural gas purchases at Energy Services are composed of natural gas costs to be paid upon completion of a variety of transactions, as well as realized gains and losses from settled derivative instruments and unrealized gains and losses on the change in fair value of derivative instruments that have not yet settled. Changes in the fair value of derivatives that economically hedge the forecasted purchases of natural gas are recognized in natural gas purchases as they occur.

Demand Fees

For the purpose of securing storage and pipeline capacity in support of their respective businesses, the Energy Services and Natural Gas Distribution segments enter into storage and pipeline capacity contracts, which require the payment of associated demand fees and charges that allow them access to a high priority of service in order to maintain the ability to access storage or pipeline capacity during a fixed time period, which generally ranges from one to 10 years. Many of these demand fees and charges are based on established tariff rates as established and regulated by FERC. These charges represent commitments to pay storage providers and pipeline companies for the priority right to transport and/or store natural gas utilizing their respective assets.

The following table summarizes the demand charges, which are net of capacity releases, and are included as a component of natural gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30:

(Millions)	2020		2019		2018
Energy Services	$	121.8	$	120.4	$	153.0
Natural Gas Distribution	131.9		119.1		92.5
Total	$	253.7	$	239.5	$	245.5

Energy Services expenses demand charges over the term of the service being provided.

The Natural Gas Distribution segment’s costs associated with demand charges are included in its weighted average cost of natural gas. The demand charges are expensed based on NJNG’s BGSS sales and recovered as part of its natural gas commodity component of its BGSS tariff.

Operations and Maintenance Expenses

Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of vehicles, tools and equipment, payments to contractors, utility plant maintenance, amortization of software costs for unregulated entities, customer service, professional fees and other outside services, insurance expense, accretion of cost of removal for future retirements of utility assets and other administrative expenses and are expensed as incurred.

Stock-Based Compensation

Stock-based compensation represents costs related to stock-based awards granted to employees and members of NJR’s Board of Directors. NJR recognizes stock-based compensation based upon the estimated fair value of awards. The recognition period for these costs begins at either the applicable service inception date or grant date and continues throughout the requisite service period. The related compensation cost is recognized as O&M expense on the Consolidated Statements of Operations. See Note 10. Stock-Based Compensation for further information.

Sales Tax Accounting

As a result of the adoption of ASC 606, Revenue from Contracts with Customers, as of October 1, 2018, the Company excludes from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales tax on a net basis in operating revenues on the Consolidated Statements of Operations. Prior to October 1, 2018, sales tax was presented in both operating revenues and operating expenses.

Income Taxes

The Company computes income taxes using the asset and liability method, whereby deferred income taxes are generally determined based on the difference between the financial statement and tax basis of assets and liabilities using enacted tax rates in effect in the years in which the differences are expected to reverse. See Note 13. Income Taxes. In addition, the Company evaluates its tax positions to determine the appropriate accounting and recognition of future obligations associated with unrecognized tax benefits.

The Company invests in property that qualifies for federal ITCs and utilizes the ITCs, as allowed, based on the cost and life of the assets. ITCs at NJNG are deferred and amortized as a reduction to the tax provision over the average lives of the related equipment in accordance with regulatory treatment. ITCs at the unregulated subsidiaries of NJR are recognized as a reduction to the carrying value of the related asset when placed in service. ITCs are recognized in earnings as a reduction to depreciation expense over the productive life of the related property.

Projects placed in service through December 31, 2019, qualified for a 30-percent federal ITC. The credit declines to 26 percent for property under construction during 2020, 22 percent for property under construction during 2021 and 10 percent for any property that is under construction before 2022. The Company has taken steps to preserve the ITC at the higher rate for certain solar projects that are completed after the scheduled reduction in rates, in accordance with IRS guidance on safe harbor determination.

Investments in Equity Investees

The Company accounts for its investments in Steckman Ridge and PennEast using the equity method of accounting where it is not the primary beneficiary, as defined under ASC 810, Consolidation, its respective ownership interests are 50 percent or less and/or it has significant influence over operating and management decisions. The Company’s share of earnings is recognized as equity in earnings of affiliates on the Consolidated Statements of Operations.

Equity method investments are reviewed for impairment when changes in facts and circumstances indicate that the current fair value may be less than the asset’s carrying amount. If the Company determines the decline in the value of its equity method investment is other than temporary, an impairment charge is recorded in an amount equal to the excess of the carrying value of the asset over its fair value.

Property Plant and Equipment

Property, plant and equipment is stated at original cost. Costs include direct labor, materials and third-party construction contractor costs, capitalized interest and certain indirect costs related to equipment and employees engaged in construction. Utility plant and nonutility plant for Adelphia Gateway also includes AFUDC. Upon retirement, the cost of depreciable property, plus removal costs less salvage, is charged to accumulated depreciation with no gain or loss recorded.

Depreciation is computed on a straight-line basis over the useful life of the assets for our nonutility entities, and using rates based on the estimated average lives of the various classes of depreciable property for NJNG. The composite rate of depreciation used for NJNG was 2.65 percent of average depreciable property in fiscal 2020, 2.25 percent in fiscal 2019 and 2.29 percent in fiscal 2018. The Company recorded $107.4 million, $81.1 million and $76.6 million in depreciation expense during fiscal 2020, 2019 and 2018, respectively.

During fiscal 2018 and 2019, the estimated useful lives of commercial solar assets ranged from 15 to 25 years. During the fourth quarter of fiscal 2020, the Company reassessed the estimated useful lives of its commercial solar asset fleet. Based upon this review, the Company concluded that the actual lives of certain commercial solar assets were longer than the estimated useful lives used for depreciation purposes. As a result, effective July 1, 2020, the Company changed its estimates of the useful lives of its solar assets to a range of 15 to 35 years. The effects of this change were considered immaterial to the Consolidated Financial Statements.

Property, plant and equipment was comprised of the following as of September 30:

(Thousands)	Estimated
Property Classifications	Estimated Useful Lives	2020		2019
Distribution facilities	38 to 74 years	$	2,688,885	$	2,419,381
Transmission facilities	35 to 56 years	332,947		330,912
Storage facilities	34 to 47 years	79,922		79,916
Solar property	15 to 35 years	674,930		593,867
Storage and transportation property	5 to 50 years	428,491		28,445
All other property	5 to 35 years	259,791		48,886
Total property, plant and equipment		4,464,966		3,501,407
Accumulated depreciation and amortization		(742,197)		(691,774)
Property, plant and equipment, net		$	3,722,769	$	2,809,633

Within storage and transportation property, base gas is required to maintain the necessary pressure and to allow for efficient operation of the Leaf River storage facility. The base gas is determined to be recoverable and is considered part of the facility and thus presented as a component in property, plant and equipment. This natural gas is not depreciated, as it is expected to be recovered and sold. As of September 30, 2020, the base gas had a cost basis of $5.7 million.

Capitalized and Deferred Interest

NJNG’s base rates include the ability to recover AFUDC on its construction work in progress. For all NJNG construction projects, an incremental cost of equity is recoverable during periods when NJNG’s short-term debt balances are lower than its construction work in progress. For more information on AFUDC treatment with respect to certain accelerated infrastructure projects, see Note 4. Regulation - Infrastructure Programs.

Capitalized amounts associated with the debt and equity components of NJNG’s AFUDC are recorded in utility plant on the Consolidated Balance Sheets. Corresponding amounts for the debt component are recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations.

Adelphia Gateway’s base rates include the ability to recover AFUDC on its construction work in progress. Beginning in the fourth quarter of fiscal 2020, capitalized amounts associated with Adelphia Gateway’s AFUDC are recorded in nonutility plant on the Consolidated Balance Sheets. Corresponding amounts are recorded in other income on the Consolidated Statements of Operations.

Capitalized and deferred interest include the following for the fiscal years ended September 30:

($ in thousands)	2020						2019			2018
	NJNG			Adelphia Gateway			NJNG			NJNG
AFUDC:
Debt	$	5,134		$	1,394		$	3,710		$	1,979
Equity	14,599			2,454			6,492			5,531
Total	$	19,733		$	3,848		$	10,202		$	7,510
Weighted average interest rate	6.79		%	8.28		%	6.35		%	5.94		%

Pursuant to a BPU order, NJNG is permitted to recover carrying costs on uncollected balances related to SBC program costs, which include NJCEP, RAC and USF expenditures. The SBC interest rate changes each September based on the August 31 seven-year constant maturity treasury rate plus 60 basis points. The rate was 1.97 percent, 3.30 percent and 3.41 percent for the fiscal years ended September 30, 2020, 2019 and 2018, respectively. Accordingly, other income included $511,000, $760,000 and $411,000 in the fiscal years ended September 30, 2020, 2019 and 2018, respectively.

Clean Energy Ventures capitalizes interest on the allocation of the costs of debt borrowed for the financing of solar investments. Capitalized amounts are included in nonutility plant and equipment on the Consolidated Balance Sheets.

Cash and Cash Equivalents

Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to escrow balances for utility plant projects, which is recorded in other noncurrent assets on the Consolidated Balance Sheets.

ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, required that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement. The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Consolidated Balance Sheets to the total amounts in the Statements of Cash Flows, as of September 30:

(Thousands)	2020		2019		2018
Balance Sheet
Cash and cash equivalents	$	117,012	$	2,676	$	1,458
Restricted cash in other noncurrent assets	$	2,411	$	1,387	$	252
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	119,423	$	4,063	$	1,710

Loans Receivable

NJNG currently provides loans, with terms ranging from 2 to 10 years, to customers that elect to purchase and install certain energy-efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at fair value on the Consolidated Balance Sheets. The Company recorded $13.7 million and $12.4 million in other current assets and $35.3 million and $38.8 million in other noncurrent assets as of September 30, 2020 and 2019, respectively, on the Consolidated Balance Sheets, related to the loans. If NJNG determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of September 30, 2020 and 2019, the Company has not recorded any impairments for SAVEGREEN loans.

Regulatory Assets & Liabilities

Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment.

Our Natural Gas Distribution segment maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and in accordance with the ASC 980, Regulated Operations. As a result of the impact of the ratemaking process and regulatory actions of the BPU, NJNG is required to recognize the economic effects of rate regulation. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of NJNG’s regulatory assets and liabilities.

In January 2020, NJR acquired Adelphia Gateway an existing 84-mile pipeline in southeastern Pennsylvania, which maintains its accounts in accordance with the FERC Uniform System of Accounts and in accordance with the ASC 980, Regulated Operations. Accordingly, Adelphia Gateway capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of Adelphia Gateway’s regulatory assets and liabilities.

Natural Gas in Storage

Natural gas in storage is reflected at average cost on the Consolidated Balance Sheets and represents natural gas and LNG that will be utilized in the ordinary course of business. The following table summarizes natural gas in storage, at average cost by company, as of September 30:

	2020				2019
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	110,037	27.2		$	117,413	27.0
Energy Services		57,352		34.3		52,390		25.6
Storage and Transportation		115		0.02		—		—
Total		$	167,504	61.52		$	169,803	52.6

Derivative Instruments

The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts and interest rate contracts, as well as its physical commodity contracts related to the purchase and sale of natural gas at Energy Services, as derivatives, and therefore recognizes them at fair value on the Consolidated Balance Sheets. The Company’s unregulated subsidiaries record changes in the fair value of their financial commodity derivatives in natural gas purchases and changes in

the fair value of their physical forward contracts in natural gas purchases or operating revenues, as appropriate, on the Consolidated Statements of Operations. Ineffective portions of the cash flow hedges are recognized immediately in earnings.

The ASC 815, Derivatives and Hedging also provides for a NPNS scope exception for qualifying physical commodity contracts for which physical delivery is probable and the quantities delivered are expected to be used or sold over a reasonable period of time in the normal course of business. Effective January 1, 2016, the Company prospectively applies this normal scope exception on a case-by-case basis to physical commodity contracts at NJNG and PPAs at Clean Energy Ventures. When applied, it does not account for these contracts until the contract settles and the related underlying natural gas or power is delivered. Gains and/or losses on NJNG’s derivatives used to economically hedge its regulated natural gas supply obligations, as well as its exposure to interest rate variability, are recoverable through its BGSS, a component of its tariff. Accordingly, the offset to the change in fair value of these derivatives is recorded as a regulatory asset or liability on the Consolidated Balance Sheets. See Note 5. Derivative Instruments for additional details regarding natural gas trading and hedging activities.

Fair values of exchange-traded instruments, including futures and swaps, are based on unadjusted, quoted prices in active markets. The Company’s non-exchange-traded financial instruments, foreign currency derivatives, over-the-counter physical commodity contracts at Energy Services and interest rate contracts are valued using observable, quoted prices for similar or identical assets when available. In establishing the fair value of contracts for which a quoted basis price is not available at the measurement date, management utilizes available market data and pricing models to estimate fair values. Fair values are subject to change in the near term and reflect management’s best estimate based on a variety of factors. Estimating fair values of instruments that do not have quoted market prices requires management’s judgment in determining amounts that could reasonably be expected to be received from, or paid to, a third party in settlement of the instruments. These amounts could be materially different from amounts that might be realized in an actual sale transaction.

During fiscal 2020, the Company entered into treasury lock transactions to fix the benchmark treasury rate associated with debt issuances for NJNG and NJR that occurred during the fiscal year. Settlement of the NJNG treasury locks resulted in a loss, which was recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the debt as a component of interest expense on the Consolidated Statements of Operations. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks resulted in a loss, which was recorded within OCI and will be amortized in earnings over the life of the debt as a component of interest expense on the Consolidated Statements of Operations. Amounts recognized in interest expense for NJNG and NJR related to the amortization of the loss on treasury lock transactions totaled $50,000 and $108,000, respectively, as of September 30, 2020.

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 of the respective software.

The following table presents the software costs included in the Consolidated Financial Statements, as of September 30:

(Thousands)	2020		2019
Balance Sheets
Utility plant, at cost	$	13,452	$	—
Construction work in progress	$	—	$	4,778
Nonutility plant and equipment, at cost	$	316	$	—
Accumulated depreciation and amortization, utility plant	$	(279)	$	—
Accumulated depreciation and amortization, nonutility plant and equipment	$	(5)	$	—
Software costs	$	4,707	$	1,702
Statements of Operations
Operation and maintenance (1)	$	6,720	$	9,062
Depreciation and amortization	$	284	$	—

(1)During fiscal 2020, $63,000 was amortized into O&M.

Investments in Equity Securities

Investments in equity securities were carried at fair value on the Consolidated Balance Sheets. For the fiscal year ended September 30, 2018, total unrealized gains and losses associated with equity securities were included as a part of accumulated other comprehensive income, a component of common stock equity, and reclassifications of realized gains or losses out of other comprehensive income into earnings were recorded in other income, net on the Consolidated Statements of Operations, based on average cost. On October 1, 2018, the Company adopted ASU No. 2016-01, an amendment to ASC 825, Financial Instruments. As a result, both realized and unrealized gains and losses were recorded in other income, net on the Consolidated Statements of Operations, based on average cost.

At September 30, 2018, the Company's investments in equity securities were comprised of an investment in DM Common Units, which had a fair value of $32.9 million. On January 28, 2019, Dominion and DM finalized an agreement and plan of merger and each outstanding DM Common Unit was converted into 0.2492 shares of Dominion common stock. This resulted in the conversion of the Company's 1.84 million DM Common Units into approximately 458,000 Dominion common shares. On March 6, 2019, the Company sold its investment in Dominion and received proceeds of approximately $34.5 million. As a result of the sale, the Company recorded total realized gains of $1.6 million in other income, net on the Consolidated Statements of Operations.

Intangible Assets

Finite-lived intangible assets are stated at cost less accumulated amortization. The Company amortizes intangible assets based upon the pattern in which the economic benefits are consumed over the life of the asset unless a pattern cannot be reliably determined, in which case the Company uses a straight-line amortization method. As of September 30, 2020, intangible assets consist primarily of acquired wholesale natural gas energy contracts totaling $10 million. The wholesale natural gas contracts are being amortized based upon expected cash flows over the respective terms of the agreements.

The estimated future amortization expense as of September 30, is as follows:

(Thousands)
2021	$	5,101
2022	$	2,611
2023	$	2,271
2024	$	77

Long-lived Assets

The Company reviews the recoverability of long-lived assets and finite-lived intangible assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable, such as significant adverse changes in regulation, business climate or market conditions, including prolonged periods of adverse commodity and capacity prices. If there are changes indicating that the carrying value of such assets may not be recoverable, an undiscounted cash flows test is performed. If the sum of the expected future undiscounted cash flows is less than the carrying amount of the asset, an impairment loss is recognized by reducing the recorded value of the asset to its fair value. Factors that the Company analyzes in determining whether an impairment in its long-lived assets exists include: a significant decrease in the market price of a long-lived asset; a significant adverse change in the extent in which a long-lived asset is being used in its physical condition; legal proceedings or other contributing factors; significant business climate changes; accumulations of costs in significant excess of the amounts expected; a current-period operating or cash flow loss combined with a history of such events; and current expectations that more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its estimated useful life. During fiscal 2020 and 2019, there were no events or circumstances that indicated that the carrying value of long-lived assets or finite-lived intangibles were not recoverable.

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt. See Note 9. Debt for the total unamortized debt issuance costs that are recorded as a reduction to long-term debt on the Consolidated Balance Sheets.

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 Consolidated Balance Sheets. During fiscal 2020 and 2019, NJNG received $4 million and $9.9 million, respectively, in connection with the sale leaseback of its natural gas meters with terms ranging from seven to 11 years.

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

During fiscal 2020 and 2018, Clean Energy Ventures received proceeds of $42.9 million and $71.5 million, respectively, in connection with the failed sale leaseback of commercial solar assets. The proceeds received were recognized as a financing obligation on the Consolidated Balance Sheets. Clean Energy Ventures did not enter into any sale leaseback transactions for its commercial solar assets during fiscal 2019. Clean Energy Ventures simultaneously entered into agreements to lease the assets back over a term of five- to 15-years. The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from SRECs 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 Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease.

Environmental Contingencies 

Loss contingencies are recorded as liabilities when it is probable a liability has been incurred and the amount of the loss is reasonably estimable in accordance with accounting standards for contingencies. Estimating probable losses requires an analysis of uncertainties that often depend upon judgments about potential actions by third parties. Accruals for loss contingencies are recorded based on an analysis of potential results.

With respect to environmental liabilities and related costs, NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG’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. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries. NJNG will continue to seek recovery of MGP-related costs through the 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. See Note 15. Commitments and Contingent Liabilities for more details.

Pension and Postemployment Plans

The Company has two noncontributory defined pension plans covering eligible employees, including officers. Benefits are based on each employee’s years of service and compensation. The Company’s funding policy is to contribute annually to these plans at least the minimum amount required under the Employee Retirement Income Security Act, as amended, and not more than can be deducted for federal income tax purposes. Plan assets consist of equity securities, fixed-income securities and short-term investments. The Company did not make any discretionary contributions to the pension plans in fiscal 2020, 2019 and 2018, respectively.

The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds. The Company contributed $8.4 million, $7.9 million and $6.2 million in aggregate to these plans in

fiscal 2020, 2019 and 2018, respectively, which is recorded in postemployment employee benefit liability on the Consolidated Balance Sheets. See Note 11. Employee Benefit Plans, for a more detailed description of the Company’s pension and postemployment plans.

Asset Retirement Obligations

The Company recognizes ARO related to the costs associated with cutting and capping NJNG’s main and service natural gas distribution mains, which is required by New Jersey law when taking such natural gas distribution mains out of service. The Company also recognizes ARO associated with Clean Energy Ventures’ solar assets when there are decommissioning provisions in lease agreements that require removal of the asset at the end of the lease term.

ARO are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations. Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets.

Estimating future removal costs requires management to make significant judgments because most of the removal obligations span long time frames and removal may be conditioned upon future events. Asset removal technologies are also constantly changing, which makes it difficult to estimate removal costs. Accordingly, inherent in the estimate of ARO are various assumptions including the ultimate settlement date, expected cash outflows, inflation rates, credit-adjusted risk-free rates and consideration of potential outcomes where settlement of the ARO can be conditioned upon events. In the latter case, the Company develops possible retirement scenarios and assigns probabilities based on management’s reasonable judgment and knowledge of industry practice. Accordingly, ARO are subject to change.

Accumulated Other Comprehensive Income

The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects, as of September 30:

(Thousands)	Investments in Equity Securities		Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2018	$	3,446	$	—	$	(16,056)		$	(12,610)
Other comprehensive income, net of tax
Other comprehensive (loss), before reclassifications, net of tax of $0, $0, $6,557 and $6,557, respectively	—		—		(16,978)			(16,978)
Amounts reclassified from accumulated other comprehensive (loss), net of tax of $0, $0, $(451) and $(451), respectively	—		—		1,247		(1)	1,247
Net current-period other comprehensive income, net of tax of $0, $0, $6,106 and $6,106, respectively	—		—		(15,731)			(15,731)
Reclassifications of certain income tax effects to retained earnings (2)	(3,446)		—		—			(3,446)
Balance at September 30, 2019	$	—	$	—	$	(31,787)		$	(31,787)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $0, $3,203, $1,235, $4,438, respectively	—		(10,505)		(4,882)			(15,387)
Amounts reclassified from accumulated other comprehensive loss, net of tax of $0, $(32), $(668), $(700), respectively	—		108		2,751		(1)	2,859
Net current-period other comprehensive income, net of tax of $0, $3,171, $567, $3,738, respectively	—		(10,397)		(2,131)			(12,528)
Balance at September 30, 2020	$	—	$	(10,397)	$	(33,918)		$	(44,315)

(1)Included in the computation of net periodic pension cost, a component of O&M expense on the Consolidated Statements of Operations. For more details, see Note 11. Employee Benefit Plans.

(2)Due to the adoption of ASU No. 2016-01, an amendment to ASC 825, Financial Instruments. See Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the Accounting Standards Codification section for more details.

Foreign Currency Transactions

The market area of Energy Services includes Canadian delivery points and as a result, Energy Services incurs certain natural gas commodity costs and demand fees denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of natural gas purchases on the Consolidated Statements of Operations. Gains and losses recognized for the fiscal years ended September 30, 2020, 2019 and 2018, are considered immaterial.

Reclassification

Certain prior period amounts have been reclassified to conform to the current period presentation. Amounts related to energy and other taxes have been reclassified to O&M on the Consolidated Statements of Operations. Software costs previously recorded in other non-current assets have been reclassified to utility plant and software costs, and prepaid expenses previously recorded in other current assets have been reclassified on the Consolidated Balance Sheets. Certain amounts related to software costs previously reported in cash flows from operating activities have been reclassified to cash flows used in investing activities and prepaid expenses were reclassified within working capital on the Consolidated Statements of Cash Flows.

Change in Accounting Policy

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

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

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the fiscal years ended September 30, 2020, 2019 and 2018 are as follows:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Depreciation and amortization	$	119,894	(12,526)	$	107,368
Total operating expenses	$	1,737,285	(12,526)	$	1,724,759
Operating income	$	216,383	12,526	$	228,909
Income before income taxes and equity in earnings of affiliates	$	172,664	12,526	$	185,190
Income tax (benefit) expense	$	(6,944)	43,438	$	36,494
Net income	$	193,919	(30,912)	$	163,007
Weighted average shares outstanding
Diluted	95,107		(4)	95,103
Earnings per common share
Basic	$	2.05	(0.33)	$	1.72
Diluted	$	2.04	(0.33)	$	1.71
September 30, 2019
Depreciation and amortization	$	91,730	(10,621)	$	81,109
Total operating expenses	$	2,438,110	(10,621)	$	2,427,489
Operating income	$	153,935	10,621	$	164,556
Income before income taxes and equity in earnings of affiliates	$	118,126	10,621	$	128,747
Income tax (benefit) expense	$	(37,751)	56,191	$	18,440
Net income	$	169,505	(45,570)	$	123,935
Weighted average shares outstanding
Diluted	89,616		(20)	89,596
Earnings per common share
Basic	$	1.90	(0.51)	$	1.39
Diluted	$	1.89	(0.51)	$	1.38
September 30, 2018
Depreciation and amortization	$	85,701	(9,130)	$	76,571
Total operating expenses	$	2,715,227	(9,130)	$	2,706,097
Operating income	$	199,882	9,130	$	209,012
Income before income taxes and equity in earnings of affiliates	$	166,643	9,130	$	175,773
Income tax benefit	$	(53,785)	11,553	$	(42,232)
Net income	$	233,436	(2,423)	$	231,013
Earnings per common share
Basic	$	2.66	(0.03)	$	2.63
Diluted	$	2.64	(0.02)	$	2.62

The cumulative effect of the change in accounting policy on the Unaudited Condensed Consolidated Balance Sheets as of September 30, 2020 and 2019 are as follows:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Assets
Nonutility plant and equipment, at cost	$	1,430,723	(322,211)	$	1,108,512
Accumulated depreciation and amortization, nonutility plant and equipment	$	(202,507)	61,945	$	(140,562)
Property, plant and equipment, net	$	3,983,035	(260,266)	$	3,722,769
Other noncurrent assets	$	78,716	6,941	$	85,657
Total noncurrent assets	$	964,435	6,941	$	971,376
Total assets	$	5,569,802	(253,325)	$	5,316,477
Capitalization
Retained earnings	$	1,148,297	(200,796)	$	947,501
Common stock equity	$	1,844,692	(200,796)	$	1,643,896
Total capitalization	$	4,104,158	(200,796)	$	3,903,362
Liabilities
Deferred income taxes	$	190,610	(52,529)	$	138,081
Total noncurrent liabilities	$	931,922	(52,529)	$	879,393
Total capitalization and liabilities	$	5,569,802	(253,325)	$	5,316,477
September 30, 2019
Assets
Nonutility plant and equipment, at cost	$	861,904	(285,730)	$	576,174
Accumulated depreciation and amortization, nonutility plant and equipment	$	(156,033)	49,419	$	(106,614)
Property, plant and equipment, net	$	3,045,944	(236,311)	$	2,809,633
Other noncurrent assets	$	94,791	21,268	$	116,059
Total noncurrent assets	$	815,435	21,268	$	836,703
Total assets	$	4,372,985	(215,043)	$	4,157,942
Capitalization
Retained earnings	$	1,075,960	(169,884)	$	906,076
Common stock equity	$	1,551,717	(169,884)	$	1,381,833
Total capitalization	$	3,088,894	(169,884)	$	2,919,010
Liabilities
Deferred income taxes	$	190,663	(45,159)	$	145,504
Total noncurrent liabilities	$	837,714	(45,159)	$	792,555
Total capitalization and liabilities	$	4,372,985	(215,043)	$	4,157,942

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Cash Flows as of September 30, 2020, 2019 and 2018 are as follow:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Depreciation and amortization	$	119,894	(12,526)	$	107,368
Deferred income taxes	$	(9,092)	43,438	$	34,346
September 30, 2019
Depreciation and amortization	$	91,730	(10,621)	$	81,109
Deferred income taxes	$	(59,013)	56,191	$	(2,822)
September 30, 2018
Depreciation and amortization	$	85,701	(9,130)	$	76,571
Deferred income taxes	$	15,590	11,553	$	27,143

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Common Stock Equity as of September 30, 2020, 2019 and 2018 are as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Retained Earnings
Balance at September 30, 2017	$	867,984	(121,891)	$	746,093
Net Income	$	233,436	(2,423)	$	231,013
Balance at September 30, 2018	$	1,007,117	(124,314)	$	882,803
Net Income	$	169,505	(45,570)	$	123,935
Balance at September 30, 2019	$	1,075,960	(169,884)	$	906,076
Net Income	$	193,919	(30,912)	$	163,007
Balance at September 30, 2020	$	1,148,297	(200,796)	$	947,501
Total Common stock equity
Balance at September 30, 2017	$	1,236,643	(121,891)	$	1,114,752
Net Income	$	233,436	(2,423)	$	231,013
Balance at September 30, 2018	$	1,418,978	(124,314)	$	1,294,664
Net Income	$	169,505	(45,570)	$	123,935
Balance at September 30, 2019	$	1,551,717	(169,884)	$	1,381,833
Net Income	$	193,919	(30,912)	$	163,007
Balance at September 30, 2020	$	1,844,692	(200,796)	$	1,643,896

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REVENUE

12 Months Ended

Sep. 30, 2020

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 we do 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 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 and wind 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. All wind assets were sold as of February 7, 2019. 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 RECs, 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	Wholesale natural gas services	The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers on a monthly basis in line with the terms of the contract and based on the services provided. Payment is due each month for the previous month's invoiced services.
Storage and Transportation	Natural gas services	The performance obligation of our Storage and Transportation segment is to provide the customer with storage and transportation services. Storage and Transportation generates revenues from firm storage contracts and transportation contracts, related usage fees for the use of storage space, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as our customers receive the benefits of our service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement.
Home Services and Other	Service contracts	Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice.

Revenue Recognized at a Point in Time:
Storage and Transportation	Natural gas services	The performance obligation of our Storage and Transportation segment is to provide the customer with storage and transportation services. Storage and Transportation generates revenues from hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Hub services revenues are recognized as services are performed.
Home Services and Other	Installations	Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators, for 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 fiscal 2020 are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Natural gas utility sales	$	695,858	—		—	—	—	$	695,858
Wholesale natural gas services	—		—		24,511	44,728	—	69,239
Service contracts	—		—		—	—	32,455	32,455
Installations and maintenance	—		—		—	—	18,562	18,562
Renewable Energy Certificates	—		1,384		—	—	—	1,384
Electricity sales	—		20,099		—	—	—	20,099
Eliminations (1)	—		—		—	(2,713)	(1,207)	(3,920)
Revenues from contracts with customers	695,858		21,483		24,511	42,015	49,810	833,677
Alternative revenue programs (2)	15,750		—		—	—	—	15,750
Derivative Instruments	18,315		81,134	(3)	1,005,908	—	—	1,105,357
Eliminations (1)	—		—		(1,116)	—	—	(1,116)
Revenues out of scope	34,065		81,134		1,004,792	—	—	1,119,991
Total operating revenues	$	729,923	102,617		1,029,303	42,015	49,810	$	1,953,668
2019
Natural gas utility sales	$	680,151	—		—	—	—	$	680,151
Wholesale natural gas services	—		—		31,459	—	—	31,459
Service contracts	—		—		—	—	31,499	31,499
Installations and maintenance	—		—		—	—	19,403	19,403
Electricity sales	—		22,121		—	—	—	22,121
Eliminations (1)	—		—		—	—	(2,302)	(2,302)
Revenues from contracts with customers	680,151		22,121		31,459	—	48,600	782,331
Alternative revenue programs (2)	10,364		—		—	—	—	10,364
Derivative Instruments	20,278		75,978	(3)	1,711,332	—	—	1,807,588
Eliminations (1)	—		—		(8,238)	—	—	(8,238)
Revenues out of scope	30,642		75,978		1,703,094	—	—	1,809,714
Total operating revenues	$	710,793	98,099		1,734,553	—	48,600	$	2,592,045

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

(2)Includes CIP revenue.

(3)Includes SREC revenue.

Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the fiscal years ended September 30, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Residential	$	490,233	10,233	—	—	48,867	$	549,333
Commercial and industrial	129,946		11,250	24,511	42,015	943	208,665
Firm transportation	69,357		—	—	—	—	69,357
Interruptible and off-tariff	6,322		—	—	—	—	6,322
Revenues out of scope	34,065		81,134	1,004,792	—	—	1,119,991
Total operating revenues	$	729,923	102,617	1,029,303	42,015	49,810	$	1,953,668
2019
Residential	$	440,787	9,003	—	—	47,655	$	497,445
Commercial and industrial	171,357		13,118	31,459	—	945	216,879
Firm transportation	61,370		—	—	—	—	61,370
Interruptible and off-tariff	6,637		—	—	—	—	6,637
Revenues out of scope	30,642		75,978	1,703,094	—	—	1,809,714
Total operating revenues	$	710,793	98,099	1,734,553	—	48,600	$	2,592,045

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 Consolidated Balance Sheets during fiscal 2020 are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of October 1, 2019	$	139,263	$	6,510	$	27,116
(Decrease) Increase	(5,090)		2,716		(1,182)
Balance as of September 30, 2020	$	134,173	$	9,226	$	25,934

The following table provides information about receivables and revenue earned on contracts in progress in excess of billings, which are included within accounts receivable, billed and unbilled, and customers’ credit balances and deposits, respectively, on the Consolidated Balance Sheets as of September 30:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Customer accounts receivable
Billed	$	52,134	5,282	70,457	3,905	2,395	$	134,173
Unbilled	7,842		1,384	—	—	—	9,226
Customers' credit balances and deposits	(25,934)		—	—	—	—	(25,934)
Total	$	34,042	6,666	70,457	3,905	2,395	$	117,465
2019
Customer accounts receivable
Billed	$	36,302	3,233	97,301	—	2,427	$	139,263
Unbilled	6,510		—	—	—	—	6,510
Customers' credit balances and deposits	(27,114)		—	—	—	(2)	(27,116)
Total	$	15,698	3,233	97,301	—	2,425	$	118,657

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REGULATION

12 Months Ended

Sep. 30, 2020

Regulated Operations [Abstract]

REGULATION

4. REGULATION

The EDECA is the legal framework for New Jersey’s public utility and wholesale energy landscape. NJNG is required, pursuant to a written order by the BPU under EDECA, to open its residential markets to competition from third-party natural gas suppliers. Customers can choose the supplier of their natural gas commodity in NJNG’s service territory.

As required by EDECA, NJNG’s rates are segregated into two primary components: the commodity portion, which represents the wholesale cost of natural gas, including the cost for interstate pipeline capacity to transport the natural gas to NJNG’s service territory; and the delivery portion, which represents the transportation of the commodity portion through NJNG’s natural gas distribution system to the end-use customer. NJNG does not earn utility gross margin on the commodity portion of its natural gas sales. NJNG earns utility gross margin through the delivery of natural gas to its customers, regardless of whether it or a third-party supplier provides the wholesale natural gas commodity.

Under EDECA, the BPU is required to audit the state’s energy utilities every two years. The primary purpose of the audit is to ensure that utilities and their affiliates offering unregulated retail services do not have an unfair competitive advantage over nonaffiliated providers of similar retail services. A combined competitive services and management audit of NJNG commenced in August 1, 2013. A draft management audit report was accepted by the BPU on July 23, 2014, for public comment. To date, NJNG has implemented all audit recommendations with the approval of BPU staff and is waiting for final BPU approval.

NJNG is subject to cost-based regulation; therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility capital investments based on the BPU’s approval. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets, and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.

NJNG’s recovery of costs is facilitated through its base rates, BGSS and other regulatory tariff riders. NJNG is required to make an annual filing to the BPU by June 1 of each year for review of its BGSS, CIP and other programs and related rates. Annual rate changes are requested to be effective at the beginning of the following fiscal year. The current base rates include a weighted average cost of capital of 6.95 percent and a return on common equity of 9.6 percent. In addition, NJNG is permitted to request approval of certain rate or program changes. All rate and program changes are subject to proper notification and BPU review and approval.

Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are composed of the following:

(Thousands)	2020		2019
Regulatory assets-current
New Jersey Clean Energy Program	$	15,570	$	15,468
Conservation Incentive Program	19,120		3,371
Underrecovered natural gas costs	—		9,506
Derivatives at fair value, net	—		4,526
Other current regulatory assets	1,682		—
Total current regulatory assets	$	36,372	$	32,871
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	36,516	$	38,351
Liability for future expenditures	150,590		131,080
Deferred income taxes	28,241		19,631
Derivatives at fair value, net	1		486
SAVEGREEN	21,281		10,201
Postemployment and other benefit costs	188,170		212,461
Deferred storm damage costs	6,515		8,687
Cost of removal	75,080		65,660
Other noncurrent regulatory assets	20,068		10,080
Total noncurrent regulatory assets	$	526,462	$	496,637
Regulatory liability-current
Overrecovered natural gas costs	$	25,914	$	—
Derivatives at fair value, net	274		—
Total current regulatory liabilities	$	26,188	$	—
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	195,425	$	200,417
Derivatives at fair value, net	352		—
New Jersey Clean Energy Program	—		197
Other noncurrent regulatory liabilities	509		1,821
Total noncurrent regulatory liabilities	$	196,286	$	202,435

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

Regulatory assets at Adelphia Gateway, not included in the table above, total $158,000 and $997,000 in current and noncurrent, respectively, and is comprised primarily of the tax benefit associated with the equity component of AFUDC as of September 30, 2020. Recovery of regulatory assets is subject to FERC approval.

New Jersey Clean Energy Program

The NJCEP is a statewide program that encourages energy efficiency and renewable energy. Funding amounts are determined by the BPU’s Office of Clean Energy and all New Jersey utilities are required to share in the annual funding obligation. The current NJCEP program is for the State of New Jersey’s fiscal year ending June 2021. NJNG recovers the costs associated with its portion of the NJCEP obligation through its NJCEP rider, with interest.

Over and Underrecovered Natural Gas Costs

NJNG recovers its cost of natural gas through the BGSS rate component of its customers’ bills. NJNG’s cost of natural gas includes the purchased cost of the natural gas commodity, fees paid to pipelines and storage facilities, adjustments as a result of BGSS incentive programs and hedging transactions. Overrecovered natural gas costs represent a regulatory liability that generally occurs when NJNG’s BGSS rates are higher than actual costs and requests approval to be returned to customers including interest, when applicable, in accordance with NJNG’s approved BGSS tariff. Conversely, underrecovered natural gas costs generally occur during periods when NJNG’s BGSS rates are lower than actual costs, in which case NJNG records a regulatory asset and requests amounts to be recovered from customers in the future.

Derivatives

Derivatives are utilized by NJNG to manage the price risk associated with its natural gas purchasing activities and to participate in certain BGSS incentive programs. The gains and losses associated with NJNG’s derivatives are recoverable through its BGSS, as noted above, without interest. See Note 5. Derivative Instruments.

Conservation Incentive Program

The CIP permits NJNG to recover utility gross margin variations related to customer usage resulting from customer conservation efforts and mitigates the impact of weather on its margin. Such utility gross margin variations are recovered in the year following the end of the CIP usage year, without interest, and are subject to additional conditions, including an earnings test, a revenue test and an evaluation of BGSS-related savings. This program has no expiration date.

Environmental Remediation Costs

NJNG is responsible for the cleanup of certain former gas manufacturing facilities. Actual expenditures are recovered from customers, with interest, over seven-year rolling periods, through a RAC rate rider. Recovery for NJNG’s estimated future liability will be requested and/or recovered when actual expenditures are incurred. See Note 15. Commitments and Contingent Liabilities.

Deferred Income Taxes

Upon adoption of a 1993 provision of ASC 740, Income Taxes, NJNG recognized a transition adjustment and corresponding regulatory asset representing the difference between NJNG’s existing deferred tax amounts compared with the deferred tax amounts calculated in accordance with the change in method prescribed by ASC 740. NJNG recovers the regulatory asset associated with these tax impacts through future base rates, without interest.

SAVEGREEN

NJNG administers certain programs that supplement the state’s NJCEP and that allow NJNG to promote clean energy to its residential and commercial customers, as described further below. NJNG will recover related expenditures and a weighted average cost of capital on the unamortized balance through a tariff rider, with interest, as approved by the BPU, over a two- to 10-year period depending upon the specific program incentive.

Postemployment and Other Benefit Costs

Postemployment and Other Benefit Costs represents NJNG’s underfunded postemployment benefit obligations, as well as a fiscal 2010 tax charge resulting from a change in the deductibility of federal subsidies associated with Medicare Part D, both of which are deferred as regulatory assets and are recoverable, without interest, in base rates. The BPU approved the recovery of the tax charge through NJNG’s base rates effective October 2016 over a seven-year amortization period. See Note 11. Employee Benefit Plans.

Deferred Storm Damage Costs

Portions of NJNG’s distribution system incurred significant damage as a result of Post-Tropical Cyclone Sandy in October 2012. NJNG deferred the uninsured incremental O&M costs associated with its restoration efforts, which were approved for recovery by the BPU through NJNG’s base rates, without interest, effective October 2016 over a seven-year amortization period.

Cost of Removal

NJNG accrues and collects for cost of removal in base rates on its utility property, without interest. These costs are recorded in accumulated depreciation for regulatory reporting purposes, and actual costs of removal, without interest, will be recovered in subsequent rates, pursuant to the BPU order. Consistent with GAAP, amounts recorded within accumulated depreciation for regulatory accounting purposes are reclassified out of accumulated depreciation to either a regulatory asset or a regulatory liability depending on whether actual cost of removal is still subject to collection or amounts overcollected will be refunded back to customers. NJNG’s prior regulatory liability represented customer collections in excess of actual expenditures, which the Company returned to customers as a reduction to depreciation expense.

Other Regulatory Assets

Other regulatory assets consist primarily of deferred costs associated with certain components of NJNG’s SBC, as discussed further in the regulatory proceedings section, and NJNG’s compliance with federal- and state-mandated PIM provisions. NJNG’s related costs to maintain the operational integrity of its distribution and transmission main are recoverable, without interest, subject to BPU review and approval. As of September 30, 2020, NJNG recorded $1.8 million of PIM in other regulatory assets, which is being recovered through base rates over a seven-year amortization period effective October 2016.

The following is a description of certain regulatory proceedings during fiscal 2019 and 2020:

In March 2019, NJNG filed a base rate case with the BPU requesting a natural gas revenue increase of $128.2 million, including a change in the Company’s overall rate of return on rate base to 7.87 percent. NJNG is also seeking permission to request recovery for SRL in a future filing, upon completion of the project. On July 2, 2019, the Company filed an update with actual information through May 31, 2019, which reflected a revenue increase of $129.8 million. In September 2019, the Company filed a second update with actual information through August 31, 2019, which reflected a revenue increase of $134.3 million. On November 13, 2019, the BPU issued an order adopting a stipulation of settlement approving a $62.2 million increase to base rates, which were effective on November 15, 2019. The increase includes an overall rate of return on rate base of 6.95 percent, return on common equity of 9.6 percent, a common equity ratio of 54 percent and a depreciation rate of 2.78 percent.

BGSS and CIP

BGSS rates are normally revised on an annual basis. In addition, to manage the fluctuations in wholesale natural gas costs, NJNG has the ability to make two interim filings during each fiscal year to increase residential and small commercial customer BGSS rates on a self-implementing and provisional basis. NJNG is also permitted to refund or credit back a portion of the commodity costs to customers at any time given five days’ notice when the natural gas commodity costs decrease in comparison to amounts projected or to amounts previously collected from customers. Concurrent with the annual BGSS filing, NJNG files for an annual review of its CIP. NJNG’s annual BGSS and CIP filings are summarized as follows:

•2018 BGSS/CIP filing — In April 2019, the BPU approved NJNG’s annual petition on a final basis to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well as changes to the CIP rates, which resulted in a $30.9 million annual recovery decrease effective October 2018.

•On December 28, 2018, NJNG notified the BPU that it will increase the BGSS rate, effective February 1, 2019, resulting in an estimated $10.9 million increase to the revenues credited to BGSS from February through September 30, 2019.

•2019 BGSS/CIP filing — On March 27, 2020, the BPU approved, on a final basis, NJNG’s annual petition to modify its BGSS, balancing charge and CIP rates. The rate changes resulted in a $17.6 million decrease to the annual revenues credited to BGSS and a $15.6 million annual increase related to its balancing charge, as well as changes to CIP rates, which resulted in a $10.6 million annual recovery increase, effective October 1, 2019.

•2020 BGSS/CIP filing — On September 9, 2020, the BPU approved NJNG’s annual petition to modify its BGSS, balancing charge and CIP rates for residential and small commercial customers. The rate changes will result in a $20.4 million decrease to the annual revenues credited to BGSS, a $3.8 million annual decrease related to its balancing charge, as well as changes to CIP rates, which will result in a $16.5 million annual recovery increase, effective October 1, 2020.

BGSS Incentive Programs

NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of utility gross margin-sharing programs that include off-system sales, capacity release and storage incentive programs. The Company is permitted to annually propose a process to evaluate and discuss alternative incentive programs, should performance of the existing incentives or market conditions warrant re-evaluation.

Energy Efficiency Programs

SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives, which are designed to encourage the installation of high efficiency heating and cooling equipment and other upgrades to promote energy efficiency to its residential and commercial customers while stimulating state and local economies through the creation of jobs. Depending on the specific initiative or approval, NJNG recovers costs associated with the programs over a three- to 10-year period through a tariff rider mechanism. As of September 30, 2020, the BPU approved total SAVEGREEN investments of approximately $354.3 million, including $135 million that was approved in September 2018, for a continuation of existing EE programs and the implementation of new programs through December 2021.

On September 25, 2020, NJNG filed a petition with the BPU for an additional three-year SAVEGREEN program consisting of approximately $127 million of direct investment, $113 million in financing options, and approximately $23 million in operation and maintenance expenses, to be effective July 1, 2021. SAVEGREEN investments and costs are filed with the BPU on an annual basis. NJNG’s annual EE filings are summarized as follows:

•2018 EE filing — On December 18, 2018, the BPU approved a decrease in NJNG's EE recovery rate reflecting actual costs incurred through September 30, 2018, which resulted in an annual recovery of approximately $8.8 million, effective January 1, 2019.

•2019 EE filing — On October 25, 2019, the BPU approved an increase in NJNG's EE recovery rate, which resulted in an annual recovery of approximately $11.3 million, effective November 1, 2019.

•2020 EE filing — On May 29, 2020, NJNG filed a petition with the BPU to minimally decrease its EE recovery rate. Throughout the course of the proceeding, the Company updated the filing for additional actual information. Based on the updated information, the BPU approved the request to maintain its existing rate, which will result in an annual recovery of approximately $11.4 million, effective November 1, 2020.

Societal Benefits Charge

The SBC is comprised of three primary riders that allow NJNG to recover costs associated with USF, which is a permanent statewide program for all natural gas and electric utilities for the benefit of income-eligible customers, MGP remediation and the NJCEP. NJNG has submitted the following filings to the BPU, which include a report of program expenditures incurred each program year:

•2018 SBC filing — In September 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which resulted in a $1 million annual increase, effective October 1, 2018. In March 2019, the BPU approved NJNG’s annual SBC application requesting recovery of remediation expenses incurred through June 30, 2018, an increase in the RAC of approximately $1.4 million annually, and an increase to the NJCEP factor, which resulted in an annual increase of approximately $1.9 million, effective April 1, 2019.

•2019 SBC filing — On June 24, 2019, NJNG filed its annual USF compliance filing proposing an increase to the statewide USF rate, which will result in the annual recovery increasing by $1.2 million, effective October 1, 2019. On September 27, 2019, NJNG filed its annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $1.4 million annually and an increase to the NJCEP factor, which resulted in an annual increase of approximately $3.3 million, effective April 1, 2020. On March 16, 2020, a stipulation was signed in NJNG's annual SBC application which included an increase in the RAC rate of $1.2 million annually and a decrease to the NJCEP factor of $600,000. The BPU approved the stipulation on September 9, 2020, effective October 1, 2020.

•2020 USF filing — On June 25, 2020, NJNG filed its annual USF compliance filing proposing a decrease to the statewide USF rate, decreasing the annual recovery by approximately $400,000. On September 23, 2020, the BPU approved the decrease, effective October 1, 2020.

•2020 SBC filing — On September 29, 2020, NJNG filed its annual SBC application requesting to recover remediation expenses including an increase in the RAC, of approximately $1.3 million annually and an increase to the NJCEP factor, which will result in an annual increase of approximately $6 million, effective April 1, 2021.

Infrastructure Programs

NJNG has significant annual capital expenditures associated with the management of its natural gas distribution and transmission system, including new utility plant for customer growth and its associated PIM and infrastructure programs. NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability of NJNG’s natural gas distribution system, including SAFE and NJ RISE.

SAFE/NJ RISE

The SAFE program replaces portions of NJNG’s natural gas distribution unprotected steel, cast iron infrastructure and associated services to improve the safety and reliability of the natural gas distribution system. SAFE I was approved to invest up to $130 million, exclusive of AFUDC, over a four-year period. SAFE II was approved to invest up to $200 million, excluding AFUDC, over a five-year period. NJNG will recover approximately $157.5 million through annual rate filings, with the remainder recovered through subsequent rate cases. As a condition of approval of the program, NJNG was required to file a base rate case no later than November 2019 and satisfied this requirement with its March 29, 2019 base rate case filing.

NJ RISE consists of six capital investment projects estimated to cost $102.5 million over a five-year period, excluding AFUDC, for natural gas distribution storm-hardening and mitigation projects, along with incremental depreciation expense. NJ RISE includes a weighted average cost of capital that ranges from 6.74 percent to 6.9 percent and a return on equity of 9.75 percent. Requests for recovery of future NJ RISE capital costs will occur in conjunction with SAFE II.

On September 17, 2018, the BPU approved NJNG’s petition requesting a base rate increase of $6.8 million annually for the recovery of SAFE II and NJ RISE capital investment costs related to the 12 months ending June 30, 2018, effective October 1, 2018. On September 27, 2019, the BPU approved NJNG’s annual petition requesting a base rate increase of $7.8 million, effective October 1, 2019.

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

Southern Reliability Link

The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG’s service territory. All approvals required for the completion of the project have been received and construction began in December 2018.

Infrastructure Investment Program

On February 28, 2019, NJNG filed a petition with the BPU seeking authority to implement a five-year IIP. The IIP consists of two components, transmission and distribution investments and information technology replacement and enhancements. The total investment for the IIP is approximately $507 million. Upon approval from the BPU, investments will be recovered through annual filings to adjust base rates. On October 28, 2020, the BPU approved the Company’s transmission and distribution component of the IIP for $150 million over five years, effective November 1, 2020. The recovery of information technology replacement and enhancements, that was included in the original IIP filing, will be included as part of base rate filings as projects are placed in service.

Other Filings

COVID-19

On July 2, 2020, the BPU issued an order which authorized New Jersey utilities to create a regulatory asset by deferring incremental COVID-19 related costs and required a related quarterly report be filed for the COVID-19-related costs and savings incurred. Utilities must file petition by later of December 31, 2021, or within 60 days of the close of the regulatory asset period and rate recovery can be addressed in the filing or the utility may request consideration be deferred to future rate case. Any potential rate recovery and the appropriate period of recovery, will be addressed through that filing, or may request a deferral of rate recovery for a future base rate case.

The Tax Act

On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. As a result, NJNG recorded a regulatory liability, which included the revaluation of its deferred income taxes and the accounting of the income tax effects on the revaluation.

On January 31, 2018, the BPU issued an Order which directed New Jersey utilities to submit filings to the BPU by March 2, 2018, to propose the prospective change in base rates as a result of the Tax Act to be effective April 1, 2018, the method to return to customers the overcollection of taxes in base rates from January 1, 2018, through March 31, 2018, and an outline of the method by which the excess deferred taxes would be returned to customers. The excess deferred taxes are primarily related to timing differences associated with utility plant depreciation and are subject to IRS normalization rules, which require amortization over the remaining life of the utility plant.

As a result of the changes associated with the Tax Act, NJNG recorded a decrease in its net deferred tax liability of $228.4 million, which included $164.3 million for the revaluation of its deferred income taxes and $64.1 million for the accounting of the income tax effects on the revaluation of those deferred income taxes. These amounts were recorded as a regulatory liability on the Consolidated Balance Sheets. On March 1, 2018, NJNG submitted its required filing to the BPU proposing a $19.7 million base rate reduction and customer refunds of approximately $31 million, which is inclusive of state sales tax and interest at the Company’s short-term debt rate as specified in the Company’s last base rate case. On March 26, 2018, the BPU approved, on an interim basis, the $19.7 million rate reduction, effective April 1, 2018. On May 22, 2018, the BPU approved final rates and customer refunds of the $31 million. These credits were returned to customer accounts in June 2018. As of September 30, 2020, the regulatory liability included excess deferred income taxes of $195 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles.

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DERIVATIVE INSTRUMENTS

12 Months Ended

Sep. 30, 2020

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 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 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 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

NJNG’s physical and financial commodity derivatives, except for those designated as NPNS, are recognized at fair value on the Consolidated Balance Sheets. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Consolidated Balance Sheets. Effective January 1, 2016, the Company prospectively applies the NPNS scope exception on a case-by-case basis to certain qualifying physical commodity contracts. Contracts that are designated as NPNS are recognized in regulatory assets or liabilities on the Consolidated Balances Sheets upon settlement. The average cost of natural gas is charged to expense in the current-period earnings based on the BGSS factor times the therm sales.

In June 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with a $125 million debt issuance that was finalized in May 2018. This debt issuance coincided with the maturity of NJNG's $125 million, 5.6 percent notes that came due May 15, 2018. This treasury lock was settled on March 13, 2018, which coincided with the pricing of the new debt being issued. Settlement of the treasury lock resulted in a $2.6 million loss, which was recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the $125 million, 4.01 percent notes that were issued on May 11, 2018.

During fiscal 2020, NJNG entered into treasury lock transactions to fix the benchmark treasury rate associated with a $75 million debt tranche that was issued in September 2020. Settlement of the treasury locks resulted in a $6.6 million loss, which was recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the debt as a component of interest expense on the Consolidated Statements of Operations, which totaled $50,000, as of September 30, 2020.

Clean Energy Ventures

The Company elects NPNS accounting treatment on qualifying PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative. Contracts designated as NPNS are accounted for 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 certain contracts to be normal.

Home Services and Other

On January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on its $100 million variable rate term loan, which fixed the variable rate at 2.84 percent. The swap terminated on August 16, 2019, which coincided with the maturity of the debt. The change in the fair value and the settlement of the interest rate swap was recorded as a component of interest expense on the Consolidated Statements of Operations.

During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with $260 million debt issuance that was finalized in July 2020 and a $200 million debt issuance that was finalized in September 2020. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks resulted in a loss of $13.7 million, which was recorded within OCI and will be amortized in earnings over the life of the debt as a component of interest expense on the Consolidated Statements of Operations, which totaled $108,000, net of tax, as of September 30, 2020.

Fair Value of Derivatives

The following table reflects the fair value of the Company’s derivative assets and liabilities recognized on the Consolidated Balance Sheets as of September 30:

			Fair Value
			2020						2019
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	78		$	76		$	67		$	245
Financial commodity contracts	Derivatives - current		71			282			382			570
Energy Services:
Physical commodity contracts	Derivatives - current		6,454			20,438			6,847			27,540
	Derivatives - noncurrent		1,264			12,003			1,710			12,641
Financial commodity contracts	Derivatives - current		16,671			12,965			17,806			29,057
	Derivatives - noncurrent		2,037			1,346			5,716			6,105
Foreign currency contracts	Derivatives - current		36			104			1			211
	Derivatives - noncurrent		48			3			—			75
Total fair value of derivatives			$	26,659		$	47,217		$	32,529		$	76,444

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 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 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 September 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222
As of September 30, 2019:
Derivative assets:
Energy Services
Physical commodity contracts		$	8,557		$	(2,906)		$	(200)		$	5,451
Financial commodity contracts		23,522			(19,646)			—			3,876
Foreign currency contracts		1			(1)			—			—
Total Energy Services		$	32,080		$	(22,553)		$	(200)		$	9,327
Natural Gas Distribution
Physical commodity contracts		$	67		$	(9)		$	—		$	58
Financial commodity contracts		382			(382)						—
Total Natural Gas Distribution		$	449		$	(391)		$	—		$	58
Derivative liabilities:
Energy Services
Physical commodity contracts		$	40,181		$	(2,906)		$	—		$	37,275
Financial commodity contracts		35,162			(19,646)			(15,516)			—
Foreign currency contracts		286			(1)			—			285
Total Energy Services		$	75,629		$	(22,553)		$	(15,516)		$	37,560
Natural Gas Distribution
Physical commodity contracts		$	245		$	(9)		$	—		$	236
Financial commodity contracts		570			(382)			(188)			—
Total Natural Gas Distribution		$	815		$	(391)		$	(188)		$	236

(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 (losses) on the financial transactions that are economic hedges of the cost of the purchased natural gas are recognized prior to the gains (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 (losses) on the financial derivative instruments and gains (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 reflects the effect of derivative instruments on the Consolidated Statements of Operations as of September 30:

(Thousands)	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income on Derivatives
Derivatives not designated as hedging instruments:		2020		2019		2018
Energy Services:
Physical commodity contracts	Operating revenues	$	1,163	$	(5,732)	$	(9,311)
Physical commodity contracts	Natural gas purchases	(3,366)		(521)		(197)
Financial commodity contracts	Natural gas purchases	58,949		(643)		(24,622)
Foreign currency contracts	Natural gas purchases	(41)		(283)		(379)
Home Services and Other:
Interest rate contracts	Interest expense	—		(233)		334
Total unrealized and realized (losses) gains		$	56,705	$	(7,412)	$	(34,175)

NJNG’s derivative contracts are part of the Company’s risk management activities that relate to its natural gas purchases, BGSS incentive programs and debt financing. These transactions are entered into pursuant to regulatory approval. At settlement, the resulting gains and/or losses are payable to or recoverable from utility customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings.

The following table reflects the gains (losses) associated with NJNG’s derivative instruments as of September 30:

(Thousands)	2020		2019		2018
Natural Gas Distribution:
Physical commodity contracts	$	2,077	$	5,926	$	1,232
Financial commodity contracts	(3,903)		(7,700)		1,844
Interest rate contracts	—		—		8,467
Total unrealized and realized (losses) gains	$	(1,826)	$	(1,774)	$	11,543

NJR designates its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges are recorded in OCI and upon settlement of the contracts, realized gains and (losses) are reclassified from OCI to interest expense on the Consolidated Statements of Operations.

The following table reflects the effect of derivative instruments designated as cash flow hedges in OCI as of September 30:

(Thousands)	Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives				Location of Gain (Loss) Reclassified from OCI into Income	Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income
Derivatives in cash flow hedging relationships:	2020		2019			2020		2019
Interest rate contracts	$	(13,568)	$	—	Interest expense	$	140	$	—

NJNG and Energy Services had the following outstanding long (short) derivatives as of September 30:

		Volume (Bcf)
	Transaction Type	2020	2019
Natural Gas Distribution	Futures	23.7	27.6
	Physical Commodity	6.0	11.6
Energy Services	Futures	(27.5)	(29.6)
	Swaps	(1.8)	(5.0)
	Options	—	1.0
	Physical Commodity	5.0	44.5

Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $5.1 million and $6.2 million and 960,000 and 796,000 SRECs that were open, as of September 30, 2020 and 2019, 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 as of September 30, by segment, are as follows:

(Thousands)	Balance Sheet Location	2020		2019
Natural Gas Distribution	Restricted broker margin accounts	$	13,525	$	1,982
Energy Services	Restricted broker margin accounts	$	55,919	$	71,741

Wholesale Credit Risk

NJNG, Energy Services and Clean Energy Ventures are exposed to credit risk as a result of their sales/wholesale marketing activities. As a result of the inherent volatility in the prices of natural gas commodities, derivatives, SRECs, electricity and RECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty fails to perform the obligations under its contract (e.g., fails to deliver or pay for natural gas, SRECs, electricity or RECs), 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 September 30, 2020. 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		$	132,105
Noninvestment grade		8,527
Internally-rated investment grade		24,647
Internally-rated noninvestment grade		12,471
Total		$	177,750

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

Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company’s credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on September 30, 2020 and 2019, were considered immaterial. These amounts differ from the respective net derivative liabilities reflected on the Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.

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FAIR VALUE

12 Months Ended

Sep. 30, 2020

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. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.

As of September 30, the estimated fair value of long-term debt at NJNG and NJR, including current maturities, excluding finance leases and debt issuance costs, is as follows (1):

(Thousands)	2020		2019
NJNG (2) (3)
Carrying value	$	1,092,845	$	892,845
Fair market value	$	1,271,715	$	984,129
NJR (4)
Carrying value	$	1,010,000	$	550,000
Fair market value	$	1,146,033	$	584,735

(1)See Note 9. Debt for a reconciliation to long-term and short-term debt.

(2)Excludes finance leases of $74.2 million and $35.4 million as of September 30, 2020 and September 30, 2019, respectively.

(3)Excludes NJNG's debt issuance costs of $9.2 million and $9 million as of September 30, 2020 and September 30, 2019, respectively.

(4)Excludes NJR's debt issuance costs of $3.4 million and $2 million as of September 30, 2020 and September 30, 2019, 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 Consolidated Balance Sheets. The estimated fair value of solar asset financing obligations as of September 30, 2020 and September 30, 2019 was $149.2 million and $98.6 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 September 30, 2020, NJR 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, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs.

The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and includes the following:

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

Level 2Other significant observable inputs, such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:

•widely accepted and public;

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

•observable and published.

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

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

Financial derivative portfolios of NJNG and Energy Services consist mainly of futures, options and swaps. The Company primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market; therefore, the primary sources for its price inputs are CME, NYMEX and ICE. Energy Services uses Platts and Natural Gas Exchange for Canadian delivery points. However, Energy Services also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the transportation cost to the final delivery location is not significant to the overall valuation. If required, Energy Services’ policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or other pricing services.

The Company also has other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When the Company determines fair values, measurements are adjusted, as needed, for credit risk associated with its counterparties, as well as its own credit risk. The Company determines these adjustments by using historical default probabilities that correspond to the applicable S&P issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.

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 September 2020:
Assets
Physical commodity contracts		$	—		$	7,796		$	—	$	7,796
Financial commodity contracts		18,279			500			—		18,779
Financial commodity contracts - foreign exchange		—			84			—		84
Money market funds		112,291			—			—		112,291
Other		1,840			—			—		1,840
Total assets at fair value		$	132,410		$	8,380		$	—	$	140,790
Liabilities
Physical commodity contracts		$	—		$	32,517		$	—	$	32,517
Financial commodity contracts		14,593			—			—		14,593
Financial commodity contracts - foreign exchange		—			107			—		107
Total liabilities at fair value		$	14,593		$	32,624		$	—	$	47,217
As of September 30, 2019:
Assets
Physical commodity contracts		$	—		$	8,624		$	—	$	8,624
Financial commodity contracts		20,028			3,876			—		23,904
Financial commodity contracts - foreign exchange		—			1			—		1
Other (1)		1,706			—			—		1,706
Total assets at fair value		$	21,734		$	12,501		$	—	$	34,235
Liabilities
Physical commodity contracts		$	—		$	40,426		$	—	$	40,426
Financial commodity contracts		35,732			—			—		35,732
Financial commodity contracts - foreign exchange		—			286			—		286
Total liabilities at fair value		$	35,732		$	40,712		$	—	$	76,444

(1)Includes money market funds.

See Note 5. Derivative Instruments for additional details.

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INVESTMENTS IN EQUITY INVESTEES

12 Months Ended

Sep. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

INVESTMENTS IN EQUITY INVESTEES

7. INVESTMENTS IN EQUITY INVESTEES

As of September 30, the Company’s investments in equity method investees includes the following:

(Thousands)	2020		2019
Steckman Ridge (1)	$	112,378	$	114,428
PennEast (2)	95,997		85,840
Total	$	208,375	$	200,268

(1)Includes loans with a total outstanding principal balance of $70.4 million for both fiscal 2020 and 2019, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

(2)Includes a deferred tax component related to AFUDC equity of $4.6 million and $4.1 million for September 30, 2020 and September 30, 2019, respectively.

Steckman Ridge

The Company holds a 50 percent equity method investment in Steckman Ridge, a jointly owned and controlled natural gas storage facility located in Bedford County, Pennsylvania. Due to the anticipated expiration of a customer contract, the Company evaluated its investment in Steckman Ridge for other-than-temporary impairment and determined an impairment charge was not necessary.

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

PennEast

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

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

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

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

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

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

On June 29, 2020, the Supreme Court requested that the Solicitor General of the U.S. file a brief that expresses the views on the question of the use of eminent domain to acquire state owned lands for pipeline construction. 

The Company evaluated its investment in PennEast for other-than-temporary impairment and determined an impairment charge was not necessary. The Company estimated the fair value of its investment in PennEast using probability-weighted scenarios of discounted future cash flows. Management made significant estimates and assumptions related to development options and legal outcomes, construction costs, timing of capital investments and in-service dates, revenues and discount rates. Higher probabilities were assumed related to those scenarios where the project is completed. The discounted cash flow scenarios contemplated the impact of key assumptions of future court decisions and future management decisions and requires management to make significant estimates regarding the likelihood of various scenarios and assumptions. It is reasonably possible that future unfavorable developments, such as a reduced likelihood of success from development options and legal outcomes, estimated increases in construction costs, increases in the discount rate, or further significant delays, could result in

an impairment of our equity method investment. Also, the use of alternate judgments and assumptions could result in a different calculation of fair value, which could ultimately result in the recognition of an other-than-temporary impairment charge in the Consolidated Financial Statements.

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EARNINGS PER SHARE

12 Months Ended

Sep. 30, 2020

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 the fiscal years ended September 30:

(Thousands, except per share amounts)	2020		2019		2018
Net income, as reported	$	163,007	$	123,935	$	231,013
Basic earnings per share
Weighted average shares of common stock outstanding-basic	94,798		89,242		87,689
Basic earnings per common share	$1.72		$1.39		$2.63
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	94,798		89,242		87,689
Incremental shares (1)	305		354		626
Weighted average shares of common stock outstanding-diluted	95,103		89,596		88,315
Diluted earnings per common share (2)	$1.71		$1.38		$2.62

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

(2)There were anti-dilutive shares of 74,000 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement for fiscal 2020. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for fiscal 2019 and 2018.

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DEBT

12 Months Ended

Sep. 30, 2020

Debt Disclosure [Abstract]

DEBT

9. DEBT

NJNG and NJR finance working capital requirements and capital expenditures through the issuance of various long-term debt and other financing arrangements, including unsecured credit and private placement debt shelf facilities. Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit.

Long-term Debt

The following table presents the long-term debt of the Company as of September 30:

(Thousands)			2020		2019
NJNG
First mortgage bonds:		Maturity date:
3.00%	Series OO	August 1, 2041	46,500		46,500
3.15%	Series PP	April 15, 2028	50,000		50,000
3.58%	Series QQ	March 13, 2024	70,000		70,000
4.61%	Series RR	March 13, 2044	55,000		55,000
2.82%	Series SS	April 15, 2025	50,000		50,000
3.66%	Series TT	April 15, 2045	100,000		100,000
3.63%	Series UU	June 21, 2046	125,000		125,000
4.01%	Series VV	May 11, 2048	125,000		125,000
3.50%	Series WW	April 1, 2042	10,300		10,300
3.38%	Series XX	April 1, 2038	10,500		10,500
2.45%	Series YY	April 1, 2059	15,000		15,000
3.76%	Series ZZ	July 17, 2049	100,000		100,000
3.86%	Series AAA	July 17, 2059	85,000		85,000
2.75%	Series BBB	August 1, 2039	9,545		9,545
3.00%	Series CCC	August 1, 2043	41,000		41,000
3.13%	Series DDD	June 30, 2050	50,000		—
3.13%	Series EEE	July 23, 2050	50,000		—
3.33%	Series FFF	July 23, 2060	25,000		—
2.87%	Series GGG	September 1, 2050	25,000		—
2.97%	Series HHH	September 1, 2060	50,000		—
Finance lease obligation-buildings		June 30, 2037	47,597		5,637
Finance lease obligation-meters		Various dates	26,562		29,744
Less: Debt issuance costs			(9,195)		(9,027)
Less: Current maturities of long-term debt			(10,416)		(10,420)
Total NJNG long-term debt			1,147,393		908,779
NJR
3.25%	Unsecured senior notes	September 17, 2022	50,000		50,000
3.20%	Unsecured senior notes	August 18, 2023	50,000		50,000
3.48%	Unsecured senior notes	November 7, 2024	100,000		100,000
3.54%	Unsecured senior notes	August 18, 2026	100,000		100,000
3.96%	Unsecured senior notes	June 8, 2028	100,000		100,000
3.29%	Unsecured senior notes	July 17, 2029	150,000		150,000
3.60%	Unsecured senior notes	July 23, 2032	130,000		—
3.50%	Unsecured senior notes	July 23, 2030	130,000		—
3.25%	Unsecured senior notes	September 1, 2033	80,000		—
3.13%	Unsecured senior notes	September 1, 2031	120,000		—
Less: Debt issuance costs			(3,424)		(2,004)
Less: Current maturities of long-term debt			—		—
Total NJR long-term debt			1,006,576		547,996
Clean Energy Ventures
Solar asset financing obligation		Various dates	122,317		91,401
Less: Current maturities of long-term debt			(16,820)		(10,999)
Total Clean Energy Ventures long-term debt			105,497		80,402
Total long-term debt			$	2,259,466	$	1,537,177

Annual long-term debt redemption requirements, excluding finance leases, debt issuance costs and solar asset financing obligations, as of September 30, are as follows:

(Thousands)	NJR		NJNG
2021	$	—	$	—
2022	$	50,000	$	—
2023	$	50,000	$	—
2024	$	100,000	$	70,000
2025	$	—	$	50,000
Thereafter	$	810,000	$	972,845

NJNG

First Mortgage Bonds

NJNG and Trustee entered into the Mortgage Indenture, dated September 1, 2014, which secures all of the outstanding First Mortgage Bonds issued by NJNG. The Mortgage Indenture provides a direct first mortgage lien upon substantially all of the operating properties and franchises of NJNG (other than excepted property, such as cash on hand, choses-in-action, securities, rent, natural gas meters and certain materials, supplies, appliances and vehicles), subject only to certain permitted encumbrances. The Mortgage Indenture contains provisions subjecting after-acquired property (other than excepted property and subject to pre-existing liens, if any, at the time of acquisition) to the lien thereof.

NJNG’s Mortgage Indenture does not restrict NJNG’s ability to pay dividends. New Jersey Administrative Code 14:4-4.7 states that a public utility cannot issue dividends, without regulatory approval, if its equity to total capitalization ratio falls below 30 percent. As of September 30, 2020, NJNG’s equity to total capitalization ratio is 53.1 percent and has the ability to issue up to $1.1 billion of FMB under the terms of the Mortgage Indenture.

On April 18, 2019, NJNG completed the remarketing of three FMBs, in the amount of $35.8 million, with a weighted average interest rate of 3.02 percent. The bonds have maturity dates ranging from April 2038 to April 2059. The bonds were previously purchased in lieu of redemption and were being held by the Company.

On July 17, 2019, NJNG entered into a Note Purchase Agreement, under which NJNG issued $100 million of 3.76 percent senior notes due July 17, 2049 and $85 million of 3.86 percent senior notes due July 17, 2059. The senior notes are secured by an equal principal amount of NJNG's FMBs issued under NJNG's Mortgage Indenture.

On August 1, 2019, NJNG completed a remarketing of three existing variable rate FMBs, with a total principal amount of $97 million, which fixed the interest rates of the bonds. NJNG remarketed $46.5 million at 3 percent due August 1, 2041, $41 million at 3 percent due August 2043 and $9.5 million at 2.75 percent due August 1, 2039. EDA Bonds are special, limited obligations of the EDA payable solely from payments made by NJNG pursuant to a Loan Agreement and are secured by the pledge of $97 million principal amount of the FMB issued by the Company.

On May 14, 2020, NJNG entered into a Note Purchase Agreement for $125 million of its senior notes, of which $100 million were at an interest rate of 3.13 percent, maturing in 2050, and $25 million were at an interest rate of 3.33 percent, maturing in 2060. On June 30, 2020, NJNG issued $50 million of 3.13 percent senior notes due June 30, 2050. On July 23, 2020, NJNG issued the remaining $50 million of 3.13 percent senior notes due July 23, 2050 and $25 million of 3.33 percent senior notes due July 23, 2060. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

On September 1, 2020, NJNG entered into and issued a Note Purchase Agreement for $75 million of its senior notes, of which $25 million were at an interest rate of 2.87 percent, maturing in 2050, and $50 million were at an interest rate of 2.97 percent, maturing in 2060. The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.

Sale Leasebacks

NJNG has entered into a sale leaseback for its headquarters building, which has a 16-year term that expires in June 30, 2037. The present value of the agreement’s lease payments is reflected as a finance lease liability, which are included in utility plant and long-term debt, respectively, on the Consolidated Balance Sheets.

NJNG received $4 million, $9.9 million and $7.8 million for fiscal 2020, 2019 and 2018, respectively, in connection with the sale leaseback of its natural gas meters. NJNG records a finance lease liability that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease. During fiscal 2020, 2019 and 2018, NJNG exercised early purchase options with respect to meter leases by making final principal payments of $1.2 million, $1.1 million and $2.2 million, respectively.

Contractual commitments for finance lease payments, as of the fiscal years ended September 30, are as follows:

(Thousands)	senior note
2021		$	54,992
2022		6,004
2023		4,622
2024		5,279
2025		3,396
Thereafter		2,324
Subtotal		76,617
Less: Interest component		(2,458)
Total		$	74,159

NJR

On July 17, 2019, NJR entered into a Note Purchase Agreement for $150 million of 3.29 percent senior notes due on July 17, 2029. NJR issued $50 million of these senior notes on July 17, 2019 and issued the remaining $100 million of these senior notes on August 15, 2019.

On January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on its $100 million variable rate term loan, which fixed the variable rate at 2.84 percent. The swap terminated on August 16, 2019, which coincided with the maturity of the debt. NJR had no long-term variable-rate debt outstanding as of September 30, 2020 and 2019.

On May 14, 2020, NJR entered into a Note Purchase Agreement for $260 million of its senior notes, of which $130 million are at a fixed interest rate of 3.5 percent, maturing in 2030, and $130 million are at a fixed interest rate of 3.6 percent, maturing in 2032. On July 23, 2020, NJR issued all $260 million of the senior notes. The senior notes are unsecured and guaranteed by certain unregulated subsidiaries of NJR.

On September 1, 2020, NJR entered into and issued a Note Purchase Agreement for $200 million of its senior notes, of which $120 million are at a fixed interest rate of 3.13 percent, maturing in 2031, and $80 million are at a fixed interest rate of 3.25 percent, maturing in 2033. The senior notes are unsecured and guaranteed by certain unregulated subsidiaries of NJR.

Clean Energy Ventures

Clean Energy Ventures received proceeds of $42.9 million and $71.5 million in fiscal 2020 and 2018, respectively, in connection with the sale leaseback of commercial solar assets. Clean Energy Ventures did not receive proceeds related to the sale leaseback of commercial solar assets during fiscal 2019. Clean Energy Ventures enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over a period of five to 15 years. These sale leasebacks arrangements did not qualify for sale treatment and, therefore, are accounted for as a financing arrangement, which are typically secured by the renewable energy facility asset and its future cash flows from SREC and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer. Clean Energy Ventures continues to operate the solar assets, including related expenses, and retain the revenue generated from SRECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the contract term.

Contractual commitments for the solar financing obligation payments, as of the fiscal years ended September 30, are as follows:

(Thousands)	Lease Payments
2021		$	12,928
2022		12,926
2023		13,003
2024		12,904
2025		8,985
Thereafter		47,268
Subtotal		108,014
Less: Interest component		(23,052)
Total		$	84,962

Short-term Debt

A summary of NJR’s and NJNG’s short-term bank facilities as of September 30, are as follows:

(Thousands)	2020			2019			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	425,000		$	425,000		December 2023
Notes outstanding at end of period	$	125,350		$	25,450
Weighted average interest rate at end of period	1.49		%	3.04		%
Amount available at end of period (2)	$	289,356		$	394,800
Bank revolving credit facilities (1)	$	250,000		$	—		April 2021
Notes outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (2)	$	250,000		$	—
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		December 2023
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2)Letters of credit outstanding total $10.3 million and $4.8 million as of September 30, 2020 and 2019, respectively, which reduces amount available by the same amount.

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

(4)Letters of credit outstanding total $731,000 as of September 30, 2020 and 2019, which reduces amount available by the same amount.

Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit. Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.

On October 9, 2019, NJR entered into a $350 million Bridge Facility, which was used primarily to finance the Leaf River acquisition. The Bridge Facility accrued interest at the LIBOR rate for a 1-month interest period plus 0.875 percent during the first 180 days, and 1.075 percent after 180 days. Loans under the Bridge Facility were required to be prepaid to the extent of new cash proceeds received upon the issuance of equity of NJR, the incurrence of indebtedness by NJR or its subsidiaries, the disposition of assets by NJR or its subsidiaries or upon other specified events, in each case subject to certain exceptions set forth in the Bridge Facility. As of September 30, 2020, the loan was repaid in full.

NJR

On April 24, 2020, NJR entered into a 364-day $250 million revolving credit facility with an interest rate based on LIBOR plus 1.625 percent. After six months, all outstanding amounts under the credit facility would convert to a term loan and would be due on April 23, 2021. In connection with entry into this credit facility, as of September 30, 2020, all outstanding borrowings under NJR's December 13, 2019, $150 million revolving line of credit facility were repaid. On October 24, 2020, there was no balance outstanding on the $250 million credit facility. As a result, the credit facility was considered terminated.

On June 25, 2018, the $425 million NJR Credit Facility was amended to permit liens and the disposition of assets relating to sale leaseback or other similar tax equity financing arrangements of meter assets or of solar facilities. These transactions are permissible so long as NJR is in compliance with certain covenants both before and after such incurrence, and if no event of default may be caused by such sale leaseback or similar arrangement.

On December 5, 2018, NJR entered into an Amended and Restated Credit Agreement governing a $425 million NJR Credit Facility. The NJR Credit Facility expires on December 5, 2023, subject to two mutual options for a one-year extension beyond that date. The NJR Credit Facility permits the borrowing of revolving loans and swingline loans, as well as the issuance of letters of credit. The NJR Credit Facility also includes an accordion feature, which would allow NJR, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit Facility in minimum increments of $50 million increments up to a maximum of $250 million. Certain of NJR’s unregulated subsidiaries have guaranteed all of NJR’s obligations under the NJR Credit Facility. The credit facility is used primarily to finance its share repurchases, to satisfy Energy Services’ short-term liquidity needs and to finance, on an initial basis, unregulated investments.

As of September 30, 2020, NJR had seven letters of credit outstanding totaling $10.3 million on behalf of Energy Services and Clean Energy Ventures. These letters of credit reduce the amount available under NJR’s committed credit facility by the same amount. NJR does not anticipate that these letters of credit will be drawn upon by the counterparties, and they will be renewed as necessary.

Energy Services’ letters of credit are used for margin requirements for natural gas transactions, collateral and security deposit for retail natural gas sales and expire on dates ranging from December 2020 to September 2021.

Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.

NJNG

On December 5, 2018, NJNG entered into an Amended and Restated Credit Agreement governing a $250 million, NJNG Credit Facility. The NJNG Credit Facility expires on December 5, 2023, subject to two mutual options for a one-year extension beyond that date. The NJNG Credit Facility permits the borrowing of revolving loans and swingline loans, as well as the issuance of letters of credit. The NJNG Credit Facility also includes an accordion feature, which would allow NJNG, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJNG Credit Facility in minimum increments of $50 million up to a maximum of $100 million.

As of September 30, 2020, NJNG has two letters of credit outstanding for $731,000. NJNG’s letters of credit are used as collateral for remediation projects and expire in August 11, 2021. These letters of credit reduce the amount available under NJNG’s committed credit facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by the counterparty and they will be renewed as necessary.

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STOCK-BASED COMPENSATION

12 Months Ended

Sep. 30, 2020

Share-based Payment Arrangement [Abstract]

STOCK-BASED COMPENSATION

10. STOCK-BASED COMPENSATION

In January 2017, the NJR 2017 Stock Award and Incentive Plan replaced the NJR 2007 Stock Award and Incentive Plan. Shares have been issued in the form of performance share units, restricted stock units, deferred retention stock units and unrestricted common stock to non-employee directors. As of September 30, 2020, 3,189,550 shares remain available for future issuance.

The following table summarizes all stock-based compensation expense recognized during the following fiscal years:

(Thousands)	2020		2019		2018
Stock-based compensation expense:
Performance share awards	$	1,943	$	5,804	$	3,526
Restricted and non-restricted stock	2,868		2,492		2,191
Deferred retention stock	1,725		1,500		7,128
Compensation expense included in operation and maintenance expense	6,536		9,796		12,845
Income tax benefit (1)	(1,900)		(2,848)		(3,734)
Total, net of tax	$	4,636	$	6,948	$	9,111

(1)Excludes additional tax benefit related to delivered shares of $647,000, $1.3 million and $3 million as of September 30, 2020, 2019 and 2018, respectively.

Performance Share Units

In fiscal 2020, the Company granted to certain officers 33,123 performance shares, which are market condition awards that vest on September 30, 2022, subject to the Company meeting certain conditions. In fiscal 2020, the Company also granted to certain officers 48,941 performance shares, of which 30,473 vest on September 30, 2022 and 18,468 vest annually over a three-year period beginning in September 2020, both of which are subject to the Company meeting certain performance conditions.

In fiscal 2019, the Company granted to certain officers 36,392 performance shares, which are market condition awards that vest on September 30, 2021, subject to the Company meeting certain conditions. In fiscal 2019, the Company also granted to certain officers 63,870 performance shares, of which 33,844 vest on September 30, 2021 and 30,026 vest annually over a three-year period beginning in September 2019, both of which are subject to the Company meeting certain performance conditions.

In fiscal 2018, the Company granted to certain officers 31,836 performance shares, which are market condition awards that vested on September 30, 2020, subject to the Company meeting certain conditions. In fiscal 2018, the Company also granted to certain officers 59,341 performance shares, of which 29,608 vested in September 30, 2020 and 29,733 vest annually over a three-year period beginning in September 2018, both of which were subject to the Company meeting certain performance conditions. The vesting of these awards are shown in the table below.

There is approximately $2.4 million of deferred compensation related to unvested performance shares that is expected to be recognized over the weighted average period of 1.7 years.

The following table summarizes the performance share activity under the stock award and incentive plans for the past three fiscal years:

	Shares (1)	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Non-vested and outstanding at September 30, 2017	156,587		$30.12		—
Granted	91,177		$44.67		—
Vested (2)	(100,146)		$29.49		$	4,714
Cancelled/forfeited	(2,442)		$31.45		—
Non-vested and outstanding at September 30, 2018	145,176		$39.67		—
Granted	100,262		$47.98		—
Vested (3)	(103,009)		$38.52		$	4,622
Cancelled/forfeited	(11,920)		$44.34		—
Non-vested and outstanding at September 30, 2019	130,509		$46.53		—
Granted	82,064		$40.61		—
Vested (4)	(55,025)		$44.27		$	2,083
Cancelled/forfeited	(1,817)		$44.38		—
Non-vested and outstanding at September 30, 2020	155,731		$44.22		—

(1)The number of common shares issued related to certain performance shares may range from zero to 150 percent of the number of shares shown in the table above based on the Company’s achievement of performance goals.

(2)As certified by the Company’s Leadership and Compensation Committee on November 13, 2018, the number of common shares related to performance shares earned was 99 percent, or 38,660 shares, the number of common shares earned related to NFE performance was 121 percent or 39,694 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 36,998 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

(3)As certified by the Company’s Leadership and Compensation Committee on November 12, 2019, the number of common shares earned related to TSR performance was 119 percent or 43,641 shares, the number of common shares earned related to NFE performance was 117 percent or 26,413 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 24,468 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

(4)As certified by the Company’s Leadership and Compensation Committee on November 9, 2020, there were no common shares earned related to TSR performance, the number of common shares earned related to NFE performance was 114 percent or 28,513 shares and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 11,139 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

The Company measures compensation expense related to performance shares based on the fair value of these awards at their date of grant. In accordance with ASC 718, Compensation - Stock Compensation, compensation expense for market condition grants are recognized for awards granted, and are not adjusted based on actual achievement of the performance goals. The Company estimated the fair value of these grants on the date of grant using a lattice model. Performance condition grants

are initially fair valued at the Company’s stock price on grant date, and are subsequently adjusted for actual achievement of the performance goals.

Restricted Stock Units

In fiscal 2020, the Company granted 42,478 shares of restricted stock units that vest annually over a three-year period beginning October 2020. In fiscal 2019, the Company granted 29,222 shares of restricted stock that vest annually over a three-year period beginning in October 2019. In fiscal 2019, the Company also granted 6,062 shares of restricted stock that vest annually over a three-year period beginning April 2020. In fiscal 2018, the Company granted 27,949 shares of restricted stock that vest annually over a three-year period beginning in October 2018. There is approximately $1 million of deferred compensation related to unvested restricted stock shares that is expected to be recognized over the weighted average period of 1.8 years.

The following table summarizes the restricted stock activity under the stock award and incentive plans for the past three fiscal years:

	Shares	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Non-vested and outstanding at September 30, 2017	51,154		$32.40		—
Granted	27,949		$45.00		—
Vested	(33,815)		$31.23		$	1,438
Cancelled/forfeited	(1,120)		$33.54		—
Non-vested and outstanding at September 30, 2018	44,168		$41.24		—
Granted	35,284		$48.24		—
Vested	(20,748)		$39.26		$	935
Cancelled/forfeited	(548)		$42.96		—
Non-vested and outstanding at September 30, 2019	58,156		$46.18		—
Granted	42,478		$40.61		—
Vested	(25,973)		$44.71		$	1,073
Cancelled/forfeited	(1,175)		$43.62		—
Non-vested and outstanding at September 30, 2020	73,486		$43.52		—

Deferred Retention Stock Units

Deferred retention stock awards are granted upon approval by the Board of Directors, which generally occurs subsequent to the fiscal year end. Deferred retention stock awards vest immediately when granted, with shares delivered at a future date in accordance with the terms of the underlying agreements. The expense for these awards is recognized in the fiscal year in which services are rendered. The following table summarizes the deferred retention stock award under the stock award and incentive plans for the past three fiscal years:

	Shares	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Outstanding at September 30, 2017	672,578		$29.54		—
Granted/Vested	24,167		$45.00		—
Delivered	(452,694)		$29.42		$	19,581
Forfeited	(1,969)		$35.56
Outstanding at September 30, 2018	242,082		$32.99		—
Granted/Vested	167,407		$47.95		—
Delivered	(158,733)		$30.32		$	7,145
Forfeited	(7,195)		$44.41		—
Outstanding at September 30, 2019	243,561		$44.67		—
Granted/Vested	42,358		$40.72		—
Delivered	(57,673)		$35.25		$	2,423
Outstanding at September 30, 2020	228,246		$46.32		—

Non-Employee Director Stock

Effective January 2020, non-employee director compensation includes an annual equity retainer that is awarded at the time of the Company’s annual meeting of shareowners. The shares vest upon the earlier of the first anniversary of the grant date or the date of the Company’s next annual meeting of shareowners following the grant date and are subsequently amortized to expense over a 12-month period. During fiscal years 2019 and 2018, the equity portion of non-employee director compensation was awarded in shares of NJR common stock. The shares vested immediately and were subsequently amortized to expense over a 12-month period. The following summarizes non-employee director share awards for the past three fiscal years:

	2020		2019	2018
Shares granted	27,696	(1)	26,165	26,524
Weighted average grant date fair value	$42.88		$44.80	$39.85

(1)$311,000 of expense remains as of September 30, 2020, to be recognized through December 31, 2020.

XML

EMPLOYEE BENEFIT PLANS

12 Months Ended

Sep. 30, 2020

Retirement Benefits [Abstract]

EMPLOYEE BENEFIT PLANS

11. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

The Company has two trusteed, noncontributory defined benefit retirement plans covering eligible regular represented and non-represented employees with more than one year of service. Defined benefit plan benefits are based on years of service and average compensation during the highest 60 consecutive months of employment. The Company also provides postemployment medical and life insurance benefits to employees who meet certain eligibility requirements.

All represented employees of NJRHS hired on or after October 1, 2000, non-represented employees hired on or after October 1, 2009 and NJNG represented employees hired on or after January 1, 2012, are covered by an enhanced defined contribution plan instead of the defined benefit plan. Participation in the postemployment medical and life insurance plan was also frozen to new employees as of the same dates, with the exception of new NJRHS represented employees, for which benefits were frozen beginning April 3, 2012.

The Company maintains an unfunded nonqualified PEP that was established to provide employees with the full level of benefits as stated in the qualified plan without reductions due to various limitations imposed by the provisions of federal income tax laws and regulations. There were no plan assets in the nonqualified plan due to the nature of the plan.

In April 2018, the Company implemented a voluntary early retirement program open to certain eligible employees. As of September 30, 2018, pension and postemployment benefit costs related to the special termination benefits were $4.2 million and other severance benefits were $2.2 million. For the amounts incurred, NJNG recognized an expense of approximately $5.1 million and Home Services and other recognized an expense of approximately $1.3 million, as a component of O&M in the Consolidated Statements of Operations.

The Company’s funding policy for its pension plans is to contribute at least the minimum amount required by the Employee Retirement Income Security Act of 1974, as amended. In fiscal 2020 and 2019, the Company had no minimum funding requirements. The Company made no discretionary contributions to the pension plans in fiscal 2020 or 2019. The Company does not expect to be required to make additional contributions to fund the pension plans over the following two fiscal years based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents.

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. The Company contributed $8.4 million and $7.9 million, in fiscal 2020 and 2019, respectively, and estimates that it will contribute between $5 million and $10 million over each of the next five years. Additional contributions may be required based on market conditions and changes to assumptions.

The Affordable Care Act was enacted in March 2010 and created an excise tax applicable to high-cost health plans, commonly known as the Cadillac Tax. Employers who sponsor health plans that have an annual cost that exceeded an amount defined by the law would pay a 40 percent tax on the excess plan costs beginning in 2022. The 2020 federal spending package permanently eliminated the Affordable Care Act-mandated Cadillac tax on high-cost employer-sponsored health coverage. Due to the repeal, the Company's OPEB liability was revalued for these changes. The Company applied a practical expedient to remeasure the plan assets and obligations as of December 31, 2019, which was the nearest calendar month-end date. The impact of the revaluation of the OPEB liability was recorded as of January 1, 2020 and is incorporated within actuarial assumptions at September 30, 2020.

The following summarizes the changes in the funded status of the plans and the related liabilities recognized on the Consolidated Balance Sheets as of September 30:

	Pension (1)				OPEB
(Thousands)	2020		2019		2020		2019
Change in Benefit Obligation
Benefit obligation at beginning of year	$	360,477	$	298,575	$	260,003	$	196,785
Service cost	8,223		7,381		4,854		4,404
Interest cost	10,587		12,173		7,026		8,324
Plan participants’ contributions (2)	25		43		194		210
Actuarial loss (gain)	29,738		52,549		(23,226)		54,700
Benefits paid, net of retiree subsidies received	(11,886)		(10,244)		(2,989)		(4,420)
Benefit obligation at end of year	$	397,164	$	360,477	$	245,862	$	260,003
Change in plan assets
Fair value of plan assets at beginning of year	$	288,634	$	279,410	$	83,925	$	77,980
Actual return on plan assets	30,632		19,194		6,872		2,499
Employer contributions	596		231		8,436		7,926
Benefits paid, net of plan participants’ contributions (2)	(11,894)		(10,201)		(2,827)		(4,479)
Fair value of plan assets at end of year	$	307,968	$	288,634	$	96,406	$	83,926
Funded status	$	(89,196)	$	(71,843)	$	(149,456)	$	(176,077)
Amounts recognized on Consolidated Balance Sheets
Postemployment employee (liability)
Current	$	(531)	$	(603)	$	(900)	$	(800)
Noncurrent	(88,665)		(71,240)		(148,556)		(175,277)
Total	$	(89,196)	$	(71,843)	$	(149,456)	$	(176,077)

(1)Includes the Company’s PEP.

(2)Prior to July 1, 1998, employees were eligible to elect an additional participant contribution to enhance their benefits and contributions made during the periods were insignificant.

The actuarial loss on the Company’s pension is primarily due to a decrease in the discount rate used to measure the benefit obligation. The actuarial gain related to the OPEB plans is primarily due to the remeasurement of the plan assets and obligations due to the removal of the Cadillac tax, partially offset by a decrease in the discount rate. The Company recognizes a liability for its underfunded benefit plans as required by ASC 715, Compensation - Retirement Benefits. The Company records the offset to regulatory assets for the portion of liability relating to NJNG and to accumulated other comprehensive income for the portion of the liability related to its unregulated operations.

The following table summarizes the amounts recognized in regulatory assets and accumulated other comprehensive income as of September 30:

	Regulatory Assets				Accumulated Other Comprehensive Income (Loss)
	Pension		OPEB		Pension		OPEB
Balance at September 30, 2018	$	66,233	$	68,685	$	14,633	$	7,659
Amounts arising during the period:
Net actuarial loss	38,137		48,452		14,271		9,264
Amounts amortized to net periodic costs:
Net actuarial (loss)	(4,662)		(5,820)		(1,103)		(648)
Prior service credit	(102)		312		—		53
Balance at September 30, 2019	$	99,606	$	111,629	$	27,801	$	16,328
Amounts arising during the period:
Net actuarial loss (gain)	11,953		(21,974)		7,731		(1,614)
Amounts amortized to net periodic costs:
Net actuarial (loss)	(7,893)		(6,536)		(2,528)		(907)
Prior service (cost) credit	(102)		182		—		16
Balance at September 30, 2020	$	103,564	$	83,301	$	33,004	$	13,823

The amounts in regulatory assets and accumulated other comprehensive income not yet recognized as components of net periodic benefit cost as of September 30 are:

	Regulatory Assets								Accumulated Other Comprehensive Income (Loss)
	Pension				OPEB				Pension				OPEB
(Thousands)	2020		2019		2020		2019		2020		2019		2020		2019
Net actuarial loss	$	103,197	$	99,139	$	83,600	$	112,109	$	33,004	$	27,801	$	13,847	$	16,367
Prior service cost (credit)	367		467		(299)		(480)		—		—		(24)		(39)
Total	$	103,564	$	99,606	$	83,301	$	111,629	$	33,004	$	27,801	$	13,823	$	16,328

To the extent the unrecognized amounts in accumulated other comprehensive income or regulatory assets exceed 10 percent of the greater of the benefit obligation or the fair value of plan assets, an amortized amount over the average expected future working lifetime of the active plan participants is recognized. Amounts included in regulatory assets and accumulated other comprehensive income expected to be recognized as components of net periodic benefit cost in fiscal 2021 are as follows:

	Regulatory Assets				Accumulated Other Comprehensive Income (Loss)
(Thousands)	Pension		OPEB		Pension		OPEB
Net actuarial loss	$	8,269	$	6,846	$	3,178	$	1,064
Prior service cost (credit)	102		(166)		—		(13)
Total	$	8,371	$	6,680	$	3,178	$	1,051

The accumulated benefit obligation for the pension plans, including the PEP, exceeded the fair value of plan assets. The projected benefit and accumulated benefit obligations and the fair value of plan assets as of September 30, are as follows:

	Pension
(Thousands)	2020		2019
Projected benefit obligation	$	397,164	$	360,477
Accumulated benefit obligation	$	352,320	$	319,527
Fair value of plan assets	$	307,968	$	288,634

The components of the net periodic cost for pension benefits, including the Company’s PEP, and OPEB costs (principally health care and life insurance) for employees and covered dependents for fiscal years ended September 30, are as follows:

	Pension						OPEB
(Thousands)	2020		2019		2018		2020		2019		2018
Service cost	$	8,223	$	7,381	$	8,139	$	4,854	$	4,404	$	4,607
Interest cost	10,587		12,173		10,493		7,026		8,324		6,365
Expected return on plan assets	(20,579)		(19,054)		(19,639)		(6,510)		(5,515)		(5,352)
Recognized actuarial loss	10,424		5,765		7,537		7,442		6,466		4,660
Prior service cost (credit) amortization	102		102		106		(197)		(365)		(365)
Net periodic benefit cost	8,757		$	6,367	$	6,636	$	12,615	$	13,314	9,915
Special termination benefit	—		—		3,730		—		—		490
Net periodic benefit cost recognized as expense	$	8,757	$	6,367	$	10,366	$	12,615	$	13,314	$	10,405

Assumptions

The weighted average assumptions used to determine the Company’s benefit costs during the fiscal years below and obligations as of September 30, are as follows:

	Pension								OPEB
	2020		2019			2018			2020		2019			2018
Benefit costs:
Discount rate	3.37/3.35%	(1)	4.36/4.35%		(1)	4.04/4.03%		(1)	3.48/3.44%	(1)	4.38/4.37%		(1)	4.12/4.08%		(1)
Expected asset return	7.25		7.00	%		7.50	%		7.25		7.00	%		7.50	%
Compensation increase	3.00/3.50%	(1)	3.25/3.50%		(1)	3.25/3.50%		(1)	3.00/3.50%	(1)	3.25/3.50%		(1)	3.25/3.50%		(1)
Obligations:
Discount rate	2.95/2.92%	(1)	3.37/3.35%		(1)	4.36/4.35%			3.08/3.03%	(1)	3.48/3.44%		(1)	4.38/4.37%		(1)
Compensation increase	3.00/3.50%	(1)	3.00/3.50%		(1)	3.25/3.50%		(1)	3.00/3.50%	(1)	3.00/3.50%		(1)	3.25/3.50%		(1)

(1)Percentages for represented and nonrepresented plans, respectively.

When measuring its projected benefit obligations, the Company uses an aggregate discount rate at which its obligation could be effectively settled. The Company determines a single weighted average discount rate based on a yield curve comprised of rates of return on a population of high quality debt issuances (AA- or better) whose cash flows (via coupons or maturities) match the timing and amount of its expected future benefit payments. The Company measures its service and interest costs using a disaggregated, or spot rate, approach. The Company applies the duration-specific spot rates from the full yield curve, as of the measurement date, to each year’s future benefit payments, which aligns the timing of the plans’ separate future cash flows to the corresponding spot rates on the yield curve.

Information relating to the assumed HCCTR used to determine expected OPEB benefits as of September 30, and the effect of a 1 percent change in the rate, are as follows:

($ in thousands)	2020		2019		2018
HCCTR	7.6%		7.6%		7.9%
Ultimate HCCTR	4.5%		4.5%		4.5%
Year ultimate HCCTR reached	2026		2026		2024
Effect of a 1 percentage point increase in the HCCTR on:
Year-end benefit obligation	$	49,106	$	49,061	$	36,260
Total service and interest cost	$	2,799	$	2,923	$	2,482
Effect of a 1 percentage point decrease in the HCCTR on:
Year-end benefit obligation	$	(38,844)	$	(38,747)	$	(28,743)
Total service and interest costs	$	(2,151)	$	(2,250)	$	(1,937)

The Company’s investment objective is a long-term real rate of return on assets before permissible expenses that is approximately 5 percent greater than the assumed rate of inflation, as measured by the consumer price index. The expected long-term rate of return is based on the asset categories in which the Company invests and the current expectations and historical performance for these categories.

The mix and targeted allocation of the pension and OPEB plans’ assets are as follows:

	2021		Assets at
	Target		September 30,
Asset Allocation	Allocation		2020		2019
U.S. equity securities	34	%	38	%	37	%
International equity securities	17		18		17
Fixed income	38		39		42
Other assets	11		5		4
Total	100	%	100	%	100	%

The Company adopted the revised mortality assumptions published by the Society of Actuaries for its pension and other postemployment benefit obligations, which reflected increased life expectancies in the U.S. The adoption of the new mortality projection scale, MP-2019 and the Pri-2012 mortality study, did not materially impact the projected benefit obligation for the plans.

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following fiscal years:

(Thousands)	Pension		OPEB
2021	$	12,799	$	6,179
2022	$	13,765	$	6,837
2023	$	14,512	$	7,420
2024	$	15,345	$	7,988
2025	$	16,267	$	8,625
2026 - 2030	$	95,969	$	52,480

The Company’s OPEB plans provide prescription drug benefits that are actuarially equivalent to those provided by Medicare Part D. Therefore, under the Medicare Prescription Drug, Improvement and Modernization Act of 2003, the Company qualifies for federal subsidies.

The following estimated subsidy payments are expected to be paid during the following fiscal years:

	Estimated Subsidy
(Thousands)	Payment
2021		$	292
2022		$	316
2023		$	349
2024		$	384
2025		$	420
2026 - 2030		$	2,789

Pension and OPEB assets held in the master trust, measured at fair value, as of September 30, are summarized as follows:

(Thousands)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Total
As of September 2020:	Pension				OPEB
Assets
Money market funds	$	—	$	—	$	15	$	15
Registered Investment Companies:
Equity Funds:
Large Cap Index	95,542		95,542		29,908		29,908
Extended Market Index	21,085		21,085		6,470		6,470
International Stock	56,912		56,912		17,390		17,390
Fixed Income Funds:
Emerging Markets	16,008		16,008		4,958		4,958
Core Fixed Income	—		—		11,146		11,146
Opportunistic Income	—		—		7,128		7,128
Ultra Short Duration	—		—		7,057		7,057
High Yield Bond Fund	26,303		26,303		8,223		8,223
Long Duration Fund	77,036		77,036		—		—
Total assets at in the fair value hierarchy	$	292,886	292,886		$	92,295	92,295
Investments measured at net asset value
Common collective trusts			15,082				4,111
Total assets at fair value			$	307,968			$	96,406

(Thousands)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Total
As of September 30, 2019:	Pension				OPEB
Assets
Money market funds	$	—	$	—	$	21	$	21
Registered Investment Companies:
Equity Funds:
Large Cap Index	89,374		89,374		25,474		25,474
Extended Market Index	16,548		16,548		5,036		5,036
International Stock	49,929		49,929		14,564		14,564
Fixed Income Funds:
Emerging Markets	15,794		15,794		4,764		4,764
Core Fixed Income	—		—		10,570		10,570
Opportunistic Income	—		—		6,365		6,365
Ultra Short Duration	—		—		6,340		6,340
High Yield Bond Fund	24,328		24,328		7,350		7,350
Long Duration Fund	80,041		80,041		—		—
Total assets at in the fair value hierarchy	$	276,014	276,014		$	80,484	80,484
Investments measured at net asset value
Common collective trusts			12,620				3,442
Total assets at fair value			$	288,634			$	83,926

The Plan had no Level 2 or Level 3 fair value measurements during fiscal 2020 and 2019, and there have been no changes in valuation methodologies as of September 30, 2020. The Plan held assets that are valued using net asset value as a practical expedient, which are excluded from the fair value hierarchy.

The following is a description of the valuation methodologies used for assets measured at fair value:

Money Market funds — Represents bank balances and money market funds that are valued based on the net asset value of shares held at year end.

Registered Investment Companies — Equity and fixed income funds valued at the net asset value of shares held by the plan at year end as reported on the active market on which the individual securities are traded.

Common collective trusts — The NAV for common collective trusts is provided by the trustee and is used as a practical expedient to estimate fair value. The NAV is based on the value of the underlying assets owned by the fund less liabilities.

The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Furthermore, while the Plan believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.

Defined Contribution Plan

The Company offers a Savings Plan to eligible employees. The Company matches 80 percent of participants’ contributions up to 6 percent of base compensation. Represented NJRHS employees, non-represented employees hired on or after October 1, 2009, and NJNG represented employees hired on or after January 1, 2012, are eligible for an employer special contribution of between 3.5 percent and 4.5 percent of base compensation, depending on years of service, into the Savings Plan on their behalf. The amount expensed and contributed for the matching provision of the Savings Plan was $4.5 million in fiscal 2020, $3.9 million in fiscal 2019 and $3.9 million in fiscal 2018. The amount contributed for the employer special contribution of the Savings Plan was $1.6 million in fiscal 2020, $1.3 million in fiscal 2019 and $959,000 in fiscal 2018.

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ASSET RETIREMENT OBLIGATIONS

12 Months Ended

Sep. 30, 2020

Asset Retirement Obligation Disclosure [Abstract]

ASSET RETIREMENT OBLIGATIONS

12. ASSET RETIREMENT OBLIGATIONS

The Company recognizes ARO when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. Accordingly, the Company recognizes ARO related to the costs associated with cutting and capping its main and service natural gas distribution pipelines of NJNG, which is required by New Jersey law when taking such natural gas distribution pipeline out of service. The Company also recognizes ARO related to Clean Energy Ventures’ solar assets when there are decommissioning provisions in Clean Energy Ventures’ lease agreements that require removal of the asset.

Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets. Accretion amounts associated with Clean Energy Ventures’ ARO are recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations.

The following is an analysis of the change in the Company’s ARO for the fiscal years ended September 30:

(Thousands)	2020				2019
	NJNG		NJRCEV		NJNG		NJRCEV
Balance at October 1	$	26,944	$	4,102	$	25,640	$	3,048
Accretion	1,476		196		1,427		150
Additions	—		1,306		135		904
Change in estimated useful life	—		(1,160)		—		—
Change in assumptions	1,104		—		—		—
Retirements	(244)		—		(258)		—
Other	—		—		—		—
Balance at period end	$	29,280	$	4,444	$	26,944	$	4,102

Accretion for the next five years, for the fiscal years ended September 30, is estimated to be as follows:

	Estimated
(Thousands)	Accretion
2021	$	1,717
2022	1,789
2023	1,869
2024	1,948
2025	2,029
Total	$	9,352

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INCOME TAXES

12 Months Ended

Sep. 30, 2020

Income Tax Disclosure [Abstract]

INCOME TAXES

13. INCOME TAXES

The income tax benefit from operations for the fiscal years ended September 30, consists of the following:

(Thousands)	2020		2019		2018
Current:
Federal	$	(2,164)	$	10,933	$	(2,848)
State	6,763		3,530		4,563
Deferred:
Federal	28,817		4,103		(40,138)
State	3,400		4,003		7,181
Investment/production tax credits	(322)		(4,129)		(10,990)
Income tax expense (benefit)	$	36,494	$	18,440	$	(42,232)

As of September 30, the temporary differences, which give rise to deferred tax assets (liabilities), consist of the following:

(Thousands)	2020		2019
Deferred tax assets
Investment tax credits (1)	$	194,840	$	156,153
	—		—
Federal net operating losses (2)	24,091		24,173
State net operating losses	33,233		25,302
Fair value of derivatives	13,979		9,673
Postemployment benefits	8,544		9,192
Incentive compensation	7,071		7,231
Amortization of intangibles	5,892		4,991
Overrecovered natural gas costs	7,244		—
Other	2,370		7,139
Total deferred tax assets	$	297,264	$	243,854
Less: Valuation allowance	(17,639)		(4,035)
Total deferred tax assets net of valuation allowance	$	279,625	$	239,819
Deferred tax liabilities
Property related items	$	(359,604)	$	(313,246)
Remediation costs	(10,207)		(10,720)
Investments in equity investees	(23,395)		(21,730)
Underrecovered natural gas costs	—		(2,657)
Conservation incentive plan	(5,345)		(942)
Other	(6,639)		(4,776)
Total deferred tax liabilities	$	(405,190)	$	(354,071)
Total net deferred tax liabilities	$	(125,565)	$	(114,252)

(1)Includes $898,000 and $2 million for NJNG for fiscal 2020 and 2019, respectively, which is being amortized over the life of the related assets.

(2)See discussion of federal net operating loss utilization in the Other Tax Items section of this note.

A reconciliation of the U.S. federal statutory rate to the effective rate from operations for the fiscal years ended September 30, is as follows:

(Thousands)	2020			2019			2018
Statutory income tax expense	$	41,896		$	29,898		$	45,961
Change resulting from:
Investment/production tax credits	(322)			(4,129)			(10,990)
Cost of removal of assets placed in service prior to 1981	(5,362)			(6,349)			(5,829)
AFUDC equity	(4,933)			(2,313)			(2,117)
State income taxes, net of federal benefit	11,965			6,262			7,322
NJ Unitary method change	(15,345)			—			—
Valuation allowance	13,604			—			—
Tax Act - utility excess deferred income taxes amortized (1)	(3,573)			(3,573)			(1,786)
Tax Act - nonutility excess deferred income taxes (1)	—			—			(59,627)
Tax Act - utility excess deferred income taxes refunded to customers (1)	—			—			(14,323)
Other	(1,436)			(1,356)			(843)
Income tax expense (benefit)	$	36,494		$	18,440		$	(42,232)
Effective income tax rate (2) (3)	18.3		%	14.0		%	(23.9)		%

(1)For a more detailed description, see The Tax Act section of this note.

(2)The U.S. federal statutory rate was 21 percent for both fiscal 2020 and 2019 and 24.5 percent for fiscal 2018.

(3)The effective tax rate without the impact of the Tax Act would have been 12.4 percent for fiscal 2018.

The Company and one or more of its subsidiaries files or expects to file income and/or franchise tax returns in the U.S. Federal jurisdiction and in the states of Colorado, Connecticut, Delaware, Louisiana, Maryland, New Jersey, North Carolina, Pennsylvania, Texas, Mississippi and Virginia. The Company neither files in, nor believes it has a filing requirement in, any foreign jurisdictions other than Canada. Due to certain available tax treaty benefits, the Company incurs no tax liability in Canada.

The Company’s federal income tax returns through fiscal 2014 have either been reviewed by the IRS, or the related statute of limitations has expired and all matters have been settled. Federal income tax returns for periods subsequent to fiscal 2014 are open to examination or are currently under examination by the IRS. For all periods subsequent to those ended September 30, 2016, the Company’s state income tax returns are statutorily open to examination in all applicable states with the exception of Colorado, New Jersey and Texas. In Colorado, New Jersey and Texas, all periods subsequent to September 30, 2015 are statutorily open to examination.

In May 2019, the Company received a favorable ruling from the IRS regarding a change to its tax method of accounting for the capitalization of certain costs associated with self-constructed property placed in service during fiscal years prior to September 30, 2015. The self-constructed property to which these costs relate is considered qualified energy property as defined under the Internal Revenue Code. As such, the Company is eligible to claim a 30 percent ITC on the increase in the depreciable cost basis of the property through the filing of an amended tax return in the year of change. As a result of the favorable IRS ruling, the Company recorded an addition to its contra asset, which is amortized over the life of the productive assets.

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

As of September 30, 2020, the Company evaluated certain tax benefits that have been recorded in the financial statements and concluded that a portion of the tax benefits are uncertain at this time. As a result, the Company recorded a reserve that is netted against deferred income taxes on the Consolidated Balance Sheets. The tax benefits relate to fiscal tax years open to examination by the IRS and may be subject to subsequent adjustment. The reserve for uncertain tax benefits for the fiscal year ended September 30, is as follows:

(Thousands)	2020		2019
Balance at October 1,	$	4,930	$	—
Additions based on tax positions related to the current fiscal period	—		4,930
Balance at period end	$	4,930	$	4,930

CARES Act

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

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

Other Tax Items

As of September 30, 2020 and 2019, the Company has federal income tax net operating losses of approximately $134 million. Federal net operating losses can generally be carried back two years and forward 20 years and will begin to expire in fiscal 2036, with the remainder expiring by 2038. The Company expects to exercise its ability to carryback federal net operating losses to offset taxable income in prior periods.

For the net operating losses it expects to carryback, the Company estimated the portion considered refundable and recorded receivables of approximately $22.8 million as of September 30, 2020 and 2019, as a component of other noncurrent assets on the Consolidated Balance Sheets. Upon filing amended federal income tax returns to carryback its remaining federal net operating losses totaling $24.1 million, the Company will reduce its taxable income in those periods and recapture federal investment tax credits of the same amount that were previously utilized to offset taxable income.

In addition, as of September 30, 2020 and 2019, the Company has tax credit carryforwards of approximately $195.2 million and $154.2 million, respectively, which each have a life of 20 years. When the Company carries back the federal net operating losses noted above, it expects to recapture investment tax credits totaling $24.1 million. These recaptured tax credits are in addition to the $195.2 million and will be carried forward to offset future taxable income. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2034.

As of September 30, 2020 and 2019, the Company has state income tax net operating losses of approximately $487.7 million and $340 million, respectively. These state net operating losses have varying carry-forward periods dictated by the state in which they were incurred; these state carry-forward periods range from seven to 20 years and would begin to expire in fiscal 2021, with the majority expiring after 2035. The Company expects to utilize this entire carryforward, other than as described below.

On February 7, 2019, Clean Energy Ventures finalized the sale of its remaining wind assets. As a result of the sale, it is more likely than not that certain state net operating loss carryforwards will not be realizable prior to their expiration and recorded a valuation allowance related to state net operating loss carryforwards in Montana, Iowa and Kansas.

As a result of changes to filing requirements in the State of New Jersey that require tax returns filed for periods ending on or after July 31, 2019, be filed on a combined basis when part of an affiliated group, the Company recorded a benefit from income taxes, resulting from the re-measurement of deferred income tax attributes. The Company also evaluated its New Jersey state net operating loss carryforwards on a post-apportionment basis and determined it is more likely than not that a portion of these net operating loss carryforwards may not be realizable prior to their expiration. As a result, the Company recorded a valuation allowance associated with New Jersey state net operating loss carryforwards.

As of September 30, 2020 and 2019, the Company had a valuation allowance of $17.6 million and $4 million related to state net operating loss carryforwards.

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 will decline to 26 percent for property under construction during 2020, and to 22 percent for property under construction during 2021. For any property that is under construction before 2022, but not placed in service before 2024, the ITC will be reduced to 10 percent.

The Tax Act

On December 22, 2017, the President signed into law the Tax Act. The law made several changes to the Internal Revenue Code of 1986, as amended, the most impactful to the Company of which was a reduction in the federal corporate income tax rate from 35 percent to 21 percent that became effective January 1, 2018. Since the Company's fiscal year end is September 30, it is required by the Internal Revenue Code to calculate a statutory rate based upon the federal tax rates in effect before and after the effective date of the change in the taxable year that includes the effective date. Accordingly, the Company applied a federal statutory tax rate of 24.5 percent during fiscal 2018 and as of October 1, 2018, used the enacted rate of 21 percent. As a result of the changes associated with the Tax Act during fiscal 2019, the Company recognized a tax benefit of $59.6 million.

As a result of the changes associated with the Tax Act, NJNG recorded a decrease in its net deferred tax liability of $228.4 million, which included $164.3 million for the revaluation of its deferred income taxes and $64.1 million for the accounting of the income tax effects on the revaluation of those deferred income taxes. These amounts were recorded as a regulatory liability on the Consolidated Balance Sheets. On May 22, 2018, the BPU approved a refund of $31 million, which included approximately $20.1 million of the initial revaluation of excess deferred income taxes, $9 million for the overcollection of taxes from customers from January 1, 2018 through March 31, 2018, and interest on the overcollected taxes at the Company's short-term debt rate. These credits were returned to customer accounts in June 2018.

During fiscal 2018, NJNG credited approximately $17 million to income tax (benefit) provision on the Consolidated Statements of Operations, which includes $14.3 million attributable to the remeasurement of deferred income taxes, $1.8 million for the amortization of excess deferred income taxes primarily related to timing differences associated with utility plant depreciation and $880,000 related to the revaluation of deferred income taxes not included in base rates. As of September 30, 2020, the regulatory liability included excess deferred income taxes of $195 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles.

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LEASES

12 Months Ended

Sep. 30, 2020

Leases [Abstract]

LEASES

14. LEASES

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and leased 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. The Company’s land leases and office equipment 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. For more information on the adoption of ASC 842, Leases, see Note 2. Summary of Significant Accounting Policies.

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. These variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use asset and lease 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.

The Company’s solar land lease terms are primarily between 15 and 35 years, which includes options to extend the terms for multiple additional 5 to 10 years each. The Company’s office leases vary in duration, ranging from 1 to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of 7 years with purchase options available prior to the end of the 7 year term. Equipment leases include general office equipment that also vary in duration, most are for a term of 5 years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The expense related to the leases subject to the short-term lease recognition exemption are recognized on a straight-line basis, with such amounts disclosed in the financial statement notes below.

The Company has lease agreements with lease and nonlease components and has elected the practical expedient to combine lease and nonlease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not significant to the Company. The Company’s lease agreements do not contain any

material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

The following table presents the Company's lease costs included in the Consolidated Statements of Operations for the fiscal year ended September 30:

(Thousands)	Income Statement Location	2020
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	5,007
Interest on lease liabilities	Interest expense, net of capitalized interest	1,511
Total finance lease cost		6,518
Operating lease cost	Operation and maintenance, net of capitalized costs	$	6,404
Short-term lease cost	Operation and maintenance	1,041
Variable lease cost	Operation and maintenance	1,025
Total lease cost		$	14,988

The following table presents supplemental cash flow information related to leases for the fiscal year ended September 30:

(Thousands)	2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	8,804
Operating cash flows from finance leases	$	1,189
Financing cash flows from finance leases	$	6,985

Assets obtained or modified through amendments in exchange for operating lease liabilities during fiscal 2020 were $76.6 million. Assets obtained or modified through amendments in exchange for finance lease liabilities during fiscal 2020, were $49.7 million.

The following table presents the balance and classifications of our right of use assets and lease liabilities included in the Consolidated Balance Sheets for the fiscal year ended September 30:

(Thousands)	Balance Sheet Location	2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	131,769
Finance lease assets	Utility plant	71,085
Total lease assets		$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	6,724
Finance lease liabilities	Current maturities of long-term debt	10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	95,030
Finance lease liabilities	Long-term debt	63,743
Total lease liabilities		$	175,913

As of September 30, 2020, the weighted average remaining lease term for the operating and finance leases is 25.5 and 11.5 years, respectively. The weighted average discount rate used in the valuation of the operating and finance lease liabilities and right-of-use assets over the remaining lease term is 3.18 percent and 2.5 percent, respectively.

The following table presents the Company's maturities of lease liabilities as of September 30, 2020:

(Thousands)	Operating Leases		Finance Leases
2021	$	6,706	$	54,992
2022	6,634		6,004
2023	6,590		4,622
2024	6,210		5,279
2025	5,646		3,396
Thereafter	122,085		2,324
Total future lease payments	153,871		76,617
Less: Liability accretion	(52,117)		(2,458)
Total lease liability	$	101,754	$	74,159

The following table reflects the Company's future minimum lease payments due under non-cancelable operating leases for continuing operations as of September 30, 2019, under ASC 840 and is being presented for comparative purposes. These commitments relate principally to commercial solar land leases, equipment and real property leases, including land and office facility leases, natural gas meters and office equipment.

(Thousands)	Operating Leases		Finance Leases
2020	$	4,411	$	11,707
2021	$	4,698	$	6,603
2022	$	4,609	$	7,494
2023	$	4,579	$	3,995
2024	$	4,199	$	4,652
Thereafter	$	54,405	$	4,173

On August 14, 2020, the Company entered into a partial termination agreement of its lease contracts associated with its natural gas cavern storage. As a result of the partial termination, the Company paid $28.5 million to the lease owners receiving in return a 50 year non-compete agreement. The Company treated these Leaf River lease arrangements as one combined contract and its termination was recognized as remeasurement of the remaining lease assets that will be amortized over the remaining part of the lease lives.

LEASES

14. LEASES

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and leased 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. The Company’s land leases and office equipment 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. For more information on the adoption of ASC 842, Leases, see Note 2. Summary of Significant Accounting Policies.

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. These variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use asset and lease 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.

The Company’s solar land lease terms are primarily between 15 and 35 years, which includes options to extend the terms for multiple additional 5 to 10 years each. The Company’s office leases vary in duration, ranging from 1 to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of 7 years with purchase options available prior to the end of the 7 year term. Equipment leases include general office equipment that also vary in duration, most are for a term of 5 years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The expense related to the leases subject to the short-term lease recognition exemption are recognized on a straight-line basis, with such amounts disclosed in the financial statement notes below.

The Company has lease agreements with lease and nonlease components and has elected the practical expedient to combine lease and nonlease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not significant to the Company. The Company’s lease agreements do not contain any

material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

The following table presents the Company's lease costs included in the Consolidated Statements of Operations for the fiscal year ended September 30:

(Thousands)	Income Statement Location	2020
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	5,007
Interest on lease liabilities	Interest expense, net of capitalized interest	1,511
Total finance lease cost		6,518
Operating lease cost	Operation and maintenance, net of capitalized costs	$	6,404
Short-term lease cost	Operation and maintenance	1,041
Variable lease cost	Operation and maintenance	1,025
Total lease cost		$	14,988

The following table presents supplemental cash flow information related to leases for the fiscal year ended September 30:

(Thousands)	2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	8,804
Operating cash flows from finance leases	$	1,189
Financing cash flows from finance leases	$	6,985

Assets obtained or modified through amendments in exchange for operating lease liabilities during fiscal 2020 were $76.6 million. Assets obtained or modified through amendments in exchange for finance lease liabilities during fiscal 2020, were $49.7 million.

The following table presents the balance and classifications of our right of use assets and lease liabilities included in the Consolidated Balance Sheets for the fiscal year ended September 30:

(Thousands)	Balance Sheet Location	2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	131,769
Finance lease assets	Utility plant	71,085
Total lease assets		$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	6,724
Finance lease liabilities	Current maturities of long-term debt	10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	95,030
Finance lease liabilities	Long-term debt	63,743
Total lease liabilities		$	175,913

As of September 30, 2020, the weighted average remaining lease term for the operating and finance leases is 25.5 and 11.5 years, respectively. The weighted average discount rate used in the valuation of the operating and finance lease liabilities and right-of-use assets over the remaining lease term is 3.18 percent and 2.5 percent, respectively.

The following table presents the Company's maturities of lease liabilities as of September 30, 2020:

(Thousands)	Operating Leases		Finance Leases
2021	$	6,706	$	54,992
2022	6,634		6,004
2023	6,590		4,622
2024	6,210		5,279
2025	5,646		3,396
Thereafter	122,085		2,324
Total future lease payments	153,871		76,617
Less: Liability accretion	(52,117)		(2,458)
Total lease liability	$	101,754	$	74,159

The following table reflects the Company's future minimum lease payments due under non-cancelable operating leases for continuing operations as of September 30, 2019, under ASC 840 and is being presented for comparative purposes. These commitments relate principally to commercial solar land leases, equipment and real property leases, including land and office facility leases, natural gas meters and office equipment.

(Thousands)	Operating Leases		Finance Leases
2020	$	4,411	$	11,707
2021	$	4,698	$	6,603
2022	$	4,609	$	7,494
2023	$	4,579	$	3,995
2024	$	4,199	$	4,652
Thereafter	$	54,405	$	4,173

On August 14, 2020, the Company entered into a partial termination agreement of its lease contracts associated with its natural gas cavern storage. As a result of the partial termination, the Company paid $28.5 million to the lease owners receiving in return a 50 year non-compete agreement. The Company treated these Leaf River lease arrangements as one combined contract and its termination was recognized as remeasurement of the remaining lease assets that will be amortized over the remaining part of the lease lives.

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COMMITMENTS AND CONTINGENT LIABILITIES

12 Months Ended

Sep. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENT LIABILITIES

15. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through October 2036, for the supply, transportation and storage of natural gas. These contracts include annual fixed charges of approximately $124.7 million at current contract rates and volumes, which are recoverable through BGSS.

For the purpose of securing storage and pipeline capacity, our Energy Services segment enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by Energy Services to maintain the ability to access such natural gas storage or pipeline capacity, during a fixed time period, which generally ranges from one to 10 years. Demand charges are established by interstate storage and pipeline operators and are regulated by FERC. These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and/or transport natural gas utilizing their respective assets.

Commitments as of September 30, 2020, for natural gas purchases and future demand fees for the next five fiscal year periods, are as follows:

(Thousands)	2021		2022		2023		2024		2025		Thereafter
Energy Services:
Natural gas purchases	$	151,270	$	1,600	$	—	$	—	$	—	$	—
Storage demand fees	21,857		13,028		8,632		3,748		2,488		942
Pipeline demand fees	76,462		53,451		29,736		22,687		17,110		36,527
Sub-total Energy Services	$	249,589	$	68,079	$	38,368	$	26,435	$	19,598	$	37,469
NJNG:
Natural gas purchases	$	4,377	$	—	$	—	$	—	$	—	$	—
Storage demand fees	36,096		32,122		20,303		12,768		6,830		3,530
Pipeline demand fees	88,564		131,578		107,614		85,118		79,609		552,465
Sub-total NJNG	$	129,037	$	163,700	$	127,917	$	97,886	$	86,439	$	555,995
Total	$	378,626	$	231,779	$	166,285	$	124,321	$	106,037	$	593,464

As of September 30, 2020, the Company’s future minimum lease payments under various operating leases will not be more than $1.4 million annually for the next five years and $73,000 in the aggregate for all years thereafter.

Guarantees

As of September 30, 2020, there were NJR guarantees covering approximately $258 million of Energy Services’ natural gas purchases and demand fee commitments not yet reflected in accounts payable on the Consolidated Balance Sheets.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of certain former MGP sites, dating back to gas operations in the late 1800s and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the NJDEP, and participating in various studies and investigations by outside consultants, to determine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action, where warranted, under NJDEP regulations.

NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester, Toms River, and Freehold, New Jersey, collectively, the "former MGP sites", including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future expenditures at the former MGP sites for which it is responsible, including potential liabilities for further and continued natural resource damages, may be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites. As we have not yet completed the remedial investigation of the site, the total amount of potential costs of all remedial actions at the MGP site in Freehold, New Jersey, cannot be reasonably estimated at this time.

The estimated total future expenditures for all former MGP sites will range from approximately $143.1 million to $181.7 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, the Company accrues at the lower end of the range. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Consolidated Balance Sheets of $150.6 million as of September 30, 2020 and $131.1 million as of September 30, 2019, based on the most likely amount. The remediation liability at September 30, 2020 includes adjustments for actual expenditures during fiscal 2020. 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. As of September 30, 2019, costs associated with preliminary assessment activities were considered immaterial and included as a component of NJNG’s annual SBC application to recover remediation expenses. 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 is included in the MGP

remediation liability and corresponding regulatory asset on the Consolidated Balance Sheet at September 30, 2020. NJNG will continue to gather information to determine whether the obligation exists to undertake remedial action.

NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. On September 9, 2020,the BPU approved NJNG's an increase in the RAC, which increased the annual recovery from $8.5 million to $9.7 million and is effective October 1, 2020. As of September 30, 2020, $36.5 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Consolidated Balance Sheets. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination.

General

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

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

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COMMON STOCK EQUITY

12 Months Ended

Sep. 30, 2020

Equity [Abstract]

COMMON STOCK EQUITY

16. COMMON STOCK EQUITY

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

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

On September 18, 2020, the Company amended our forward sale agreements to extend the maturity date of such forward sales agreements from September 30, 2020 to September 10, 2021. As of September 30, 2020, if the Company elected to net settle the forward sale agreement, the Company would receive approximately $14.3 million under a cash settlement or would receive 543,150 common shares under a net share settlement.

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

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REPORTING SEGMENT AND OTHER OPERATIONS DATA

12 Months Ended

Sep. 30, 2020

Segment Reporting [Abstract]

REPORTING SEGMENT AND OTHER OPERATIONS DATA

17. 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 storage and transportation 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:

(Thousands)
Fiscal Years Ended September 30,	2020		2019		2018
Operating revenues
Natural Gas Distribution
External customers	$	729,923	$	710,793	$	731,865
Clean Energy Ventures
External customers	102,617		98,099		71,375
Energy Services
External customers (1)	1,029,303		1,734,553		2,064,477
Intercompany	1,116		8,238		48,327
Storage and Transportation
External customers (1)	42,015		—		—
Intercompany	2,713		—		—
Subtotal	1,907,687		2,551,683		2,916,044
Home Services and Other
External customers	49,810		48,600		47,392
Intercompany	1,207		2,302		2,665
Eliminations	(5,036)		(10,540)		(50,992)
Total	$	1,953,668	$	2,592,045	$	2,915,109
Depreciation and amortization
Natural Gas Distribution	$	71,883	$	57,980	$	53,208
Clean Energy Ventures	25,329		22,376		22,747
Energy Services (2)	123		118		76
Storage and Transportation	9,293		6		6
Subtotal	106,628		80,480		76,037
Home Services and Other	1,032		914		780
Eliminations	(292)		(285)		(246)
Total	$	107,368	$	81,109	$	76,571
Interest income (3)
Natural Gas Distribution	$	538	$	994	$	614
Clean Energy Ventures	240		—		—
Energy Services	99		78		240
Storage and Transportation	3,510		4,000		3,374
Subtotal	4,387		5,072		4,228
Home Services and Other	8,633		1,942		1,476
Eliminations	(10,061)		(5,391)		(5,090)
Total	$	2,959	$	1,623	$	614

(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 Consolidated Statements of Operations.

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

(Thousands)
Fiscal Years Ended September 30,	2020		2019		2018
Interest expense, net of capitalized interest
Natural Gas Distribution	$	30,975	$	26,134	$	25,299
Clean Energy Ventures	20,253		14,846		18,320
Energy Services	3,276		5,205		3,945
Storage and Transportation	13,124		2,185		1,667
Subtotal	67,628		48,370		49,231
Home Services and Other	10,327		1,535		7
Eliminations	(10,358)		(2,823)		(2,952)
Total	$	67,597	$	47,082	$	46,286
Income tax provision (benefit)
Natural Gas Distribution	$	27,021	$	9,434	$	(1,910)
Clean Energy Ventures	11,034		7,270		(68,379)
Energy Services	(3,615)		(1,573)		24,996
Storage and Transportation	4,247		2,254		(8,548)
Subtotal	38,687		17,385		(53,841)
Home Services and Other	(2,478)		1,428		11,944
Eliminations	285		(373)		(335)
Total	$	36,494	$	18,440	$	(42,232)
Equity in earnings of affiliates
Storage and Transportation	$	15,903	$	15,832	$	16,165
Eliminations	(1,592)		(2,204)		(3,157)
Total	$	14,311	$	13,628	$	13,008
Net financial earnings (loss)
Natural Gas Distribution	$	126,902	$	78,062	$	84,048
Clean Energy Ventures	22,111		31,903		73,426
Energy Services	(7,873)		2,918		60,378
Storage and Transportation	18,311		14,689		24,367
Subtotal	159,451		127,572		242,219
Home Services and Other	5,784		1,911		(3,829)
Eliminations	98		(93)		(327)
Total	$	165,333	$	129,390	$	238,063
Capital expenditures
Natural Gas Distribution	$	290,040	$	345,004	$	254,523
Clean Energy Ventures	133,841		157,828		123,421
Storage and Transportation	20,998		20,616		5,431
Subtotal	444,879		523,448		383,375
Home Services and Other	3,230		2,484		1,213
Total	$	448,109	$	525,932	$	384,588
Investments in equity investees
Storage and Transportation	$	2,117	$	4,102	$	16,151
Total	$	2,117	$	4,102	$	16,151

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:

(Thousands)	2020		2019		2018
Consolidated net financial earnings	$	165,333	$	129,390	$	238,063
Less:
Unrealized (gain) loss on derivative instruments and related transactions	(9,644)		2,881		26,770
Tax effect	2,296		(711)		(4,512)
Effects of economic hedging related to natural gas inventory	12,690		4,309		(22,570)
Tax effect	(3,016)		(1,024)		7,362
Consolidated net income	$	163,007	$	123,935	$	231,013

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. Additionally, realized derivative gains and losses are also included in current-period net income. However, NFE includes only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical natural gas flows. Included in the tax effects are current and deferred income tax expense corresponding with the non-GAAP measure. Also included in the tax effects during fiscal 2018, are the impacts of the Tax Act and resulting revaluation of the deferred income taxes that arose from derivative and hedging activity as measured under NFE. The revaluation caused the effective tax rate on reconciling items to differ from the statutory rate in effect for the year. The Company also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.

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

(Thousands)	2020		2019		2018
Assets at end of period:
Natural Gas Distribution	$	3,531,477	$	3,064,309	$	2,663,054
Clean Energy Ventures (1)	814,277		694,439		740,704
Energy Services	244,836		290,847		396,852
Storage and Transportation	844,799		240,955		242,069
Subtotal	5,435,389		4,290,550		4,042,679
Home Services and Other	138,375		104,411		114,732
Intercompany assets (2)	(257,287)		(237,019)		(171,107)
Total	$	5,316,477	$	4,157,942	$	3,986,304

(1)Includes assets held for sale of $206.9 million for September 30, 2018.

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

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RELATED PARTY TRANSACTIONS

12 Months Ended

Sep. 30, 2020

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

18. 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 September 30, 2020, Energy Services has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2020.

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

Demand fees, net of eliminations, associated with Steckman Ridge during the fiscal years ended September 30, are as follows:

(Thousands)	2020		2019		2018
Natural Gas Distribution	$	5,900	$	5,814	$	5,730
Energy Services	183		2,134		2,775
Total	$	6,083	$	7,948	$	8,505

The following table summarizes demand fees payable to Steckman Ridge as of September 30:

(Thousands)	2020		2019
Natural Gas Distribution	$	775	$	775
Energy Services	16		15
Total	$	791	$	790

NJNG and Energy Services have entered into various asset management agreements, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. As of September 30, 2020, NJNG and Energy Services had three asset management agreements with expiration dates ranging from October 31, 2020 through October 31, 2021.

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

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

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ACQUISITIONS AND DISPOSITIONS

12 Months Ended

Sep. 30, 2020

Business Combinations [Abstract]

ACQUISITIONS AND DISPOSITIONS

19. ACQUISITIONS AND DISPOSITIONS

Acquisitions

Adelphia Gateway

On January 13, 2020, Adelphia Gateway, an indirect wholly-owned subsidiary of NJR, acquired all of Talen’s membership interests in IEC, an existing 84-mile pipeline in southeastern Pennsylvania, including related assets and rights of way, for a base purchase price of $166 million. In November 2017, the Company made an initial payment of $10 million towards the base purchase price, which was included in other noncurrent assets on the Consolidated Balance Sheets. The remaining purchase price of $156 million was paid upon the close of the acquisition of the related assets. As additional consideration, Adelphia Gateway will pay Talen specified amounts of up to $23 million contingent upon the achievement of certain regulatory approvals and binding natural gas capacity commitments. On December 20, 2019, FERC issued Adelphia Gateway’s Certificate of Public Convenience and Necessity. Adelphia Gateway has agreed to provide firm natural gas transportation service for 10 years following the closing to two power generators owned by affiliates of Talen that are currently served by the pipeline.

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

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

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

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

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

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

Leaf River

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

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

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

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

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

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

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

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

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

Dispositions

Clean Energy Ventures

On June 1, 2018, Clean Energy Ventures completed the sale of its membership interest in its 9.7 MW wind farm in Two Dot, Montana to NorthWestern Energy for a total purchase price of $18.5 million. The transaction generated a pre-tax gain of approximately $951,000 which is recognized as a reduction to O&M on the Consolidated Statements of Operations.

On February 7, 2019, Clean Energy Ventures finalized the sale of its remaining wind assets to a subsidiary of Skyline Renewables LLC for a total purchase price of $208.6 million. The transaction generated a pre-tax gain of $645,000, which was recognized as a reduction to O&M expense on the Consolidated Statements of Operations.

Energy Services

On February 28, 2018, NJR sold all of the issued and outstanding shares of capital stock of NJRRS, which was a component of the Energy Services segment. The Company received $9.5 million in cash and a natural gas swap contract with a fair value of $14.6 million, which was recorded in derivatives, at fair value on the Consolidated Balance Sheets. The sale generated a pre-tax gain of $3.7 million, which was recognized as a reduction to O&M on the Consolidated Statements of Operations.

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SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)

12 Months Ended

Sep. 30, 2020

Quarterly Financial Information Disclosure [Abstract]

SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)

20. SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)

A summary of financial data for each quarter of fiscal 2020 and 2019 follows. Due to the seasonal nature of the Company’s businesses, quarterly amounts vary significantly during the fiscal year. In the opinion of management, the information furnished reflects all adjustments necessary for a fair presentation of the results of the interim periods.

	First		Second		Third		Fourth
(Thousands, except per share data)	Quarter		Quarter		Quarter		Quarter
2020
Operating revenues	$	615,036	$	639,614	$	298,974	$	400,044
Operating income (loss)	$	104,618	$	98,483	$	(16,847)	$	42,655
Net income (loss)	$	75,752	$	73,846	$	(19,298)	$	32,707
Earnings (loss) per share (1)
Basic	$0.82		$0.78		$(0.20)		$0.34
Diluted	$0.82		$0.77		$(0.20)		$0.34
2019
Operating revenues	$	811,767	$	866,255	$	434,942	$	479,081
Operating income (loss) (2)	$	91,273	$	79,606	$	(1,372)	$	(4,951)
Net income (loss)	$	75,371	$	73,671	$	(13,080)	$	(12,027)
Earnings (loss) per share (1)
Basic	$0.87		$0.83		$(0.15)		$(0.16)
Diluted	$0.87		$0.83		$(0.15)		$(0.17)

(1)The sum of quarterly amounts may not equal the annual amounts due to rounding.

(2)Quarterly amounts have been reclassified to conform to the current period presentation due to the adoption of ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits. See Note 2. Summary of Significant Accounting Policies.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

12 Months Ended

Sep. 30, 2020

Accounting Policies [Abstract]

Principles of Consolidation

Principles of Consolidation

The Consolidated Financial Statements include the accounts of the Company and its wholly-owned subsidiaries. All intercompany accounts and transactions have been eliminated.

Other financial investments or contractual interests that lack the characteristics of a voting interest entity, which are commonly referred to as variable interest entities, are evaluated by the Company to determine if the entity has the power to direct business activities and, therefore, would be considered a controlling interest that the Company would have to consolidate. Based on those evaluations, NJR has determined that it does not have any investments in variable interest entities as of September 30, 2020, 2019 and 2018.

Investments in entities over which the Company does not have a controlling financial interest are either accounted for under the equity method or cost method of accounting.

Use of Estimates

Use of Estimates

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

The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, a reserve is established if a loss is probable and can be reasonably estimated. 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, a reserve is established at 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 Consolidated Financial Statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the balance sheet date and reported amounts of revenue and expenses during the reporting periods presented. The Company considered the impacts of COVID-19 on the assumptions and estimates used and determined that there have been no material adverse impacts on the Company’s results of operations as of September 30, 2020.

Acquisitions

Acquisitions

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

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

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various assumptions and valuation methodologies requiring considerable management judgment. The most significant variables in these valuations are discount rates and the number of years on which to base the cash flow projections, as well as other assumptions and estimates used to determine the cash inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets and related cash flows. The valuation of an acquired business is based on available information at the acquisition date and assumptions that are believed to be reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date. See Note 19. Acquisitions and Dispositions for further information.

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

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

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

Our 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.

Natural Gas Purchases

Natural Gas Purchases

NJNG’s tariff includes a component for BGSS, which is designed to allow it to recover the cost of natural gas through rates charged to its customers and is typically revised on an annual basis. As part of computing its BGSS rate, NJNG projects its cost of natural gas, net of supplier refunds, the impact of hedging activities and cost savings created by BGSS incentive programs. NJNG subsequently recovers or credits the difference, if any, of actual costs compared with those included in current rates. Any underrecoveries or overrecoveries are either credited to customers or deferred and, subject to BPU approval, reflected in the BGSS rates in subsequent years.

Natural gas purchases at Energy Services are composed of natural gas costs to be paid upon completion of a variety of transactions, as well as realized gains and losses from settled derivative instruments and unrealized gains and losses on the change in fair value of derivative instruments that have not yet settled. Changes in the fair value of derivatives that economically hedge the forecasted purchases of natural gas are recognized in natural gas purchases as they occur.

Demand Fees

Demand Fees

For the purpose of securing storage and pipeline capacity in support of their respective businesses, the Energy Services and Natural Gas Distribution segments enter into storage and pipeline capacity contracts, which require the payment of associated demand fees and charges that allow them access to a high priority of service in order to maintain the ability to access storage or pipeline capacity during a fixed time period, which generally ranges from one to 10 years. Many of these demand fees and charges are based on established tariff rates as established and regulated by FERC. These charges represent commitments to pay storage providers and pipeline companies for the priority right to transport and/or store natural gas utilizing their respective assets.

The following table summarizes the demand charges, which are net of capacity releases, and are included as a component of natural gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30:

(Millions)	2020		2019		2018
Energy Services	$	121.8	$	120.4	$	153.0
Natural Gas Distribution	131.9		119.1		92.5
Total	$	253.7	$	239.5	$	245.5

Energy Services expenses demand charges over the term of the service being provided.

The Natural Gas Distribution segment’s costs associated with demand charges are included in its weighted average cost of natural gas. The demand charges are expensed based on NJNG’s BGSS sales and recovered as part of its natural gas commodity component of its BGSS tariff.

Operations and Maintenance Expenses

Operations and Maintenance Expenses

Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of vehicles, tools and equipment, payments to contractors, utility plant maintenance, amortization of software costs for unregulated entities, customer service, professional fees and other outside services, insurance expense, accretion of cost of removal for future retirements of utility assets and other administrative expenses and are expensed as incurred.

Stock Based Compensation

Stock-Based CompensationStock-based compensation represents costs related to stock-based awards granted to employees and members of NJR’s Board of Directors. NJR recognizes stock-based compensation based upon the estimated fair value of awards. The recognition period for these costs begins at either the applicable service inception date or grant date and continues throughout the requisite service period. The related compensation cost is recognized as O&M expense on the Consolidated Statements of Operations.

Sales Tax Accounting

Sales Tax Accounting

As a result of the adoption of ASC 606, Revenue from Contracts with Customers, as of October 1, 2018, the Company excludes from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales tax on a net basis in operating revenues on the Consolidated Statements of Operations. Prior to October 1, 2018, sales tax was presented in both operating revenues and operating expenses.

Income Taxes

Income Taxes

The Company computes income taxes using the asset and liability method, whereby deferred income taxes are generally determined based on the difference between the financial statement and tax basis of assets and liabilities using enacted tax rates in effect in the years in which the differences are expected to reverse. See Note 13. Income Taxes. In addition, the Company evaluates its tax positions to determine the appropriate accounting and recognition of future obligations associated with unrecognized tax benefits.

The Company invests in property that qualifies for federal ITCs and utilizes the ITCs, as allowed, based on the cost and life of the assets. ITCs at NJNG are deferred and amortized as a reduction to the tax provision over the average lives of the related equipment in accordance with regulatory treatment. ITCs at the unregulated subsidiaries of NJR are recognized as a reduction to the carrying value of the related asset when placed in service. ITCs are recognized in earnings as a reduction to depreciation expense over the productive life of the related property.

Projects placed in service through December 31, 2019, qualified for a 30-percent federal ITC. The credit declines to 26 percent for property under construction during 2020, 22 percent for property under construction during 2021 and 10 percent for any property that is under construction before 2022. The Company has taken steps to preserve the ITC at the higher rate for certain solar projects that are completed after the scheduled reduction in rates, in accordance with IRS guidance on safe harbor determination.

Investments in Equity Investees

Investments in Equity Investees

The Company accounts for its investments in Steckman Ridge and PennEast using the equity method of accounting where it is not the primary beneficiary, as defined under ASC 810, Consolidation, its respective ownership interests are 50 percent or less and/or it has significant influence over operating and management decisions. The Company’s share of earnings is recognized as equity in earnings of affiliates on the Consolidated Statements of Operations.

Equity method investments are reviewed for impairment when changes in facts and circumstances indicate that the current fair value may be less than the asset’s carrying amount. If the Company determines the decline in the value of its equity method investment is other than temporary, an impairment charge is recorded in an amount equal to the excess of the carrying value of the asset over its fair value.

Property Plant and Equipment

Property Plant and Equipment

Property, plant and equipment is stated at original cost. Costs include direct labor, materials and third-party construction contractor costs, capitalized interest and certain indirect costs related to equipment and employees engaged in construction. Utility plant and nonutility plant for Adelphia Gateway also includes AFUDC. Upon retirement, the cost of depreciable property, plus removal costs less salvage, is charged to accumulated depreciation with no gain or loss recorded.

Depreciation is computed on a straight-line basis over the useful life of the assets for our nonutility entities, and using rates based on the estimated average lives of the various classes of depreciable property for NJNG.

Capitalized and Deferred Interest

Capitalized and Deferred Interest

NJNG’s base rates include the ability to recover AFUDC on its construction work in progress. For all NJNG construction projects, an incremental cost of equity is recoverable during periods when NJNG’s short-term debt balances are lower than its construction work in progress. For more information on AFUDC treatment with respect to certain accelerated infrastructure projects, see Note 4. Regulation - Infrastructure Programs.

Capitalized amounts associated with the debt and equity components of NJNG’s AFUDC are recorded in utility plant on the Consolidated Balance Sheets. Corresponding amounts for the debt component are recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations.

Adelphia Gateway’s base rates include the ability to recover AFUDC on its construction work in progress. Beginning in the fourth quarter of fiscal 2020, capitalized amounts associated with Adelphia Gateway’s AFUDC are recorded in nonutility plant on the Consolidated Balance Sheets. Corresponding amounts are recorded in other income on the Consolidated Statements of Operations.

Clean Energy Ventures capitalizes interest on the allocation of the costs of debt borrowed for the financing of solar investments. Capitalized amounts are included in nonutility plant and equipment on the Consolidated Balance Sheets.

Cash and Cash Equivalents

Cash and Cash Equivalents

Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash related to escrow balances for utility plant projects, which is recorded in other noncurrent assets on the Consolidated Balance Sheets.

Loans Receivable

Loans Receivable

NJNG currently provides loans, with terms ranging from 2 to 10 years, to customers that elect to purchase and install certain energy-efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at fair value on the Consolidated Balance Sheets. The Company recorded $13.7 million and $12.4 million in other current assets and $35.3 million and $38.8 million in other noncurrent assets as of September 30, 2020 and 2019, respectively, on the Consolidated Balance Sheets, related to the loans. If NJNG determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of September 30, 2020 and 2019, the Company has not recorded any impairments for SAVEGREEN loans.

Regulatory Assets & Liabilities

Regulatory Assets & Liabilities

Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment.

Our Natural Gas Distribution segment maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and in accordance with the ASC 980, Regulated Operations. As a result of the impact of the ratemaking process and regulatory actions of the BPU, NJNG is required to recognize the economic effects of rate regulation. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of NJNG’s regulatory assets and liabilities.

In January 2020, NJR acquired Adelphia Gateway an existing 84-mile pipeline in southeastern Pennsylvania, which maintains its accounts in accordance with the FERC Uniform System of Accounts and in accordance with the ASC 980, Regulated Operations. Accordingly, Adelphia Gateway capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of Adelphia Gateway’s regulatory assets and liabilities.

Natural Gas in Storage

Natural Gas in StorageNatural gas in storage is reflected at average cost on the Consolidated Balance Sheets and represents natural gas and LNG that will be utilized in the ordinary course of business.

Derivative Instruments

Derivative Instruments

The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts and interest rate contracts, as well as its physical commodity contracts related to the purchase and sale of natural gas at Energy Services, as derivatives, and therefore recognizes them at fair value on the Consolidated Balance Sheets. The Company’s unregulated subsidiaries record changes in the fair value of their financial commodity derivatives in natural gas purchases and changes in

the fair value of their physical forward contracts in natural gas purchases or operating revenues, as appropriate, on the Consolidated Statements of Operations. Ineffective portions of the cash flow hedges are recognized immediately in earnings.

The ASC 815, Derivatives and Hedging also provides for a NPNS scope exception for qualifying physical commodity contracts for which physical delivery is probable and the quantities delivered are expected to be used or sold over a reasonable period of time in the normal course of business. Effective January 1, 2016, the Company prospectively applies this normal scope exception on a case-by-case basis to physical commodity contracts at NJNG and PPAs at Clean Energy Ventures. When applied, it does not account for these contracts until the contract settles and the related underlying natural gas or power is delivered. Gains and/or losses on NJNG’s derivatives used to economically hedge its regulated natural gas supply obligations, as well as its exposure to interest rate variability, are recoverable through its BGSS, a component of its tariff. Accordingly, the offset to the change in fair value of these derivatives is recorded as a regulatory asset or liability on the Consolidated Balance Sheets. See Note 5. Derivative Instruments for additional details regarding natural gas trading and hedging activities.

Fair values of exchange-traded instruments, including futures and swaps, are based on unadjusted, quoted prices in active markets. The Company’s non-exchange-traded financial instruments, foreign currency derivatives, over-the-counter physical commodity contracts at Energy Services and interest rate contracts are valued using observable, quoted prices for similar or identical assets when available. In establishing the fair value of contracts for which a quoted basis price is not available at the measurement date, management utilizes available market data and pricing models to estimate fair values. Fair values are subject to change in the near term and reflect management’s best estimate based on a variety of factors. Estimating fair values of instruments that do not have quoted market prices requires management’s judgment in determining amounts that could reasonably be expected to be received from, or paid to, a third party in settlement of the instruments. These amounts could be materially different from amounts that might be realized in an actual sale transaction.

During fiscal 2020, the Company entered into treasury lock transactions to fix the benchmark treasury rate associated with debt issuances for NJNG and NJR that occurred during the fiscal year. Settlement of the NJNG treasury locks resulted in a loss, which was recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the debt as a component of interest expense on the Consolidated Statements of Operations. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks resulted in a loss, which was recorded within OCI and will be amortized in earnings over the life of the debt as a component of interest expense on the Consolidated Statements of Operations. Amounts recognized in interest expense for NJNG and NJR related to the amortization of the loss on treasury lock transactions totaled $50,000 and $108,000, respectively, as of September 30, 2020.

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 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 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 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

NJNG’s physical and financial commodity derivatives, except for those designated as NPNS, are recognized at fair value on the Consolidated Balance Sheets. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Consolidated Balance Sheets. Effective January 1, 2016, the Company prospectively applies the NPNS scope exception on a case-by-case basis to certain qualifying physical commodity contracts. Contracts that are designated as NPNS are recognized in regulatory assets or liabilities on the Consolidated Balances Sheets upon settlement. The average cost of natural gas is charged to expense in the current-period earnings based on the BGSS factor times the therm sales.

Software Costs

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

Investments in Equity Securities

Investments in Equity Securities

Investments in equity securities were carried at fair value on the Consolidated Balance Sheets. For the fiscal year ended September 30, 2018, total unrealized gains and losses associated with equity securities were included as a part of accumulated other comprehensive income, a component of common stock equity, and reclassifications of realized gains or losses out of other comprehensive income into earnings were recorded in other income, net on the Consolidated Statements of Operations, based on average cost. On October 1, 2018, the Company adopted ASU No. 2016-01, an amendment to ASC 825, Financial Instruments. As a result, both realized and unrealized gains and losses were recorded in other income, net on the Consolidated Statements of Operations, based on average cost.

Intangible Assets and Long-Lived Assets

Intangible Assets

Finite-lived intangible assets are stated at cost less accumulated amortization. The Company amortizes intangible assets based upon the pattern in which the economic benefits are consumed over the life of the asset unless a pattern cannot be reliably determined, in which case the Company uses a straight-line amortization method. As of September 30, 2020, intangible assets consist primarily of acquired wholesale natural gas energy contracts totaling $10 million. The wholesale natural gas contracts are being amortized based upon expected cash flows over the respective terms of the agreements.

The estimated future amortization expense as of September 30, is as follows:

(Thousands)
2021	$	5,101
2022	$	2,611
2023	$	2,271
2024	$	77

Long-lived Assets

The Company reviews the recoverability of long-lived assets and finite-lived intangible assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable, such as significant adverse changes in regulation, business climate or market conditions, including prolonged periods of adverse commodity and capacity prices. If there are changes indicating that the carrying value of such assets may not be recoverable, an undiscounted cash flows test is performed. If the sum of the expected future undiscounted cash flows is less than the carrying amount of the asset, an impairment loss is recognized by reducing the recorded value of the asset to its fair value. Factors that the Company analyzes in determining whether an impairment in its long-lived assets exists include: a significant decrease in the market price of a long-lived asset; a significant adverse change in the extent in which a long-lived asset is being used in its physical condition; legal proceedings or other contributing factors; significant business climate changes; accumulations of costs in significant excess of the amounts expected; a current-period operating or cash flow loss combined with a history of such events; and current expectations that more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its estimated useful life. During fiscal 2020 and 2019, there were no events or circumstances that indicated that the carrying value of long-lived assets or finite-lived intangibles were not recoverable.

Debt Issuance Costs

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt. See Note 9. Debt for the total unamortized debt issuance costs that are recorded as a reduction to long-term debt on the Consolidated Balance Sheets.

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 Consolidated Balance Sheets. During fiscal 2020 and 2019, NJNG received $4 million and $9.9 million, respectively, in connection with the sale leaseback of its natural gas meters with terms ranging from seven to 11 years.

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

During fiscal 2020 and 2018, Clean Energy Ventures received proceeds of $42.9 million and $71.5 million, respectively, in connection with the failed sale leaseback of commercial solar assets. The proceeds received were recognized as a financing obligation on the Consolidated Balance Sheets. Clean Energy Ventures did not enter into any sale leaseback transactions for its commercial solar assets during fiscal 2019. Clean Energy Ventures simultaneously entered into agreements to lease the assets back over a term of five- to 15-years. The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from SRECs 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 Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease.

Environmental Contingencies

Environmental Contingencies 

Loss contingencies are recorded as liabilities when it is probable a liability has been incurred and the amount of the loss is reasonably estimable in accordance with accounting standards for contingencies. Estimating probable losses requires an analysis of uncertainties that often depend upon judgments about potential actions by third parties. Accruals for loss contingencies are recorded based on an analysis of potential results.

With respect to environmental liabilities and related costs, NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG’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. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries. NJNG will continue to seek recovery of MGP-related costs through the 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. See Note 15. Commitments and Contingent Liabilities for more details.

Pension and Postemployment Plans

Pension and Postemployment Plans

The Company has two noncontributory defined pension plans covering eligible employees, including officers. Benefits are based on each employee’s years of service and compensation. The Company’s funding policy is to contribute annually to these plans at least the minimum amount required under the Employee Retirement Income Security Act, as amended, and not more than can be deducted for federal income tax purposes. Plan assets consist of equity securities, fixed-income securities and short-term investments. The Company did not make any discretionary contributions to the pension plans in fiscal 2020, 2019 and 2018, respectively.

The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds.

Asset Retirement Obligations

Asset Retirement Obligations

The Company recognizes ARO related to the costs associated with cutting and capping NJNG’s main and service natural gas distribution mains, which is required by New Jersey law when taking such natural gas distribution mains out of service. The Company also recognizes ARO associated with Clean Energy Ventures’ solar assets when there are decommissioning provisions in lease agreements that require removal of the asset at the end of the lease term.

ARO are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations. Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets.

Estimating future removal costs requires management to make significant judgments because most of the removal obligations span long time frames and removal may be conditioned upon future events. Asset removal technologies are also constantly changing, which makes it difficult to estimate removal costs. Accordingly, inherent in the estimate of ARO are various assumptions including the ultimate settlement date, expected cash outflows, inflation rates, credit-adjusted risk-free rates and consideration of potential outcomes where settlement of the ARO can be conditioned upon events. In the latter case, the Company develops possible retirement scenarios and assigns probabilities based on management’s reasonable judgment and knowledge of industry practice. Accordingly, ARO are subject to change.

Foreign Currency Transactions

Foreign Currency Transactions

The market area of Energy Services includes Canadian delivery points and as a result, Energy Services incurs certain natural gas commodity costs and demand fees denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of natural gas purchases on the Consolidated Statements of Operations. Gains and losses recognized for the fiscal years ended September 30, 2020, 2019 and 2018, are considered immaterial.

Reclassification

Reclassification

Certain prior period amounts have been reclassified to conform to the current period presentation. Amounts related to energy and other taxes have been reclassified to O&M on the Consolidated Statements of Operations. Software costs previously recorded in other non-current assets have been reclassified to utility plant and software costs, and prepaid expenses previously recorded in other current assets have been reclassified on the Consolidated Balance Sheets. Certain amounts related to software costs previously reported in cash flows from operating activities have been reclassified to cash flows used in investing activities and prepaid expenses were reclassified within working capital on the Consolidated Statements of Cash Flows.

Change in Accounting Policy

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

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

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Operations during the fiscal years ended September 30, 2020, 2019 and 2018 are as follows:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Depreciation and amortization	$	119,894	(12,526)	$	107,368
Total operating expenses	$	1,737,285	(12,526)	$	1,724,759
Operating income	$	216,383	12,526	$	228,909
Income before income taxes and equity in earnings of affiliates	$	172,664	12,526	$	185,190
Income tax (benefit) expense	$	(6,944)	43,438	$	36,494
Net income	$	193,919	(30,912)	$	163,007
Weighted average shares outstanding
Diluted	95,107		(4)	95,103
Earnings per common share
Basic	$	2.05	(0.33)	$	1.72
Diluted	$	2.04	(0.33)	$	1.71
September 30, 2019
Depreciation and amortization	$	91,730	(10,621)	$	81,109
Total operating expenses	$	2,438,110	(10,621)	$	2,427,489
Operating income	$	153,935	10,621	$	164,556
Income before income taxes and equity in earnings of affiliates	$	118,126	10,621	$	128,747
Income tax (benefit) expense	$	(37,751)	56,191	$	18,440
Net income	$	169,505	(45,570)	$	123,935
Weighted average shares outstanding
Diluted	89,616		(20)	89,596
Earnings per common share
Basic	$	1.90	(0.51)	$	1.39
Diluted	$	1.89	(0.51)	$	1.38
September 30, 2018
Depreciation and amortization	$	85,701	(9,130)	$	76,571
Total operating expenses	$	2,715,227	(9,130)	$	2,706,097
Operating income	$	199,882	9,130	$	209,012
Income before income taxes and equity in earnings of affiliates	$	166,643	9,130	$	175,773
Income tax benefit	$	(53,785)	11,553	$	(42,232)
Net income	$	233,436	(2,423)	$	231,013
Earnings per common share
Basic	$	2.66	(0.03)	$	2.63
Diluted	$	2.64	(0.02)	$	2.62

The cumulative effect of the change in accounting policy on the Unaudited Condensed Consolidated Balance Sheets as of September 30, 2020 and 2019 are as follows:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Assets
Nonutility plant and equipment, at cost	$	1,430,723	(322,211)	$	1,108,512
Accumulated depreciation and amortization, nonutility plant and equipment	$	(202,507)	61,945	$	(140,562)
Property, plant and equipment, net	$	3,983,035	(260,266)	$	3,722,769
Other noncurrent assets	$	78,716	6,941	$	85,657
Total noncurrent assets	$	964,435	6,941	$	971,376
Total assets	$	5,569,802	(253,325)	$	5,316,477
Capitalization
Retained earnings	$	1,148,297	(200,796)	$	947,501
Common stock equity	$	1,844,692	(200,796)	$	1,643,896
Total capitalization	$	4,104,158	(200,796)	$	3,903,362
Liabilities
Deferred income taxes	$	190,610	(52,529)	$	138,081
Total noncurrent liabilities	$	931,922	(52,529)	$	879,393
Total capitalization and liabilities	$	5,569,802	(253,325)	$	5,316,477
September 30, 2019
Assets
Nonutility plant and equipment, at cost	$	861,904	(285,730)	$	576,174
Accumulated depreciation and amortization, nonutility plant and equipment	$	(156,033)	49,419	$	(106,614)
Property, plant and equipment, net	$	3,045,944	(236,311)	$	2,809,633
Other noncurrent assets	$	94,791	21,268	$	116,059
Total noncurrent assets	$	815,435	21,268	$	836,703
Total assets	$	4,372,985	(215,043)	$	4,157,942
Capitalization
Retained earnings	$	1,075,960	(169,884)	$	906,076
Common stock equity	$	1,551,717	(169,884)	$	1,381,833
Total capitalization	$	3,088,894	(169,884)	$	2,919,010
Liabilities
Deferred income taxes	$	190,663	(45,159)	$	145,504
Total noncurrent liabilities	$	837,714	(45,159)	$	792,555
Total capitalization and liabilities	$	4,372,985	(215,043)	$	4,157,942

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Cash Flows as of September 30, 2020, 2019 and 2018 are as follow:

(Thousands)	As Previously		Effect of	As
September 30, 2020	Reported		Change	Adjusted
Depreciation and amortization	$	119,894	(12,526)	$	107,368
Deferred income taxes	$	(9,092)	43,438	$	34,346
September 30, 2019
Depreciation and amortization	$	91,730	(10,621)	$	81,109
Deferred income taxes	$	(59,013)	56,191	$	(2,822)
September 30, 2018
Depreciation and amortization	$	85,701	(9,130)	$	76,571
Deferred income taxes	$	15,590	11,553	$	27,143

The impact of the change in accounting policy on the Unaudited Condensed Consolidated Statements of Common Stock Equity as of September 30, 2020, 2019 and 2018 are as follows:

	As Previously		Effect of	As
(Thousands)	Reported		Change	Adjusted
Retained Earnings
Balance at September 30, 2017	$	867,984	(121,891)	$	746,093
Net Income	$	233,436	(2,423)	$	231,013
Balance at September 30, 2018	$	1,007,117	(124,314)	$	882,803
Net Income	$	169,505	(45,570)	$	123,935
Balance at September 30, 2019	$	1,075,960	(169,884)	$	906,076
Net Income	$	193,919	(30,912)	$	163,007
Balance at September 30, 2020	$	1,148,297	(200,796)	$	947,501
Total Common stock equity
Balance at September 30, 2017	$	1,236,643	(121,891)	$	1,114,752
Net Income	$	233,436	(2,423)	$	231,013
Balance at September 30, 2018	$	1,418,978	(124,314)	$	1,294,664
Net Income	$	169,505	(45,570)	$	123,935
Balance at September 30, 2019	$	1,551,717	(169,884)	$	1,381,833
Net Income	$	193,919	(30,912)	$	163,007
Balance at September 30, 2020	$	1,844,692	(200,796)	$	1,643,896

Recent Updates to the Accounting Standards Codification

Recently Adopted Updates to the Accounting Standards Codification

Leases

In February 2016, the FASB issued ASU No. 2016-02, an amendment to ASC 842, Leases, which, along with other ASU's containing minor amendments and technical corrections, provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with an original term greater than one year are recorded on the balance sheet with a lessee recognizing a lease liability reflecting its obligation under the lease agreement and a right-of-use asset representing its right to use the leased asset over the lease term. The subsequent measurement of the lease depends on whether the lease is classified as an operating lease (resulting in the recognition of a straight-line lease cost) or a finance lease (resulting in the recognition of interest and asset amortization expense). Additional disclosures are required to provide transparency as to the amount, timing and uncertainty of cash flows arising from leasing activities.

In January 2018, the FASB issued ASU No. 2018-01, a further amendment to ASC 842, Leases, which was introduced by ASU No. 2016-02, as discussed above. This update provides an optional practical expedient that allows companies to not evaluate existing or expired land easements that were not previously accounted for under Topic 840 as leases as of October 1, 2019. The Company adopted this practical expedient. In July 2018, the FASB issued ASU No. 2018-11, which provides an optional transition method to ASC 842 that allows the Company to apply the new lease accounting requirements as of the effective date of the new standard, with the comparative periods remaining under the legacy ASC 840 requirements with a cumulative effect adjustment, if any, being made to the opening balance of retained earnings in the period of adoption. The Company elected this transition method and did not have any cumulative impact to the opening balance of retained earnings.

The Company elected various practical expedients permitted by ASC 842. This includes the package of practical expedients whereby the Company was not required to reassess all of its leases identified, lease classifications and initial direct costs associated with leases. The Company also elected to not separate nonlease components from lease components for certain classes of leases, such as office buildings, solar land leases and office equipment, and elected to exclude short-term leases from the recognition requirements of ASC 842 for all classes of assets. The Company adopted ASC 842 and all related amendments on October 1, 2019, using the modified retrospective transition method.

The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property leases, including land and office facility leases and office equipment and the sale leaseback of its natural gas meters. The total right-of-use assets and operating lease liabilities recorded upon adoption were $67.1 million. Upon the acquisition of Leaf River, on October 11, 2019, the Company adopted ASC 842 for Leaf River which resulted in the recognition of an additional right-of-use asset and lease liability of $21.6 million.

Derivatives and Hedging

In August 2017, the FASB issued ASU No. 2017-12, an amendment to ASC 815, Derivatives and Hedging, which, along with other ASU's containing minor amendments and technical corrections, is intended to make targeted improvements to the accounting for hedging activities by better aligning an entity’s risk management activities and financial reporting for hedging relationships. These amendments modify the accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Additionally, the amendments are intended to simplify the application of the hedge accounting guidance and provide relief to companies by easing certain hedge documentation requirements. The Company adopted this guidance on October 1, 2019. As October 1, 2019, the Company did not apply hedge accounting to its risk management activities, therefore the amendments did not have an impact on its financial position, results of operations or cash flows.

In October 2018, the FASB issued ASU No. 2018-16, an amendment to ASC 815, Derivatives and Hedging, which permits the use of the Overnight Index Swap rate based on the Secured Overnight Financing Rate as an additional acceptable U.S. benchmark interest rate for hedge accounting purposes. The Company adopted this guidance on October 1, 2019. As the Company did not apply hedge accounting to any of its risk management activities as of October 1, 2019, the amendments did not have an impact on its financial position, results of operations or cash flows.

Stock Compensation

In June 2018, the FASB issued ASU No. 2018-07, an amendment to ASC 718, Compensation - Stock Compensation, which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from non-employees. The Company adopted this guidance on October 1, 2019. There was no impact to the Company's financial position, results of operations or cash flows.

Financial Instruments

In March 2020, the FASB issued ASU No. 2020-03, Codification Improvements to Financial Instruments. This accounting standard provides clarification of guidance for financial instruments and makes narrow scope amendments related to various issues. The Company adopted this standard effective upon issuance. There was no impact to the Company's financial position, results of operations or cash flows as a result of its adoption.

Reference Rate Reform

In March 2020, the FASB issued ASU No. 2020-04, an amendment to ASC 848, Reference Rate Reform, which provides relief for companies preparing for discontinuation of interest rates such as LIBOR. The amendments in this update provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met. The amendments in this update apply only to contracts and hedging relationships that reference LIBOR or another reference rate expected to be discontinued due to reference rate reform. The amendments in this update are elective and are effective upon the ASU issuance through December 31, 2022. There was no impact to the Company's financial position, results of operations or cash flows as a result of its adoption.

Other Recent Updates to the Accounting Standards Codification

Financial Instruments

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

The Company completed its evaluation of ASU No. 2016-13 and subsequent amendments related to this topic and adopted this new guidance beginning October 1, 2020, using the modified retrospective method. The adoption did not result in a cumulative effect adjustment to retained earnings and did not have a material impact to our consolidated financial statements.

If implementation resulted in a material impact to amounts associated with NJNG accounts receivable and unbilled revenue within the scope of the new standard and that were considered incremental costs caused by COVID-19, the Company

could elect to defer those costs as a regulatory asset in accordance with the July 2, 2020 BPU order which authorized New Jersey utilities to create a regulatory asset for incremental COVID-19 related costs. See Note 4. Regulation for further detail.

Fair Value

In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective or retrospective basis depending on the specific amendments’ transition requirements. The Company is currently evaluating the impact of the adoption of this ASU but does not expect that its pending adoption will have a material effect on its consolidated financial statements. The Company does not have either Level 3 fair value measurements or transfers between Level 1 or Level 2 in its current portfolios, and therefore, does not expect this ASU to have an impact on the Company's financial statements and disclosures.

Compensation - Retirement Benefits

In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures and adds new disclosure requirements identified as relevant. The guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. Upon adoption, the amended presentation and disclosure guidance will be applied on a retrospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on the Company's disclosures upon adoption but it is not expecting this ASU to materially affect the financial statements and disclosures.

Income Taxes

In December 2019, the FASB issued ASU No. 2019-12, an amendment to ASC 740, Income Taxes, which is intended to simplify the accounting for income taxes and changes the accounting for certain income tax transactions, among other minor improvements. The guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective basis. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption.

Investments - Equity Method and Derivatives and Hedging

In January 2020, the FASB issued ASU No. 2020-01, Investments - Equity Securities (Topic 321), Investments - Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815): Clarifying the Interactions between Topic 321, Topic 323, and Topic 815. The update states that an entity is required to evaluate observable transactions that necessitate applying or discontinuing the equity method of accounting, when applying the measurement alternative in Topic 321. This evaluation occurs prior to applying or upon ceasing the equity method. The update also states that when applying paragraph 815-10-15-141(a) for forward contracts and purchased options, an entity is not required to assess whether the underlying securities will be accounted for under the equity method in accordance with Topic 323 or fair value method under Topic 825 upon settlement or exercise. The guidance is effective for the Company beginning October 1, 2021, with early adoption permitted. The Company is currently evaluating the impact of the adoption of this ASU but does not expect that its pending adoption will have a material effect on its consolidated financial statements.

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, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs.

The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and includes the following:

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

Level 2Other significant observable inputs, such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:

•widely accepted and public;

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

•observable and published.

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

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

Financial derivative portfolios of NJNG and Energy Services consist mainly of futures, options and swaps. The Company primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market; therefore, the primary sources for its price inputs are CME, NYMEX and ICE. Energy Services uses Platts and Natural Gas Exchange for Canadian delivery points. However, Energy Services also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the transportation cost to the final delivery location is not significant to the overall valuation. If required, Energy Services’ policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or other pricing services.

The Company also has other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When the Company determines fair values, measurements are adjusted, as needed, for credit risk associated with its counterparties, as well as its own credit risk. The Company determines these adjustments by using historical default probabilities that correspond to the applicable S&P issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.

Lessee Accounting

Lessee Accounting

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset and accounts for leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and leased 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. The Company’s land leases and office equipment 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. For more information on the adoption of ASC 842, Leases, see Note 2. Summary of Significant Accounting Policies.

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. These variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use asset and lease 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.

The Company’s solar land lease terms are primarily between 15 and 35 years, which includes options to extend the terms for multiple additional 5 to 10 years each. The Company’s office leases vary in duration, ranging from 1 to 25 years and may or may not include extension or early purchase options. The majority of the Company’s meter leases are for terms of 7 years with purchase options available prior to the end of the 7 year term. Equipment leases include general office equipment that also vary in duration, most are for a term of 5 years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The expense related to the leases subject to the short-term lease recognition exemption are recognized on a straight-line basis, with such amounts disclosed in the financial statement notes below.

The Company has lease agreements with lease and nonlease components and has elected the practical expedient to combine lease and nonlease components for certain classes of leases, such as office buildings, solar land leases and office equipment. Variable payments are not significant to the Company. The Company’s lease agreements do not contain any

material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

12 Months Ended

Sep. 30, 2020

Accounting Policies [Abstract]

Schedule of Demand Charges

The following table summarizes the demand charges, which are net of capacity releases, and are included as a component of natural gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30:

(Millions)	2020		2019		2018
Energy Services	$	121.8	$	120.4	$	153.0
Natural Gas Distribution	131.9		119.1		92.5
Total	$	253.7	$	239.5	$	245.5

Schedule of Property, Plant and Equipment

Property, plant and equipment was comprised of the following as of September 30:

(Thousands)	Estimated
Property Classifications	Estimated Useful Lives	2020		2019
Distribution facilities	38 to 74 years	$	2,688,885	$	2,419,381
Transmission facilities	35 to 56 years	332,947		330,912
Storage facilities	34 to 47 years	79,922		79,916
Solar property	15 to 35 years	674,930		593,867
Storage and transportation property	5 to 50 years	428,491		28,445
All other property	5 to 35 years	259,791		48,886
Total property, plant and equipment		4,464,966		3,501,407
Accumulated depreciation and amortization		(742,197)		(691,774)
Property, plant and equipment, net		$	3,722,769	$	2,809,633

Schedule of Capitalized Amounts Associated with Debt and Equity Component of AFUDC

Capitalized and deferred interest include the following for the fiscal years ended September 30:

($ in thousands)	2020						2019			2018
	NJNG			Adelphia Gateway			NJNG			NJNG
AFUDC:
Debt	$	5,134		$	1,394		$	3,710		$	1,979
Equity	14,599			2,454			6,492			5,531
Total	$	19,733		$	3,848		$	10,202		$	7,510
Weighted average interest rate	6.79		%	8.28		%	6.35		%	5.94		%

Schedule of Restricted Cash

The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Consolidated Balance Sheets to the total amounts in the Statements of Cash Flows, as of September 30:

(Thousands)	2020		2019		2018
Balance Sheet
Cash and cash equivalents	$	117,012	$	2,676	$	1,458
Restricted cash in other noncurrent assets	$	2,411	$	1,387	$	252
Statements of Cash Flow
Cash, cash equivalents and restricted cash	$	119,423	$	4,063	$	1,710

Summary of Gas in Storage

The following table summarizes natural gas in storage, at average cost by company, as of September 30:

	2020				2019
($ in thousands)	Natural Gas in Storage			Bcf	Natural Gas in Storage			Bcf
Natural Gas Distribution		$	110,037	27.2		$	117,413	27.0
Energy Services		57,352		34.3		52,390		25.6
Storage and Transportation		115		0.02		—		—
Total		$	167,504	61.52		$	169,803	52.6

Schedule of Software Costs Included in the Consolidated Financial Statements

The following table presents the software costs included in the Consolidated Financial Statements, as of September 30:

(Thousands)	2020		2019
Balance Sheets
Utility plant, at cost	$	13,452	$	—
Construction work in progress	$	—	$	4,778
Nonutility plant and equipment, at cost	$	316	$	—
Accumulated depreciation and amortization, utility plant	$	(279)	$	—
Accumulated depreciation and amortization, nonutility plant and equipment	$	(5)	$	—
Software costs	$	4,707	$	1,702
Statements of Operations
Operation and maintenance (1)	$	6,720	$	9,062
Depreciation and amortization	$	284	$	—

(1)During fiscal 2020, $63,000 was amortized into O&M.

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense

The estimated future amortization expense as of September 30, is as follows:

(Thousands)
2021	$	5,101
2022	$	2,611
2023	$	2,271
2024	$	77

Changes in Components of Accumulated Other Comprehensive Income, Net

The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects, as of September 30:

(Thousands)	Investments in Equity Securities		Cash Flow Hedges		Postemployment Benefit Obligation			Total
Balance at September 30, 2018	$	3,446	$	—	$	(16,056)		$	(12,610)
Other comprehensive income, net of tax
Other comprehensive (loss), before reclassifications, net of tax of $0, $0, $6,557 and $6,557, respectively	—		—		(16,978)			(16,978)
Amounts reclassified from accumulated other comprehensive (loss), net of tax of $0, $0, $(451) and $(451), respectively	—		—		1,247		(1)	1,247
Net current-period other comprehensive income, net of tax of $0, $0, $6,106 and $6,106, respectively	—		—		(15,731)			(15,731)
Reclassifications of certain income tax effects to retained earnings (2)	(3,446)		—		—			(3,446)
Balance at September 30, 2019	$	—	$	—	$	(31,787)		$	(31,787)
Other comprehensive income, net of tax
Other comprehensive (loss) income, before reclassifications, net of tax of $0, $3,203, $1,235, $4,438, respectively	—		(10,505)		(4,882)			(15,387)
Amounts reclassified from accumulated other comprehensive loss, net of tax of $0, $(32), $(668), $(700), respectively	—		108		2,751		(1)	2,859
Net current-period other comprehensive income, net of tax of $0, $3,171, $567, $3,738, respectively	—		(10,397)		(2,131)			(12,528)
Balance at September 30, 2020	$	—	$	(10,397)	$	(33,918)		$	(44,315)

(1)Included in the computation of net periodic pension cost, a component of O&M expense on the Consolidated Statements of Operations. For more details, see Note 11. Employee Benefit Plans.

(2)Due to the adoption of ASU No. 2016-01, an amendment to ASC 825, Financial Instruments. See Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the Accounting Standards Codification section for more details.

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REVENUE (Tables)

12 Months Ended

Sep. 30, 2020

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 and wind 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. All wind assets were sold as of February 7, 2019. 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 RECs, 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	Wholesale natural gas services	The performance obligation of Energy Services is to provide the customer transportation, storage and asset management services on an as-needed basis. Energy Services generates revenue through management fees, demand charges, reservation fees and transportation charges centered around the buying and selling of the natural gas commodity, representing one series of distinct performance obligations. Revenue is recognized based upon the underlying natural gas quantities physically delivered and the customer obtaining control. Energy Services invoices customers on a monthly basis in line with the terms of the contract and based on the services provided. Payment is due each month for the previous month's invoiced services.
Storage and Transportation	Natural gas services	The performance obligation of our Storage and Transportation segment is to provide the customer with storage and transportation services. Storage and Transportation generates revenues from firm storage contracts and transportation contracts, related usage fees for the use of storage space, injection and withdrawal at the storage facility and the delivery of natural gas to customers. Revenue is recognized over time as our customers receive the benefits of our service as it is performed on their behalf using an output method based on actual deliveries. Demand fees are recognized as revenue over the term of the related agreement.
Home Services and Other	Service contracts	Home Services enters into service contracts with homeowners to provide maintenance and replacement services of applicable heating, cooling or ventilation equipment. All services provided relate to a distinct performance obligation which is to provide services for the specific equipment over the term of the contract. Revenue is recognized on a straight-line basis over the term of the contract and payment is due upon receipt of the invoice.

Revenue Recognized at a Point in Time:
Storage and Transportation	Natural gas services	The performance obligation of our Storage and Transportation segment is to provide the customer with storage and transportation services. Storage and Transportation generates revenues from hub services for the use of storage space, injection and withdrawal from the storage facility. Hub services include park and loan transactions and wheeling. Hub services revenues are recognized as services are performed.
Home Services and Other	Installations	Home Services installs appliances, including but not limited to, furnaces, air conditioning units, boilers and generators, for 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 fiscal 2020 are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures		Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Natural gas utility sales	$	695,858	—		—	—	—	$	695,858
Wholesale natural gas services	—		—		24,511	44,728	—	69,239
Service contracts	—		—		—	—	32,455	32,455
Installations and maintenance	—		—		—	—	18,562	18,562
Renewable Energy Certificates	—		1,384		—	—	—	1,384
Electricity sales	—		20,099		—	—	—	20,099
Eliminations (1)	—		—		—	(2,713)	(1,207)	(3,920)
Revenues from contracts with customers	695,858		21,483		24,511	42,015	49,810	833,677
Alternative revenue programs (2)	15,750		—		—	—	—	15,750
Derivative Instruments	18,315		81,134	(3)	1,005,908	—	—	1,105,357
Eliminations (1)	—		—		(1,116)	—	—	(1,116)
Revenues out of scope	34,065		81,134		1,004,792	—	—	1,119,991
Total operating revenues	$	729,923	102,617		1,029,303	42,015	49,810	$	1,953,668
2019
Natural gas utility sales	$	680,151	—		—	—	—	$	680,151
Wholesale natural gas services	—		—		31,459	—	—	31,459
Service contracts	—		—		—	—	31,499	31,499
Installations and maintenance	—		—		—	—	19,403	19,403
Electricity sales	—		22,121		—	—	—	22,121
Eliminations (1)	—		—		—	—	(2,302)	(2,302)
Revenues from contracts with customers	680,151		22,121		31,459	—	48,600	782,331
Alternative revenue programs (2)	10,364		—		—	—	—	10,364
Derivative Instruments	20,278		75,978	(3)	1,711,332	—	—	1,807,588
Eliminations (1)	—		—		(8,238)	—	—	(8,238)
Revenues out of scope	30,642		75,978		1,703,094	—	—	1,809,714
Total operating revenues	$	710,793	98,099		1,734,553	—	48,600	$	2,592,045

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

(2)Includes CIP revenue.

(3)Includes SREC revenue.

Disaggregated revenues from contracts with customers by customer type and by reporting segment and other business operations during the fiscal years ended September 30, are as follows:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Residential	$	490,233	10,233	—	—	48,867	$	549,333
Commercial and industrial	129,946		11,250	24,511	42,015	943	208,665
Firm transportation	69,357		—	—	—	—	69,357
Interruptible and off-tariff	6,322		—	—	—	—	6,322
Revenues out of scope	34,065		81,134	1,004,792	—	—	1,119,991
Total operating revenues	$	729,923	102,617	1,029,303	42,015	49,810	$	1,953,668
2019
Residential	$	440,787	9,003	—	—	47,655	$	497,445
Commercial and industrial	171,357		13,118	31,459	—	945	216,879
Firm transportation	61,370		—	—	—	—	61,370
Interruptible and off-tariff	6,637		—	—	—	—	6,637
Revenues out of scope	30,642		75,978	1,703,094	—	—	1,809,714
Total operating revenues	$	710,793	98,099	1,734,553	—	48,600	$	2,592,045

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 Consolidated Balance Sheets during fiscal 2020 are as follows:

	Customer Accounts Receivable				Customers' Credit
(Thousands)	Billed		Unbilled		Balances and Deposits
Balance as of October 1, 2019	$	139,263	$	6,510	$	27,116
(Decrease) Increase	(5,090)		2,716		(1,182)
Balance as of September 30, 2020	$	134,173	$	9,226	$	25,934

Performance Obligation, in Excess of Billings

The following table provides information about receivables and revenue earned on contracts in progress in excess of billings, which are included within accounts receivable, billed and unbilled, and customers’ credit balances and deposits, respectively, on the Consolidated Balance Sheets as of September 30:

(Thousands)	Natural Gas Distribution		Clean Energy Ventures	Energy Services	Storage and Transportation	Home Services and Other	Total
2020
Customer accounts receivable
Billed	$	52,134	5,282	70,457	3,905	2,395	$	134,173
Unbilled	7,842		1,384	—	—	—	9,226
Customers' credit balances and deposits	(25,934)		—	—	—	—	(25,934)
Total	$	34,042	6,666	70,457	3,905	2,395	$	117,465
2019
Customer accounts receivable
Billed	$	36,302	3,233	97,301	—	2,427	$	139,263
Unbilled	6,510		—	—	—	—	6,510
Customers' credit balances and deposits	(27,114)		—	—	—	(2)	(27,116)
Total	$	15,698	3,233	97,301	—	2,425	$	118,657

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REGULATION (Tables)

12 Months Ended

Sep. 30, 2020

Regulated Operations [Abstract]

Schedule of Regulatory Assets

Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are composed of the following:

(Thousands)	2020		2019
Regulatory assets-current
New Jersey Clean Energy Program	$	15,570	$	15,468
Conservation Incentive Program	19,120		3,371
Underrecovered natural gas costs	—		9,506
Derivatives at fair value, net	—		4,526
Other current regulatory assets	1,682		—
Total current regulatory assets	$	36,372	$	32,871
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	36,516	$	38,351
Liability for future expenditures	150,590		131,080
Deferred income taxes	28,241		19,631
Derivatives at fair value, net	1		486
SAVEGREEN	21,281		10,201
Postemployment and other benefit costs	188,170		212,461
Deferred storm damage costs	6,515		8,687
Cost of removal	75,080		65,660
Other noncurrent regulatory assets	20,068		10,080
Total noncurrent regulatory assets	$	526,462	$	496,637
Regulatory liability-current
Overrecovered natural gas costs	$	25,914	$	—
Derivatives at fair value, net	274		—
Total current regulatory liabilities	$	26,188	$	—
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	195,425	$	200,417
Derivatives at fair value, net	352		—
New Jersey Clean Energy Program	—		197
Other noncurrent regulatory liabilities	509		1,821
Total noncurrent regulatory liabilities	$	196,286	$	202,435

(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.

Schedule of Regulatory Liabilities

Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are composed of the following:

(Thousands)	2020		2019
Regulatory assets-current
New Jersey Clean Energy Program	$	15,570	$	15,468
Conservation Incentive Program	19,120		3,371
Underrecovered natural gas costs	—		9,506
Derivatives at fair value, net	—		4,526
Other current regulatory assets	1,682		—
Total current regulatory assets	$	36,372	$	32,871
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries	$	36,516	$	38,351
Liability for future expenditures	150,590		131,080
Deferred income taxes	28,241		19,631
Derivatives at fair value, net	1		486
SAVEGREEN	21,281		10,201
Postemployment and other benefit costs	188,170		212,461
Deferred storm damage costs	6,515		8,687
Cost of removal	75,080		65,660
Other noncurrent regulatory assets	20,068		10,080
Total noncurrent regulatory assets	$	526,462	$	496,637
Regulatory liability-current
Overrecovered natural gas costs	$	25,914	$	—
Derivatives at fair value, net	274		—
Total current regulatory liabilities	$	26,188	$	—
Regulatory liabilities-noncurrent
Tax Act impact (1)	$	195,425	$	200,417
Derivatives at fair value, net	352		—
New Jersey Clean Energy Program	—		197
Other noncurrent regulatory liabilities	509		1,821
Total noncurrent regulatory liabilities	$	196,286	$	202,435

(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.

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DERIVATIVE INSTRUMENTS (Tables)

12 Months Ended

Sep. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Assets and Liabilities

The following table reflects the fair value of the Company’s derivative assets and liabilities recognized on the Consolidated Balance Sheets as of September 30:

			Fair Value
			2020						2019
(Thousands)	Balance Sheet Location	Asset Derivatives			Liability Derivatives			Asset Derivatives			Liability Derivatives
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	78		$	76		$	67		$	245
Financial commodity contracts	Derivatives - current		71			282			382			570
Energy Services:
Physical commodity contracts	Derivatives - current		6,454			20,438			6,847			27,540
	Derivatives - noncurrent		1,264			12,003			1,710			12,641
Financial commodity contracts	Derivatives - current		16,671			12,965			17,806			29,057
	Derivatives - noncurrent		2,037			1,346			5,716			6,105
Foreign currency contracts	Derivatives - current		36			104			1			211
	Derivatives - noncurrent		48			3			—			75
Total fair value of derivatives			$	26,659		$	47,217		$	32,529		$	76,444

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 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 September 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222
As of September 30, 2019:
Derivative assets:
Energy Services
Physical commodity contracts		$	8,557		$	(2,906)		$	(200)		$	5,451
Financial commodity contracts		23,522			(19,646)			—			3,876
Foreign currency contracts		1			(1)			—			—
Total Energy Services		$	32,080		$	(22,553)		$	(200)		$	9,327
Natural Gas Distribution
Physical commodity contracts		$	67		$	(9)		$	—		$	58
Financial commodity contracts		382			(382)						—
Total Natural Gas Distribution		$	449		$	(391)		$	—		$	58
Derivative liabilities:
Energy Services
Physical commodity contracts		$	40,181		$	(2,906)		$	—		$	37,275
Financial commodity contracts		35,162			(19,646)			(15,516)			—
Foreign currency contracts		286			(1)			—			285
Total Energy Services		$	75,629		$	(22,553)		$	(15,516)		$	37,560
Natural Gas Distribution
Physical commodity contracts		$	245		$	(9)		$	—		$	236
Financial commodity contracts		570			(382)			(188)			—
Total Natural Gas Distribution		$	815		$	(391)		$	(188)		$	236

(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 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 September 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13
Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211
Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222
As of September 30, 2019:
Derivative assets:
Energy Services
Physical commodity contracts		$	8,557		$	(2,906)		$	(200)		$	5,451
Financial commodity contracts		23,522			(19,646)			—			3,876
Foreign currency contracts		1			(1)			—			—
Total Energy Services		$	32,080		$	(22,553)		$	(200)		$	9,327
Natural Gas Distribution
Physical commodity contracts		$	67		$	(9)		$	—		$	58
Financial commodity contracts		382			(382)						—
Total Natural Gas Distribution		$	449		$	(391)		$	—		$	58
Derivative liabilities:
Energy Services
Physical commodity contracts		$	40,181		$	(2,906)		$	—		$	37,275
Financial commodity contracts		35,162			(19,646)			(15,516)			—
Foreign currency contracts		286			(1)			—			285
Total Energy Services		$	75,629		$	(22,553)		$	(15,516)		$	37,560
Natural Gas Distribution
Physical commodity contracts		$	245		$	(9)		$	—		$	236
Financial commodity contracts		570			(382)			(188)			—
Total Natural Gas Distribution		$	815		$	(391)		$	(188)		$	236

(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 the Consolidated Statements of Operations

The following table reflects the effect of derivative instruments on the Consolidated Statements of Operations as of September 30:

(Thousands)	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income on Derivatives
Derivatives not designated as hedging instruments:		2020		2019		2018
Energy Services:
Physical commodity contracts	Operating revenues	$	1,163	$	(5,732)	$	(9,311)
Physical commodity contracts	Natural gas purchases	(3,366)		(521)		(197)
Financial commodity contracts	Natural gas purchases	58,949		(643)		(24,622)
Foreign currency contracts	Natural gas purchases	(41)		(283)		(379)
Home Services and Other:
Interest rate contracts	Interest expense	—		(233)		334
Total unrealized and realized (losses) gains		$	56,705	$	(7,412)	$	(34,175)

Effect of Derivative Instruments Designated as Cash Flow Hedges on OCI

The following table reflects the gains (losses) associated with NJNG’s derivative instruments as of September 30:

(Thousands)	2020		2019		2018
Natural Gas Distribution:
Physical commodity contracts	$	2,077	$	5,926	$	1,232
Financial commodity contracts	(3,903)		(7,700)		1,844
Interest rate contracts	—		—		8,467
Total unrealized and realized (losses) gains	$	(1,826)	$	(1,774)	$	11,543

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

The following table reflects the effect of derivative instruments designated as cash flow hedges in OCI as of September 30:

(Thousands)	Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives				Location of Gain (Loss) Reclassified from OCI into Income	Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income
Derivatives in cash flow hedging relationships:	2020		2019			2020		2019
Interest rate contracts	$	(13,568)	$	—	Interest expense	$	140	$	—

Schedule of Outstanding Long (Short) Derivatives

NJNG and Energy Services had the following outstanding long (short) derivatives as of September 30:

		Volume (Bcf)
	Transaction Type	2020	2019
Natural Gas Distribution	Futures	23.7	27.6
	Physical Commodity	6.0	11.6
Energy Services	Futures	(27.5)	(29.6)
	Swaps	(1.8)	(5.0)
	Options	—	1.0
	Physical Commodity	5.0	44.5

Not included in the above table are Energy Services' net notional amount of foreign currency transactions of approximately $5.1 million and $6.2 million and 960,000 and 796,000 SRECs that were open, as of September 30, 2020 and 2019, respectively.

Schedule of Broker Margin Accounts by Company

The balances as of September 30, by segment, are as follows:

(Thousands)	Balance Sheet Location	2020		2019
Natural Gas Distribution	Restricted broker margin accounts	$	13,525	$	1,982
Energy Services	Restricted broker margin accounts	$	55,919	$	71,741

Summary of Gross Credit Exposures

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of September 30, 2020. 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		$	132,105
Noninvestment grade		8,527
Internally-rated investment grade		24,647
Internally-rated noninvestment grade		12,471
Total		$	177,750

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FAIR VALUE (Tables)

12 Months Ended

Sep. 30, 2020

Fair Value Disclosures [Abstract]

Estimated Fair Value of Long-term Debt

As of September 30, the estimated fair value of long-term debt at NJNG and NJR, including current maturities, excluding finance leases and debt issuance costs, is as follows (1):

(Thousands)	2020		2019
NJNG (2) (3)
Carrying value	$	1,092,845	$	892,845
Fair market value	$	1,271,715	$	984,129
NJR (4)
Carrying value	$	1,010,000	$	550,000
Fair market value	$	1,146,033	$	584,735

(1)See Note 9. Debt for a reconciliation to long-term and short-term debt.

(2)Excludes finance leases of $74.2 million and $35.4 million as of September 30, 2020 and September 30, 2019, respectively.

(3)Excludes NJNG's debt issuance costs of $9.2 million and $9 million as of September 30, 2020 and September 30, 2019, respectively.

(4)Excludes NJR's debt issuance costs of $3.4 million and $2 million as of September 30, 2020 and September 30, 2019, respectively.

Assets and Liabilities Measured at Fair Value 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 September 2020:
Assets
Physical commodity contracts		$	—		$	7,796		$	—	$	7,796
Financial commodity contracts		18,279			500			—		18,779
Financial commodity contracts - foreign exchange		—			84			—		84
Money market funds		112,291			—			—		112,291
Other		1,840			—			—		1,840
Total assets at fair value		$	132,410		$	8,380		$	—	$	140,790
Liabilities
Physical commodity contracts		$	—		$	32,517		$	—	$	32,517
Financial commodity contracts		14,593			—			—		14,593
Financial commodity contracts - foreign exchange		—			107			—		107
Total liabilities at fair value		$	14,593		$	32,624		$	—	$	47,217
As of September 30, 2019:
Assets
Physical commodity contracts		$	—		$	8,624		$	—	$	8,624
Financial commodity contracts		20,028			3,876			—		23,904
Financial commodity contracts - foreign exchange		—			1			—		1
Other (1)		1,706			—			—		1,706
Total assets at fair value		$	21,734		$	12,501		$	—	$	34,235
Liabilities
Physical commodity contracts		$	—		$	40,426		$	—	$	40,426
Financial commodity contracts		35,732			—			—		35,732
Financial commodity contracts - foreign exchange		—			286			—		286
Total liabilities at fair value		$	35,732		$	40,712		$	—	$	76,444

(1)Includes money market funds.

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INVESTMENTS IN EQUITY INVESTEES (Tables)

12 Months Ended

Sep. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

As of September 30, the Company’s investments in equity method investees includes the following:

(Thousands)	2020		2019
Steckman Ridge (1)	$	112,378	$	114,428
PennEast (2)	95,997		85,840
Total	$	208,375	$	200,268

(1)Includes loans with a total outstanding principal balance of $70.4 million for both fiscal 2020 and 2019, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.

(2)Includes a deferred tax component related to AFUDC equity of $4.6 million and $4.1 million for September 30, 2020 and September 30, 2019, respectively.

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EARNINGS PER SHARE (Tables)

12 Months Ended

Sep. 30, 2020

Earnings Per Share [Abstract]

Schedule of Basic and Diluted Earnings Per Share

The following table presents the calculation of the Company’s basic and diluted earnings per share for the fiscal years ended September 30:

(Thousands, except per share amounts)	2020		2019		2018
Net income, as reported	$	163,007	$	123,935	$	231,013
Basic earnings per share
Weighted average shares of common stock outstanding-basic	94,798		89,242		87,689
Basic earnings per common share	$1.72		$1.39		$2.63
Diluted earnings per share
Weighted average shares of common stock outstanding-basic	94,798		89,242		87,689
Incremental shares (1)	305		354		626
Weighted average shares of common stock outstanding-diluted	95,103		89,596		88,315
Diluted earnings per common share (2)	$1.71		$1.38		$2.62

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

(2)There were anti-dilutive shares of 74,000 excluded from the calculation of diluted earnings per share related to the equity forward sale agreement for fiscal 2020. There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for fiscal 2019 and 2018

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DEBT (Tables)

12 Months Ended

Sep. 30, 2020

Debt Disclosure [Abstract]

Schedule of Long-term Debt

The following table presents the long-term debt of the Company as of September 30:

(Thousands)			2020		2019
NJNG
First mortgage bonds:		Maturity date:
3.00%	Series OO	August 1, 2041	46,500		46,500
3.15%	Series PP	April 15, 2028	50,000		50,000
3.58%	Series QQ	March 13, 2024	70,000		70,000
4.61%	Series RR	March 13, 2044	55,000		55,000
2.82%	Series SS	April 15, 2025	50,000		50,000
3.66%	Series TT	April 15, 2045	100,000		100,000
3.63%	Series UU	June 21, 2046	125,000		125,000
4.01%	Series VV	May 11, 2048	125,000		125,000
3.50%	Series WW	April 1, 2042	10,300		10,300
3.38%	Series XX	April 1, 2038	10,500		10,500
2.45%	Series YY	April 1, 2059	15,000		15,000
3.76%	Series ZZ	July 17, 2049	100,000		100,000
3.86%	Series AAA	July 17, 2059	85,000		85,000
2.75%	Series BBB	August 1, 2039	9,545		9,545
3.00%	Series CCC	August 1, 2043	41,000		41,000
3.13%	Series DDD	June 30, 2050	50,000		—
3.13%	Series EEE	July 23, 2050	50,000		—
3.33%	Series FFF	July 23, 2060	25,000		—
2.87%	Series GGG	September 1, 2050	25,000		—
2.97%	Series HHH	September 1, 2060	50,000		—
Finance lease obligation-buildings		June 30, 2037	47,597		5,637
Finance lease obligation-meters		Various dates	26,562		29,744
Less: Debt issuance costs			(9,195)		(9,027)
Less: Current maturities of long-term debt			(10,416)		(10,420)
Total NJNG long-term debt			1,147,393		908,779
NJR
3.25%	Unsecured senior notes	September 17, 2022	50,000		50,000
3.20%	Unsecured senior notes	August 18, 2023	50,000		50,000
3.48%	Unsecured senior notes	November 7, 2024	100,000		100,000
3.54%	Unsecured senior notes	August 18, 2026	100,000		100,000
3.96%	Unsecured senior notes	June 8, 2028	100,000		100,000
3.29%	Unsecured senior notes	July 17, 2029	150,000		150,000
3.60%	Unsecured senior notes	July 23, 2032	130,000		—
3.50%	Unsecured senior notes	July 23, 2030	130,000		—
3.25%	Unsecured senior notes	September 1, 2033	80,000		—
3.13%	Unsecured senior notes	September 1, 2031	120,000		—
Less: Debt issuance costs			(3,424)		(2,004)
Less: Current maturities of long-term debt			—		—
Total NJR long-term debt			1,006,576		547,996
Clean Energy Ventures
Solar asset financing obligation		Various dates	122,317		91,401
Less: Current maturities of long-term debt			(16,820)		(10,999)
Total Clean Energy Ventures long-term debt			105,497		80,402
Total long-term debt			$	2,259,466	$	1,537,177

Schedule of Long-term Debt Redemption Requirements

Annual long-term debt redemption requirements, excluding finance leases, debt issuance costs and solar asset financing obligations, as of September 30, are as follows:

(Thousands)	NJR		NJNG
2021	$	—	$	—
2022	$	50,000	$	—
2023	$	50,000	$	—
2024	$	100,000	$	70,000
2025	$	—	$	50,000
Thereafter	$	810,000	$	972,845

Finance Lease, Liability, Maturity

Contractual commitments for finance lease payments, as of the fiscal years ended September 30, are as follows:

(Thousands)	senior note
2021		$	54,992
2022		6,004
2023		4,622
2024		5,279
2025		3,396
Thereafter		2,324
Subtotal		76,617
Less: Interest component		(2,458)
Total		$	74,159

The following table presents the Company's maturities of lease liabilities as of September 30, 2020:

(Thousands)	Operating Leases		Finance Leases
2021	$	6,706	$	54,992
2022	6,634		6,004
2023	6,590		4,622
2024	6,210		5,279
2025	5,646		3,396
Thereafter	122,085		2,324
Total future lease payments	153,871		76,617
Less: Liability accretion	(52,117)		(2,458)
Total lease liability	$	101,754	$	74,159

Schedule of Contractual Commitments for Finance Lease Payments

Contractual commitments for the solar financing obligation payments, as of the fiscal years ended September 30, are as follows:

(Thousands)	Lease Payments
2021		$	12,928
2022		12,926
2023		13,003
2024		12,904
2025		8,985
Thereafter		47,268
Subtotal		108,014
Less: Interest component		(23,052)
Total		$	84,962

Summary of Short-Term Bank Facilities

A summary of NJR’s and NJNG’s short-term bank facilities as of September 30, are as follows:

(Thousands)	2020			2019			Expiration Dates
NJR
Bank revolving credit facilities (1)	$	425,000		$	425,000		December 2023
Notes outstanding at end of period	$	125,350		$	25,450
Weighted average interest rate at end of period	1.49		%	3.04		%
Amount available at end of period (2)	$	289,356		$	394,800
Bank revolving credit facilities (1)	$	250,000		$	—		April 2021
Notes outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (2)	$	250,000		$	—
NJNG
Bank revolving credit facilities (3)	$	250,000		$	250,000		December 2023
Commercial paper outstanding at end of period	$	—		$	—
Weighted average interest rate at end of period	—		%	—		%
Amount available at end of period (4)	$	249,269		$	249,269

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

(2)Letters of credit outstanding total $10.3 million and $4.8 million as of September 30, 2020 and 2019, respectively, which reduces amount available by the same amount.

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

(4)Letters of credit outstanding total $731,000 as of September 30, 2020 and 2019, which reduces amount available by the same amount.

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STOCK-BASED COMPENSATION (Tables)

12 Months Ended

Sep. 30, 2020

Share-based Payment Arrangement [Abstract]

Summary of Stock-based Compensation Expense Recognized

The following table summarizes all stock-based compensation expense recognized during the following fiscal years:

(Thousands)	2020		2019		2018
Stock-based compensation expense:
Performance share awards	$	1,943	$	5,804	$	3,526
Restricted and non-restricted stock	2,868		2,492		2,191
Deferred retention stock	1,725		1,500		7,128
Compensation expense included in operation and maintenance expense	6,536		9,796		12,845
Income tax benefit (1)	(1,900)		(2,848)		(3,734)
Total, net of tax	$	4,636	$	6,948	$	9,111

(1)Excludes additional tax benefit related to delivered shares of $647,000, $1.3 million and $3 million as of September 30, 2020, 2019 and 2018, respectively.

Summary of Performance Share Activity

The following table summarizes the performance share activity under the stock award and incentive plans for the past three fiscal years:

	Shares (1)	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Non-vested and outstanding at September 30, 2017	156,587		$30.12		—
Granted	91,177		$44.67		—
Vested (2)	(100,146)		$29.49		$	4,714
Cancelled/forfeited	(2,442)		$31.45		—
Non-vested and outstanding at September 30, 2018	145,176		$39.67		—
Granted	100,262		$47.98		—
Vested (3)	(103,009)		$38.52		$	4,622
Cancelled/forfeited	(11,920)		$44.34		—
Non-vested and outstanding at September 30, 2019	130,509		$46.53		—
Granted	82,064		$40.61		—
Vested (4)	(55,025)		$44.27		$	2,083
Cancelled/forfeited	(1,817)		$44.38		—
Non-vested and outstanding at September 30, 2020	155,731		$44.22		—

(1)The number of common shares issued related to certain performance shares may range from zero to 150 percent of the number of shares shown in the table above based on the Company’s achievement of performance goals.

(2)As certified by the Company’s Leadership and Compensation Committee on November 13, 2018, the number of common shares related to performance shares earned was 99 percent, or 38,660 shares, the number of common shares earned related to NFE performance was 121 percent or 39,694 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 36,998 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

(3)As certified by the Company’s Leadership and Compensation Committee on November 12, 2019, the number of common shares earned related to TSR performance was 119 percent or 43,641 shares, the number of common shares earned related to NFE performance was 117 percent or 26,413 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 24,468 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

(4)As certified by the Company’s Leadership and Compensation Committee on November 9, 2020, there were no common shares earned related to TSR performance, the number of common shares earned related to NFE performance was 114 percent or 28,513 shares and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 11,139 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent.

Summary of Restricted Stock Activity

The following table summarizes the restricted stock activity under the stock award and incentive plans for the past three fiscal years:

	Shares	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Non-vested and outstanding at September 30, 2017	51,154		$32.40		—
Granted	27,949		$45.00		—
Vested	(33,815)		$31.23		$	1,438
Cancelled/forfeited	(1,120)		$33.54		—
Non-vested and outstanding at September 30, 2018	44,168		$41.24		—
Granted	35,284		$48.24		—
Vested	(20,748)		$39.26		$	935
Cancelled/forfeited	(548)		$42.96		—
Non-vested and outstanding at September 30, 2019	58,156		$46.18		—
Granted	42,478		$40.61		—
Vested	(25,973)		$44.71		$	1,073
Cancelled/forfeited	(1,175)		$43.62		—
Non-vested and outstanding at September 30, 2020	73,486		$43.52		—

Summary of Deferred Retention Stock Award

The following table summarizes the deferred retention stock award under the stock award and incentive plans for the past three fiscal years:

	Shares	Weighted Average Grant Date Fair Value		Total Fair Value of Vested Shares (in Thousands)
Outstanding at September 30, 2017	672,578		$29.54		—
Granted/Vested	24,167		$45.00		—
Delivered	(452,694)		$29.42		$	19,581
Forfeited	(1,969)		$35.56
Outstanding at September 30, 2018	242,082		$32.99		—
Granted/Vested	167,407		$47.95		—
Delivered	(158,733)		$30.32		$	7,145
Forfeited	(7,195)		$44.41		—
Outstanding at September 30, 2019	243,561		$44.67		—
Granted/Vested	42,358		$40.72		—
Delivered	(57,673)		$35.25		$	2,423
Outstanding at September 30, 2020	228,246		$46.32		—

Schedule of Nonemployee Director Stock Award Plan Activity

The following summarizes non-employee director share awards for the past three fiscal years:

	2020		2019	2018
Shares granted	27,696	(1)	26,165	26,524
Weighted average grant date fair value	$42.88		$44.80	$39.85

(1)$311,000 of expense remains as of September 30, 2020, to be recognized through December 31, 2020.

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EMPLOYEE BENEFIT PLANS (Tables)

12 Months Ended

Sep. 30, 2020

Retirement Benefits [Abstract]

Summary of Changes in Funded Status of Plans and Liabilities Recognized

The following summarizes the changes in the funded status of the plans and the related liabilities recognized on the Consolidated Balance Sheets as of September 30:

	Pension (1)				OPEB
(Thousands)	2020		2019		2020		2019
Change in Benefit Obligation
Benefit obligation at beginning of year	$	360,477	$	298,575	$	260,003	$	196,785
Service cost	8,223		7,381		4,854		4,404
Interest cost	10,587		12,173		7,026		8,324
Plan participants’ contributions (2)	25		43		194		210
Actuarial loss (gain)	29,738		52,549		(23,226)		54,700
Benefits paid, net of retiree subsidies received	(11,886)		(10,244)		(2,989)		(4,420)
Benefit obligation at end of year	$	397,164	$	360,477	$	245,862	$	260,003
Change in plan assets
Fair value of plan assets at beginning of year	$	288,634	$	279,410	$	83,925	$	77,980
Actual return on plan assets	30,632		19,194		6,872		2,499
Employer contributions	596		231		8,436		7,926
Benefits paid, net of plan participants’ contributions (2)	(11,894)		(10,201)		(2,827)		(4,479)
Fair value of plan assets at end of year	$	307,968	$	288,634	$	96,406	$	83,926
Funded status	$	(89,196)	$	(71,843)	$	(149,456)	$	(176,077)
Amounts recognized on Consolidated Balance Sheets
Postemployment employee (liability)
Current	$	(531)	$	(603)	$	(900)	$	(800)
Noncurrent	(88,665)		(71,240)		(148,556)		(175,277)
Total	$	(89,196)	$	(71,843)	$	(149,456)	$	(176,077)

(1)Includes the Company’s PEP.

(2)Prior to July 1, 1998, employees were eligible to elect an additional participant contribution to enhance their benefits and contributions made during the periods were insignificant.

Summary of Regulatory Assets and Accumulated Other Comprehensive Income

The following table summarizes the amounts recognized in regulatory assets and accumulated other comprehensive income as of September 30:

	Regulatory Assets				Accumulated Other Comprehensive Income (Loss)
	Pension		OPEB		Pension		OPEB
Balance at September 30, 2018	$	66,233	$	68,685	$	14,633	$	7,659
Amounts arising during the period:
Net actuarial loss	38,137		48,452		14,271		9,264
Amounts amortized to net periodic costs:
Net actuarial (loss)	(4,662)		(5,820)		(1,103)		(648)
Prior service credit	(102)		312		—		53
Balance at September 30, 2019	$	99,606	$	111,629	$	27,801	$	16,328
Amounts arising during the period:
Net actuarial loss (gain)	11,953		(21,974)		7,731		(1,614)
Amounts amortized to net periodic costs:
Net actuarial (loss)	(7,893)		(6,536)		(2,528)		(907)
Prior service (cost) credit	(102)		182		—		16
Balance at September 30, 2020	$	103,564	$	83,301	$	33,004	$	13,823

The amounts in regulatory assets and accumulated other comprehensive income not yet recognized as components of net periodic benefit cost as of September 30 are:

	Regulatory Assets								Accumulated Other Comprehensive Income (Loss)
	Pension				OPEB				Pension				OPEB
(Thousands)	2020		2019		2020		2019		2020		2019		2020		2019
Net actuarial loss	$	103,197	$	99,139	$	83,600	$	112,109	$	33,004	$	27,801	$	13,847	$	16,367
Prior service cost (credit)	367		467		(299)		(480)		—		—		(24)		(39)
Total	$	103,564	$	99,606	$	83,301	$	111,629	$	33,004	$	27,801	$	13,823	$	16,328

Schedule of Amounts Expected to be Recognized as Components of Net Periodic Benefit Cost

Amounts included in regulatory assets and accumulated other comprehensive income expected to be recognized as components of net periodic benefit cost in fiscal 2021 are as follows:

	Regulatory Assets				Accumulated Other Comprehensive Income (Loss)
(Thousands)	Pension		OPEB		Pension		OPEB
Net actuarial loss	$	8,269	$	6,846	$	3,178	$	1,064
Prior service cost (credit)	102		(166)		—		(13)
Total	$	8,371	$	6,680	$	3,178	$	1,051

Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets

The accumulated benefit obligation for the pension plans, including the PEP, exceeded the fair value of plan assets. The projected benefit and accumulated benefit obligations and the fair value of plan assets as of September 30, are as follows:

	Pension
(Thousands)	2020		2019
Projected benefit obligation	$	397,164	$	360,477
Accumulated benefit obligation	$	352,320	$	319,527
Fair value of plan assets	$	307,968	$	288,634

Components of Net Periodic Cost

The components of the net periodic cost for pension benefits, including the Company’s PEP, and OPEB costs (principally health care and life insurance) for employees and covered dependents for fiscal years ended September 30, are as follows:

	Pension						OPEB
(Thousands)	2020		2019		2018		2020		2019		2018
Service cost	$	8,223	$	7,381	$	8,139	$	4,854	$	4,404	$	4,607
Interest cost	10,587		12,173		10,493		7,026		8,324		6,365
Expected return on plan assets	(20,579)		(19,054)		(19,639)		(6,510)		(5,515)		(5,352)
Recognized actuarial loss	10,424		5,765		7,537		7,442		6,466		4,660
Prior service cost (credit) amortization	102		102		106		(197)		(365)		(365)
Net periodic benefit cost	8,757		$	6,367	$	6,636	$	12,615	$	13,314	9,915
Special termination benefit	—		—		3,730		—		—		490
Net periodic benefit cost recognized as expense	$	8,757	$	6,367	$	10,366	$	12,615	$	13,314	$	10,405

Schedule of Weighted Average Assumptions Used

The weighted average assumptions used to determine the Company’s benefit costs during the fiscal years below and obligations as of September 30, are as follows:

	Pension								OPEB
	2020		2019			2018			2020		2019			2018
Benefit costs:
Discount rate	3.37/3.35%	(1)	4.36/4.35%		(1)	4.04/4.03%		(1)	3.48/3.44%	(1)	4.38/4.37%		(1)	4.12/4.08%		(1)
Expected asset return	7.25		7.00	%		7.50	%		7.25		7.00	%		7.50	%
Compensation increase	3.00/3.50%	(1)	3.25/3.50%		(1)	3.25/3.50%		(1)	3.00/3.50%	(1)	3.25/3.50%		(1)	3.25/3.50%		(1)
Obligations:
Discount rate	2.95/2.92%	(1)	3.37/3.35%		(1)	4.36/4.35%			3.08/3.03%	(1)	3.48/3.44%		(1)	4.38/4.37%		(1)
Compensation increase	3.00/3.50%	(1)	3.00/3.50%		(1)	3.25/3.50%		(1)	3.00/3.50%	(1)	3.00/3.50%		(1)	3.25/3.50%		(1)

(1)Percentages for represented and nonrepresented plans, respectively.

Information on Assumed HCCTR Used to Determine Expected OPEB Benefits

Information relating to the assumed HCCTR used to determine expected OPEB benefits as of September 30, and the effect of a 1 percent change in the rate, are as follows:

($ in thousands)	2020		2019		2018
HCCTR	7.6%		7.6%		7.9%
Ultimate HCCTR	4.5%		4.5%		4.5%
Year ultimate HCCTR reached	2026		2026		2024
Effect of a 1 percentage point increase in the HCCTR on:
Year-end benefit obligation	$	49,106	$	49,061	$	36,260
Total service and interest cost	$	2,799	$	2,923	$	2,482
Effect of a 1 percentage point decrease in the HCCTR on:
Year-end benefit obligation	$	(38,844)	$	(38,747)	$	(28,743)
Total service and interest costs	$	(2,151)	$	(2,250)	$	(1,937)

Schedule of Mix and Targeted Allocation of Plan Assets

The mix and targeted allocation of the pension and OPEB plans’ assets are as follows:

	2021		Assets at
	Target		September 30,
Asset Allocation	Allocation		2020		2019
U.S. equity securities	34	%	38	%	37	%
International equity securities	17		18		17
Fixed income	38		39		42
Other assets	11		5		4
Total	100	%	100	%	100	%

Schedule of Expected Benefit Payments

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following fiscal years:

(Thousands)	Pension		OPEB
2021	$	12,799	$	6,179
2022	$	13,765	$	6,837
2023	$	14,512	$	7,420
2024	$	15,345	$	7,988
2025	$	16,267	$	8,625
2026 - 2030	$	95,969	$	52,480

Schedule of Estimated Subsidy Payments

The following estimated subsidy payments are expected to be paid during the following fiscal years:

	Estimated Subsidy
(Thousands)	Payment
2021		$	292
2022		$	316
2023		$	349
2024		$	384
2025		$	420
2026 - 2030		$	2,789

Summary of Pension and OPEB Assets Held in the Master Trust

Pension and OPEB assets held in the master trust, measured at fair value, as of September 30, are summarized as follows:

(Thousands)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Total
As of September 2020:	Pension				OPEB
Assets
Money market funds	$	—	$	—	$	15	$	15
Registered Investment Companies:
Equity Funds:
Large Cap Index	95,542		95,542		29,908		29,908
Extended Market Index	21,085		21,085		6,470		6,470
International Stock	56,912		56,912		17,390		17,390
Fixed Income Funds:
Emerging Markets	16,008		16,008		4,958		4,958
Core Fixed Income	—		—		11,146		11,146
Opportunistic Income	—		—		7,128		7,128
Ultra Short Duration	—		—		7,057		7,057
High Yield Bond Fund	26,303		26,303		8,223		8,223
Long Duration Fund	77,036		77,036		—		—
Total assets at in the fair value hierarchy	$	292,886	292,886		$	92,295	92,295
Investments measured at net asset value
Common collective trusts			15,082				4,111
Total assets at fair value			$	307,968			$	96,406

(Thousands)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Total
As of September 30, 2019:	Pension				OPEB
Assets
Money market funds	$	—	$	—	$	21	$	21
Registered Investment Companies:
Equity Funds:
Large Cap Index	89,374		89,374		25,474		25,474
Extended Market Index	16,548		16,548		5,036		5,036
International Stock	49,929		49,929		14,564		14,564
Fixed Income Funds:
Emerging Markets	15,794		15,794		4,764		4,764
Core Fixed Income	—		—		10,570		10,570
Opportunistic Income	—		—		6,365		6,365
Ultra Short Duration	—		—		6,340		6,340
High Yield Bond Fund	24,328		24,328		7,350		7,350
Long Duration Fund	80,041		80,041		—		—
Total assets at in the fair value hierarchy	$	276,014	276,014		$	80,484	80,484
Investments measured at net asset value
Common collective trusts			12,620				3,442
Total assets at fair value			$	288,634			$	83,926

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ASSET RETIREMENT OBLIGATIONS (Tables)

12 Months Ended

Sep. 30, 2020

Asset Retirement Obligation Disclosure [Abstract]

Analysis of Change in ARO Liability

The following is an analysis of the change in the Company’s ARO for the fiscal years ended September 30:

(Thousands)	2020				2019
	NJNG		NJRCEV		NJNG		NJRCEV
Balance at October 1	$	26,944	$	4,102	$	25,640	$	3,048
Accretion	1,476		196		1,427		150
Additions	—		1,306		135		904
Change in estimated useful life	—		(1,160)		—		—
Change in assumptions	1,104		—		—		—
Retirements	(244)		—		(258)		—
Other	—		—		—		—
Balance at period end	$	29,280	$	4,444	$	26,944	$	4,102

Schedule of Future Accretion

Accretion for the next five years, for the fiscal years ended September 30, is estimated to be as follows:

	Estimated
(Thousands)	Accretion
2021	$	1,717
2022	1,789
2023	1,869
2024	1,948
2025	2,029
Total	$	9,352

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INCOME TAXES (Tables)

12 Months Ended

Sep. 30, 2020

Income Tax Disclosure [Abstract]

Schedule of Components of Income Tax Benefit

The income tax benefit from operations for the fiscal years ended September 30, consists of the following:

(Thousands)	2020		2019		2018
Current:
Federal	$	(2,164)	$	10,933	$	(2,848)
State	6,763		3,530		4,563
Deferred:
Federal	28,817		4,103		(40,138)
State	3,400		4,003		7,181
Investment/production tax credits	(322)		(4,129)		(10,990)
Income tax expense (benefit)	$	36,494	$	18,440	$	(42,232)

Schedule of Deferred Tax Assets and Liabilities

As of September 30, the temporary differences, which give rise to deferred tax assets (liabilities), consist of the following:

(Thousands)	2020		2019
Deferred tax assets
Investment tax credits (1)	$	194,840	$	156,153
	—		—
Federal net operating losses (2)	24,091		24,173
State net operating losses	33,233		25,302
Fair value of derivatives	13,979		9,673
Postemployment benefits	8,544		9,192
Incentive compensation	7,071		7,231
Amortization of intangibles	5,892		4,991
Overrecovered natural gas costs	7,244		—
Other	2,370		7,139
Total deferred tax assets	$	297,264	$	243,854
Less: Valuation allowance	(17,639)		(4,035)
Total deferred tax assets net of valuation allowance	$	279,625	$	239,819
Deferred tax liabilities
Property related items	$	(359,604)	$	(313,246)
Remediation costs	(10,207)		(10,720)
Investments in equity investees	(23,395)		(21,730)
Underrecovered natural gas costs	—		(2,657)
Conservation incentive plan	(5,345)		(942)
Other	(6,639)		(4,776)
Total deferred tax liabilities	$	(405,190)	$	(354,071)
Total net deferred tax liabilities	$	(125,565)	$	(114,252)

(1)Includes $898,000 and $2 million for NJNG for fiscal 2020 and 2019, respectively, which is being amortized over the life of the related assets.

(2)See discussion of federal net operating loss utilization in the Other Tax Items section of this note.

Schedule of Effective Income Tax Rate Reconciliation

A reconciliation of the U.S. federal statutory rate to the effective rate from operations for the fiscal years ended September 30, is as follows:

(Thousands)	2020			2019			2018
Statutory income tax expense	$	41,896		$	29,898		$	45,961
Change resulting from:
Investment/production tax credits	(322)			(4,129)			(10,990)
Cost of removal of assets placed in service prior to 1981	(5,362)			(6,349)			(5,829)
AFUDC equity	(4,933)			(2,313)			(2,117)
State income taxes, net of federal benefit	11,965			6,262			7,322
NJ Unitary method change	(15,345)			—			—
Valuation allowance	13,604			—			—
Tax Act - utility excess deferred income taxes amortized (1)	(3,573)			(3,573)			(1,786)
Tax Act - nonutility excess deferred income taxes (1)	—			—			(59,627)
Tax Act - utility excess deferred income taxes refunded to customers (1)	—			—			(14,323)
Other	(1,436)			(1,356)			(843)
Income tax expense (benefit)	$	36,494		$	18,440		$	(42,232)
Effective income tax rate (2) (3)	18.3		%	14.0		%	(23.9)		%

(1)For a more detailed description, see The Tax Act section of this note.

(2)The U.S. federal statutory rate was 21 percent for both fiscal 2020 and 2019 and 24.5 percent for fiscal 2018.

(3)The effective tax rate without the impact of the Tax Act would have been 12.4 percent for fiscal 2018

Schedule of the Reserve for Uncertain Tax Benefits

The reserve for uncertain tax benefits for the fiscal year ended September 30, is as follows:

(Thousands)	2020		2019
Balance at October 1,	$	4,930	$	—
Additions based on tax positions related to the current fiscal period	—		4,930
Balance at period end	$	4,930	$	4,930

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LEASES (Tables)

12 Months Ended

Sep. 30, 2020

Leases [Abstract]

Lease, Cost

The following table presents the Company's lease costs included in the Consolidated Statements of Operations for the fiscal year ended September 30:

(Thousands)	Income Statement Location	2020
Finance lease cost
Amortization of right-of-use assets	Depreciation and amortization	$	5,007
Interest on lease liabilities	Interest expense, net of capitalized interest	1,511
Total finance lease cost		6,518
Operating lease cost	Operation and maintenance, net of capitalized costs	$	6,404
Short-term lease cost	Operation and maintenance	1,041
Variable lease cost	Operation and maintenance	1,025
Total lease cost		$	14,988

The following table presents supplemental cash flow information related to leases for the fiscal year ended September 30:

(Thousands)	2020
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	8,804
Operating cash flows from finance leases	$	1,189
Financing cash flows from finance leases	$	6,985

Assets and Liabilities, Lessee

The following table presents the balance and classifications of our right of use assets and lease liabilities included in the Consolidated Balance Sheets for the fiscal year ended September 30:

(Thousands)	Balance Sheet Location	2020
Assets
Noncurrent
Operating lease assets	Operating lease assets	$	131,769
Finance lease assets	Utility plant	71,085
Total lease assets		$	202,854
Liabilities
Current
Operating lease liabilities	Operating lease liabilities	$	6,724
Finance lease liabilities	Current maturities of long-term debt	10,416
Noncurrent
Operating lease liabilities	Operating lease liabilities	95,030
Finance lease liabilities	Long-term debt	63,743
Total lease liabilities		$	175,913

Lessee, Operating Lease, Liability, Maturity

The following table presents the Company's maturities of lease liabilities as of September 30, 2020:

(Thousands)	Operating Leases		Finance Leases
2021	$	6,706	$	54,992
2022	6,634		6,004
2023	6,590		4,622
2024	6,210		5,279
2025	5,646		3,396
Thereafter	122,085		2,324
Total future lease payments	153,871		76,617
Less: Liability accretion	(52,117)		(2,458)
Total lease liability	$	101,754	$	74,159

Finance Lease, Liability, Maturity

Contractual commitments for finance lease payments, as of the fiscal years ended September 30, are as follows:

(Thousands)	senior note
2021		$	54,992
2022		6,004
2023		4,622
2024		5,279
2025		3,396
Thereafter		2,324
Subtotal		76,617
Less: Interest component		(2,458)
Total		$	74,159

The following table presents the Company's maturities of lease liabilities as of September 30, 2020:

(Thousands)	Operating Leases		Finance Leases
2021	$	6,706	$	54,992
2022	6,634		6,004
2023	6,590		4,622
2024	6,210		5,279
2025	5,646		3,396
Thereafter	122,085		2,324
Total future lease payments	153,871		76,617
Less: Liability accretion	(52,117)		(2,458)
Total lease liability	$	101,754	$	74,159

Schedule of Future Minimum Rental Payments for Operating Leases

The following table reflects the Company's future minimum lease payments due under non-cancelable operating leases for continuing operations as of September 30, 2019, under ASC 840 and is being presented for comparative purposes. These commitments relate principally to commercial solar land leases, equipment and real property leases, including land and office facility leases, natural gas meters and office equipment.

(Thousands)	Operating Leases		Finance Leases
2020	$	4,411	$	11,707
2021	$	4,698	$	6,603
2022	$	4,609	$	7,494
2023	$	4,579	$	3,995
2024	$	4,199	$	4,652
Thereafter	$	54,405	$	4,173

Schedule of Future Minimum Lease Payments for Finance Leases

The following table reflects the Company's future minimum lease payments due under non-cancelable operating leases for continuing operations as of September 30, 2019, under ASC 840 and is being presented for comparative purposes. These commitments relate principally to commercial solar land leases, equipment and real property leases, including land and office facility leases, natural gas meters and office equipment.

(Thousands)	Operating Leases		Finance Leases
2020	$	4,411	$	11,707
2021	$	4,698	$	6,603
2022	$	4,609	$	7,494
2023	$	4,579	$	3,995
2024	$	4,199	$	4,652
Thereafter	$	54,405	$	4,173

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COMMITMENTS AND CONTINGENT LIABILITIES (Tables)

12 Months Ended

Sep. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Schedule of Commitments for Natural Gas Purchases and Future Demands Fees for the Next Five Years

Commitments as of September 30, 2020, for natural gas purchases and future demand fees for the next five fiscal year periods, are as follows:

(Thousands)	2021		2022		2023		2024		2025		Thereafter
Energy Services:
Natural gas purchases	$	151,270	$	1,600	$	—	$	—	$	—	$	—
Storage demand fees	21,857		13,028		8,632		3,748		2,488		942
Pipeline demand fees	76,462		53,451		29,736		22,687		17,110		36,527
Sub-total Energy Services	$	249,589	$	68,079	$	38,368	$	26,435	$	19,598	$	37,469
NJNG:
Natural gas purchases	$	4,377	$	—	$	—	$	—	$	—	$	—
Storage demand fees	36,096		32,122		20,303		12,768		6,830		3,530
Pipeline demand fees	88,564		131,578		107,614		85,118		79,609		552,465
Sub-total NJNG	$	129,037	$	163,700	$	127,917	$	97,886	$	86,439	$	555,995
Total	$	378,626	$	231,779	$	166,285	$	124,321	$	106,037	$	593,464

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REPORTING SEGMENT AND OTHER OPERATIONS DATA (Tables)

12 Months Ended

Sep. 30, 2020

Segment Reporting [Abstract]

Schedule of Business Segments and Other Operations

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

(Thousands)
Fiscal Years Ended September 30,	2020		2019		2018
Operating revenues
Natural Gas Distribution
External customers	$	729,923	$	710,793	$	731,865
Clean Energy Ventures
External customers	102,617		98,099		71,375
Energy Services
External customers (1)	1,029,303		1,734,553		2,064,477
Intercompany	1,116		8,238		48,327
Storage and Transportation
External customers (1)	42,015		—		—
Intercompany	2,713		—		—
Subtotal	1,907,687		2,551,683		2,916,044
Home Services and Other
External customers	49,810		48,600		47,392
Intercompany	1,207		2,302		2,665
Eliminations	(5,036)		(10,540)		(50,992)
Total	$	1,953,668	$	2,592,045	$	2,915,109
Depreciation and amortization
Natural Gas Distribution	$	71,883	$	57,980	$	53,208
Clean Energy Ventures	25,329		22,376		22,747
Energy Services (2)	123		118		76
Storage and Transportation	9,293		6		6
Subtotal	106,628		80,480		76,037
Home Services and Other	1,032		914		780
Eliminations	(292)		(285)		(246)
Total	$	107,368	$	81,109	$	76,571
Interest income (3)
Natural Gas Distribution	$	538	$	994	$	614
Clean Energy Ventures	240		—		—
Energy Services	99		78		240
Storage and Transportation	3,510		4,000		3,374
Subtotal	4,387		5,072		4,228
Home Services and Other	8,633		1,942		1,476
Eliminations	(10,061)		(5,391)		(5,090)
Total	$	2,959	$	1,623	$	614

(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 Consolidated Statements of Operations.

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

(Thousands)
Fiscal Years Ended September 30,	2020		2019		2018
Interest expense, net of capitalized interest
Natural Gas Distribution	$	30,975	$	26,134	$	25,299
Clean Energy Ventures	20,253		14,846		18,320
Energy Services	3,276		5,205		3,945
Storage and Transportation	13,124		2,185		1,667
Subtotal	67,628		48,370		49,231
Home Services and Other	10,327		1,535		7
Eliminations	(10,358)		(2,823)		(2,952)
Total	$	67,597	$	47,082	$	46,286
Income tax provision (benefit)
Natural Gas Distribution	$	27,021	$	9,434	$	(1,910)
Clean Energy Ventures	11,034		7,270		(68,379)
Energy Services	(3,615)		(1,573)		24,996
Storage and Transportation	4,247		2,254		(8,548)
Subtotal	38,687		17,385		(53,841)
Home Services and Other	(2,478)		1,428		11,944
Eliminations	285		(373)		(335)
Total	$	36,494	$	18,440	$	(42,232)
Equity in earnings of affiliates
Storage and Transportation	$	15,903	$	15,832	$	16,165
Eliminations	(1,592)		(2,204)		(3,157)
Total	$	14,311	$	13,628	$	13,008
Net financial earnings (loss)
Natural Gas Distribution	$	126,902	$	78,062	$	84,048
Clean Energy Ventures	22,111		31,903		73,426
Energy Services	(7,873)		2,918		60,378
Storage and Transportation	18,311		14,689		24,367
Subtotal	159,451		127,572		242,219
Home Services and Other	5,784		1,911		(3,829)
Eliminations	98		(93)		(327)
Total	$	165,333	$	129,390	$	238,063
Capital expenditures
Natural Gas Distribution	$	290,040	$	345,004	$	254,523
Clean Energy Ventures	133,841		157,828		123,421
Storage and Transportation	20,998		20,616		5,431
Subtotal	444,879		523,448		383,375
Home Services and Other	3,230		2,484		1,213
Total	$	448,109	$	525,932	$	384,588
Investments in equity investees
Storage and Transportation	$	2,117	$	4,102	$	16,151
Total	$	2,117	$	4,102	$	16,151

Reconciliation of Consolidated NFE to Consolidated Net Income

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

(Thousands)	2020		2019		2018
Consolidated net financial earnings	$	165,333	$	129,390	$	238,063
Less:
Unrealized (gain) loss on derivative instruments and related transactions	(9,644)		2,881		26,770
Tax effect	2,296		(711)		(4,512)
Effects of economic hedging related to natural gas inventory	12,690		4,309		(22,570)
Tax effect	(3,016)		(1,024)		7,362
Consolidated net income	$	163,007	$	123,935	$	231,013

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)	2020		2019		2018
Assets at end of period:
Natural Gas Distribution	$	3,531,477	$	3,064,309	$	2,663,054
Clean Energy Ventures (1)	814,277		694,439		740,704
Energy Services	244,836		290,847		396,852
Storage and Transportation	844,799		240,955		242,069
Subtotal	5,435,389		4,290,550		4,042,679
Home Services and Other	138,375		104,411		114,732
Intercompany assets (2)	(257,287)		(237,019)		(171,107)
Total	$	5,316,477	$	4,157,942	$	3,986,304

(1)Includes assets held for sale of $206.9 million for September 30, 2018.

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

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RELATED PARTY TRANSACTIONS (Tables)

12 Months Ended

Sep. 30, 2020

Related Party Transactions [Abstract]

Schedule of Related Party Transactions

Demand fees, net of eliminations, associated with Steckman Ridge during the fiscal years ended September 30, are as follows:

(Thousands)	2020		2019		2018
Natural Gas Distribution	$	5,900	$	5,814	$	5,730
Energy Services	183		2,134		2,775
Total	$	6,083	$	7,948	$	8,505

The following table summarizes demand fees payable to Steckman Ridge as of September 30:

(Thousands)	2020		2019
Natural Gas Distribution	$	775	$	775
Energy Services	16		15
Total	$	791	$	790

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ACQUISITIONS AND DISPOSITIONS (Tables)

12 Months Ended

Sep. 30, 2020

Business Combinations [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

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

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

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

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

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SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED) (Tables)

12 Months Ended

Sep. 30, 2020

Quarterly Financial Information Disclosure [Abstract]

Schedule of Quarterly Financial Data

A summary of financial data for each quarter of fiscal 2020 and 2019 follows. Due to the seasonal nature of the Company’s businesses, quarterly amounts vary significantly during the fiscal year. In the opinion of management, the information furnished reflects all adjustments necessary for a fair presentation of the results of the interim periods.

	First		Second		Third		Fourth
(Thousands, except per share data)	Quarter		Quarter		Quarter		Quarter
2020
Operating revenues	$	615,036	$	639,614	$	298,974	$	400,044
Operating income (loss)	$	104,618	$	98,483	$	(16,847)	$	42,655
Net income (loss)	$	75,752	$	73,846	$	(19,298)	$	32,707
Earnings (loss) per share (1)
Basic	$0.82		$0.78		$(0.20)		$0.34
Diluted	$0.82		$0.77		$(0.20)		$0.34
2019
Operating revenues	$	811,767	$	866,255	$	434,942	$	479,081
Operating income (loss) (2)	$	91,273	$	79,606	$	(1,372)	$	(4,951)
Net income (loss)	$	75,371	$	73,671	$	(13,080)	$	(12,027)
Earnings (loss) per share (1)
Basic	$0.87		$0.83		$(0.15)		$(0.16)
Diluted	$0.87		$0.83		$(0.15)		$(0.17)

(1)The sum of quarterly amounts may not equal the annual amounts due to rounding.

(2)Quarterly amounts have been reclassified to conform to the current period presentation due to the adoption of ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits. See Note 2. Summary of Significant Accounting Policies.

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NATURE OF THE BUSINESS (Details) customer in Thousands	12 Months Ended
	Sep. 30, 2020 customer subsidiary
Steckman Ridge
Nature of Business [Line Items]
Ownership interest, percent	50.00%
PennEast
Nature of Business [Line Items]
Ownership interest, percent	20.00%
NJNG
Nature of Business [Line Items]
Total retail customers (in customers) | customer	558
NJR Retail Holdings Corporation
Nature of Business [Line Items]
Number of principal subsidiaries (in subsidiaries) | subsidiary	2

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ADDITIONAL INFORMATION (Details) shares in Thousands					12 Months Ended
	Jul. 01, 2020	Jan. 13, 2020 mi	Mar. 06, 2019 USD ($)	Jan. 28, 2019 shares	Sep. 30, 2020 USD ($) plan	Sep. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)	Oct. 11, 2019 USD ($)	Oct. 01, 2019 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Composite rate of depreciation					2.65%	2.25%	2.29%
Depreciation and amortization					$ 107,368,000	$ 81,109,000	$ 76,571,000
SBC interest rate					1.97%	3.30%	3.41%
Deferred interest					$ 511,000	$ 760,000	$ 411,000
Loans receivable in other current assets					13,700,000	12,400,000
Loans receivable in other noncurrent assets					35,300,000	38,800,000
Gain (loss) amortized in earning					50,000
Available for sale equity securities							32,900,000
Debt conversion ratio				0.2492
Proceeds from sale of available for sale securities, net			$ 34,500,000		0	34,484,000	6,616,000
Gain on sale of available-for-sale securities, pre-tax			$ 1,600,000
Intangible assets, acquired wholesale natural gas energy					10,000,000
Proceeds from sale-leaseback transaction					4,000,000	9,895,000	7,820,000
Proceeds from sale leaseback transaction - solar					$ 42,927,000	0	71,538,000
Number of noncontributory defined benefit retirement plans (in plans) | plan					2
Number of noncontributory medical and life insurance plans (in plans) | plan					2
Operating lease assets					$ 131,769,000	0
Operating lease, liability					101,754,000
Leaf River Energy Center LLC
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease assets								$ 21,600,000
Operating lease, liability								$ 21,600,000
Accounting Standards Update 2016-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease assets									$ 67,100,000
Operating lease, liability									$ 67,100,000
Solar property | Nonutility
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Base gas cost					674,930,000	593,867,000
Storage and transportation property | Nonutility
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Base gas cost					428,491,000	28,445,000
Storage and transportation property, base gas | Nonutility
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Base gas cost					5,700,000
Pension
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Employer discretionary contributions					0	0	0
Employer contributions					596,000	231,000
OPEB
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Employer contributions					8,400,000	7,926,000	6,200,000
Clean Energy Ventures
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Proceeds from sale leaseback transaction - solar					42,900,000
Talen Generation, LLC | Talen's Membership Interests In IEC
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Pipeline length owned | mi		84
NJNG
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Proceeds from sale leaseback transaction - natural gas meters					$ 4,000,000
Proceeds from sale-leaseback transaction						$ 9,900,000	$ 7,800,000
Common Units
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other ownership interests, units issued (in shares) | shares				1,840
Dominion Shares
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other ownership interests, units issued (in shares) | shares				458
Seven-Year Treasury Rate
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt instrument, term					7 years
Basis spread on variable rate					0.60%
Minimum
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Storage and pipeline capacity, contract term					1 year
Loans receivable term					2 years
Minimum | Solar property | Nonutility
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Useful Lives	15 years				15 years	15 years	15 years
Minimum | Storage and transportation property | Nonutility
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Useful Lives					5 years
Minimum | Clean Energy Ventures
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Term of lease					5 years
Minimum | Talen Generation, LLC | Talen's Membership Interests In IEC
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Useful Lives					5 years
Minimum | NJNG
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Term of lease					7 years
Maximum
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Storage and pipeline capacity, contract term					10 years
Loans receivable term					10 years
Maximum | Solar property | Nonutility
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Useful Lives	35 years				35 years	25 years	25 years
Maximum | Storage and transportation property | Nonutility
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Useful Lives					50 years
Maximum | Clean Energy Ventures
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Term of lease					15 years
Maximum | Talen Generation, LLC | Talen's Membership Interests In IEC
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Useful Lives					30 years
Maximum | NJNG
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Term of lease					11 years

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - DEMAND FEES (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Demand fees	$ 253.7	$ 239.5	$ 245.5
Energy Services
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Demand fees	121.8	120.4	153.0
NJNG
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Demand fees	$ 131.9	$ 119.1	$ 92.5

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - PROPERTY PLANT AND EQUIPMENT (Details) - USD ($) $ in Thousands		12 Months Ended
	Jul. 01, 2020	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Property Classifications
Total property, plant and equipment		$ 4,464,966	$ 3,501,407
Accumulated depreciation and amortization		(742,197)	(691,774)
Property, plant and equipment, net		3,722,769	2,809,633
Utility | Distribution facilities
Property Classifications
Total property, plant and equipment		$ 2,688,885	2,419,381
Utility | Distribution facilities | Minimum
Property Classifications
Estimated Useful Lives		38 years
Utility | Distribution facilities | Maximum
Property Classifications
Estimated Useful Lives		74 years
Utility | Transmission facilities
Property Classifications
Total property, plant and equipment		$ 332,947	330,912
Utility | Transmission facilities | Minimum
Property Classifications
Estimated Useful Lives		35 years
Utility | Transmission facilities | Maximum
Property Classifications
Estimated Useful Lives		56 years
Utility | Storage facilities
Property Classifications
Total property, plant and equipment		$ 79,922	79,916
Utility | Storage facilities | Minimum
Property Classifications
Estimated Useful Lives		34 years
Utility | Storage facilities | Maximum
Property Classifications
Estimated Useful Lives		47 years
Nonutility | Solar property
Property Classifications
Total property, plant and equipment		$ 674,930	$ 593,867
Nonutility | Solar property | Minimum
Property Classifications
Estimated Useful Lives	15 years	15 years	15 years	15 years
Nonutility | Solar property | Maximum
Property Classifications
Estimated Useful Lives	35 years	35 years	25 years	25 years
Nonutility | Storage and transportation property
Property Classifications
Total property, plant and equipment		$ 428,491	$ 28,445
Nonutility | Storage and transportation property | Minimum
Property Classifications
Estimated Useful Lives		5 years
Nonutility | Storage and transportation property | Maximum
Property Classifications
Estimated Useful Lives		50 years
Nonutility | All other property
Property Classifications
Total property, plant and equipment		$ 259,791	$ 48,886
Nonutility | All other property | Minimum
Property Classifications
Estimated Useful Lives		5 years
Nonutility | All other property | Maximum
Property Classifications
Estimated Useful Lives		35 years

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - CAPITALIZED AND DEFERRED INTEREST (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
NJNG
AFUDC:
Debt	$ 5,134	$ 3,710	$ 1,979
Equity	14,599	6,492	5,531
Total	$ 19,733	$ 10,202	$ 7,510
Weighted average interest rate	6.79%	6.35%	5.94%
Adelphia Gateway
AFUDC:
Debt	$ 1,394
Equity	2,454
Total	$ 3,848
Weighted average interest rate	8.28%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - STATEMENT OF CASH FLOWS (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Accounting Policies [Abstract]
Cash and cash equivalents	$ 117,012	$ 2,676	$ 1,458
Restricted cash in other noncurrent assets	2,411	1,387	252
Cash, cash equivalents and restricted cash	$ 119,423	$ 4,063	$ 1,710	$ 2,469

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - GAS IN STORAGE (Details) $ in Thousands	Sep. 30, 2020 USD ($) Bcf	Sep. 30, 2019 USD ($) Bcf
Public Utilities, Inventory [Line Items]
Natural Gas in Storage | $	$ 167,504	$ 169,803
Bcf | Bcf	61.52	52.6
Natural Gas Distribution
Public Utilities, Inventory [Line Items]
Natural Gas in Storage | $	$ 110,037	$ 117,413
Bcf | Bcf	27.2	27.0
Energy Services
Public Utilities, Inventory [Line Items]
Natural Gas in Storage | $	$ 57,352	$ 52,390
Bcf | Bcf	34.3	25.6
Storage and Transportation
Public Utilities, Inventory [Line Items]
Natural Gas in Storage | $	$ 115	$ 0
Bcf | Bcf	0.02	0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - SOFTWARE COSTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Capitalized software costs	$ 4,707	$ 1,702
Software amortization	63
Operation and maintenance
Accumulated Other Comprehensive Income (Loss) [Line Items]
Software costs	6,720	9,062
Depreciation and amortization
Accumulated Other Comprehensive Income (Loss) [Line Items]
Software costs	284	0
Utility plant, at cost
Accumulated Other Comprehensive Income (Loss) [Line Items]
Software costs	13,452	0
Construction work in progress
Accumulated Other Comprehensive Income (Loss) [Line Items]
Software costs	0	4,778
Nonutility plant and equipment, at cost
Accumulated Other Comprehensive Income (Loss) [Line Items]
Software costs	316	0
Accumulated depreciation and amortization, utility plant
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated depreciation and amortization	279	0
Accumulated depreciation and amortization, nonutility plant and equipment
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated depreciation and amortization	$ 5	$ 0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - INTANGIBLE ASSETS (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Accounting Policies [Abstract]
2021	$ 5,101
2022	2,611
2023	2,271
2024	$ 77

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Thousands		12 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2017
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance		$ 1,381,833	$ 1,294,664
Reclassification of certain income tax effects to retained earnings		1,643,896	1,381,833	$ 1,114,752
Ending Balance		1,643,896	1,381,833
Investments in Equity Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance		0	3,446
Other comprehensive (loss), before reclassifications, net of tax		0	0
Amounts reclassified from accumulated other comprehensive income, net of tax		0	0
Net current-period other comprehensive (loss), net of tax		0	0
Reclassification of certain income tax effects to retained earnings		0	0
Ending Balance		0	0
Tax on other comprehensive income before reclassifications		0	0
Tax on amounts reclassified from accumulated other comprehensive income		0	0
Tax on net current-period other comprehensive income		0	0
Investments in Equity Securities | Cumulative Effect, Period of Adoption, Adjustment | Accounting Standards Update 2016-01
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance			(3,446)
Reclassification of certain income tax effects to retained earnings
Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance		0	0
Other comprehensive (loss), before reclassifications, net of tax		(10,505)	0
Amounts reclassified from accumulated other comprehensive income, net of tax		108	0
Net current-period other comprehensive (loss), net of tax		(10,397)	0
Reclassification of certain income tax effects to retained earnings		(10,397)	0
Ending Balance		(10,397)	0
Tax on other comprehensive income before reclassifications		3,203	0
Tax on amounts reclassified from accumulated other comprehensive income		(32)	0
Tax on net current-period other comprehensive income		3,171	0
Cash Flow Hedges | Cumulative Effect, Period of Adoption, Adjustment | Accounting Standards Update 2016-01
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance			0
Reclassification of certain income tax effects to retained earnings
Postemployment Benefit Obligation
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance		(31,787)	(16,056)
Other comprehensive (loss), before reclassifications, net of tax		(4,882)	(16,978)
Amounts reclassified from accumulated other comprehensive income, net of tax		2,751	1,247
Net current-period other comprehensive (loss), net of tax		(2,131)	(15,731)
Reclassification of certain income tax effects to retained earnings		(33,918)	(31,787)
Ending Balance		(33,918)	(31,787)
Tax on other comprehensive income before reclassifications		1,235	6,557
Tax on amounts reclassified from accumulated other comprehensive income		(668)	(451)
Tax on net current-period other comprehensive income		567	6,106
Postemployment Benefit Obligation | Cumulative Effect, Period of Adoption, Adjustment | Accounting Standards Update 2016-01
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance			0
Reclassification of certain income tax effects to retained earnings
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance		(31,787)	(12,610)
Other comprehensive (loss), before reclassifications, net of tax		(15,387)	(16,978)
Amounts reclassified from accumulated other comprehensive income, net of tax		2,859	1,247
Net current-period other comprehensive (loss), net of tax		(12,528)	(15,731)
Reclassification of certain income tax effects to retained earnings		(44,315)	(31,787)	$ (3,256)
Ending Balance		(44,315)	(31,787)
Tax on other comprehensive income before reclassifications		4,438	6,557
Tax on amounts reclassified from accumulated other comprehensive income		(700)	(451)
Tax on net current-period other comprehensive income		$ 3,738	6,106
Total | Cumulative Effect, Period of Adoption, Adjustment | Accounting Standards Update 2016-01
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning Balance	[1]		$ (3,446)
Reclassification of certain income tax effects to retained earnings

[1] See Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the Accounting Standards Codification section for more details.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 740 ON UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
OPERATING EXPENSES
Depreciation and amortization									$ 107,368	$ 81,109	$ 76,571
Total operating expenses									1,724,759	2,427,489	2,706,097
Operating income (loss)	$ 42,655	$ (16,847)	$ 98,483	$ 104,618	$ (4,951)	$ (1,372)	$ 79,606	$ 91,273	228,909	164,556	209,012
Income (loss) before income taxes and equity in earnings of affiliates									185,190	128,747	175,773
Income tax provision (benefit)									36,494	18,440	(42,232)
Net income (loss)	$ 32,707	$ (19,298)	$ 73,846	$ 75,752	$ (12,027)	$ (13,080)	$ 73,671	$ 75,371	$ 163,007	$ 123,935	$ 231,013
WEIGHTED AVERAGE SHARES OUTSTANDING
Diluted (in shares)									95,103	89,596	88,315
EARNINGS PER COMMON SHARE
Basic (in dollars per share)	$ 0.34	$ (0.20)	$ 0.78	$ 0.82	$ (0.16)	$ (0.15)	$ 0.83	$ 0.87	$ 1.72	$ 1.39	$ 2.63
Diluted (in dollars per share)	$ 0.34	$ (0.20)	$ 0.77	$ 0.82	$ (0.17)	$ (0.15)	$ 0.83	$ 0.87	$ 1.71	$ 1.38	$ 2.62
Previously Reported
OPERATING EXPENSES
Depreciation and amortization									$ 119,894	$ 91,730	$ 85,701
Total operating expenses									1,737,285	2,438,110	2,715,227
Operating income (loss)									216,383	153,935	199,882
Income (loss) before income taxes and equity in earnings of affiliates									172,664	118,126	166,643
Income tax provision (benefit)									(6,944)	(37,751)	(53,785)
Net income (loss)									$ 193,919	$ 169,505	$ 233,436
WEIGHTED AVERAGE SHARES OUTSTANDING
Diluted (in shares)									95,107	89,616
EARNINGS PER COMMON SHARE
Basic (in dollars per share)									$ 2.05	$ 1.90	$ 2.66
Diluted (in dollars per share)									$ 2.04	$ 1.89	$ 2.64
Effect of Change
OPERATING EXPENSES
Depreciation and amortization									$ (12,526)	$ (10,621)	$ (9,130)
Total operating expenses									(12,526)	(10,621)	(9,130)
Operating income (loss)									12,526	10,621	9,130
Income (loss) before income taxes and equity in earnings of affiliates									12,526	10,621	9,130
Income tax provision (benefit)									43,438	56,191	11,553
Net income (loss)									$ (30,912)	$ (45,570)	$ (2,423)
WEIGHTED AVERAGE SHARES OUTSTANDING
Diluted (in shares)									(4)	(20)
EARNINGS PER COMMON SHARE
Basic (in dollars per share)									$ (0.33)	$ (0.51)	$ (0.03)
Diluted (in dollars per share)									$ (0.33)	$ (0.51)	$ (0.02)

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 470 ON THE UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Assets [Abstract]
Nonutility plant and equipment, at cost	$ 1,108,512	$ 576,174
Accumulated depreciation and amortization, nonutility plant and equipment	(140,562)	(106,614)
Property, plant and equipment, net	3,722,769	2,809,633
Other noncurrent assets	85,657	116,059
Total noncurrent assets	971,376	836,703
Total assets	5,316,477	4,157,942	$ 3,986,304
CAPITALIZATION
Retained earnings	947,501	906,076
Reclassification of certain income tax effects to retained earnings	1,643,896	1,381,833	1,294,664	$ 1,114,752
Total capitalization	3,903,362	2,919,010
Liabilities [Abstract]
Deferred income taxes	138,081	145,504
Total noncurrent liabilities	879,393	792,555
Total capitalization and liabilities	5,316,477	4,157,942
Previously Reported
Assets [Abstract]
Nonutility plant and equipment, at cost	1,430,723	861,904
Accumulated depreciation and amortization, nonutility plant and equipment	(202,507)	(156,033)
Property, plant and equipment, net	3,983,035	3,045,944
Other noncurrent assets	78,716	94,791
Total noncurrent assets	964,435	815,435
Total assets	5,569,802	4,372,985
CAPITALIZATION
Retained earnings	1,148,297	1,075,960
Reclassification of certain income tax effects to retained earnings	1,844,692	1,551,717	1,418,978	1,236,643
Total capitalization	4,104,158	3,088,894
Liabilities [Abstract]
Deferred income taxes	190,610	190,663
Total noncurrent liabilities	931,922	837,714
Total capitalization and liabilities	5,569,802	4,372,985
Effect of Change
Assets [Abstract]
Nonutility plant and equipment, at cost	(322,211)	(285,730)
Accumulated depreciation and amortization, nonutility plant and equipment	61,945	49,419
Property, plant and equipment, net	(260,266)	(236,311)
Other noncurrent assets	6,941	21,268
Total noncurrent assets	6,941	21,268
Total assets	(253,325)	(215,043)
CAPITALIZATION
Retained earnings	(200,796)	(169,884)
Reclassification of certain income tax effects to retained earnings	(200,796)	(169,884)	$ (124,314)	$ (121,891)
Total capitalization	(200,796)	(169,884)
Liabilities [Abstract]
Deferred income taxes	(52,529)	(45,159)
Total noncurrent liabilities	(52,529)	(45,159)
Total capitalization and liabilities	$ (253,325)	$ (215,043)

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 740 ON THE UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation and amortization	$ 107,368	$ 81,109	$ 76,571
Deferred income taxes	34,346	(2,822)	27,143
Cash flows from operating activities	213,481	194,128	398,286
Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation and amortization	119,894	91,730	85,701
Deferred income taxes	(9,092)	(59,013)	15,590
Effect of Change
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Depreciation and amortization	(12,526)	(10,621)	(9,130)
Deferred income taxes	$ 43,438	$ 56,191	$ 11,553

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - IMPACT OF ASC 740 ON THE UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance				$ 1,381,833				$ 1,294,664	$ 1,381,833	$ 1,294,664	$ 1,114,752
Net income (loss)	$ 32,707	$ (19,298)	$ 73,846	75,752	$ (12,027)	$ (13,080)	$ 73,671	75,371	163,007	123,935	231,013
Ending Balance	1,643,896				1,381,833				1,643,896	1,381,833	1,294,664
Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance				906,076				882,803	906,076	882,803	746,093
Net income (loss)									163,007	123,935	231,013
Ending Balance	947,501				906,076				947,501	906,076	882,803
Previously Reported
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance				1,551,717				1,418,978	1,551,717	1,418,978	1,236,643
Net income (loss)									193,919	169,505	233,436
Ending Balance	1,844,692				1,551,717				1,844,692	1,551,717	1,418,978
Previously Reported | Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance				1,075,960				1,007,117	1,075,960	1,007,117	867,984
Net income (loss)									193,919	169,505	233,436
Ending Balance	1,148,297				1,075,960				1,148,297	1,075,960	1,007,117
Effect of Change
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance				(169,884)				(124,314)	(169,884)	(124,314)	(121,891)
Net income (loss)									(30,912)	(45,570)	(2,423)
Ending Balance	(200,796)				(169,884)				(200,796)	(169,884)	(124,314)
Effect of Change | Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance				$ (169,884)				$ (124,314)	(169,884)	(124,314)	(121,891)
Net income (loss)									(30,912)	(45,570)	(2,423)
Ending Balance	$ (200,796)				$ (169,884)				$ (200,796)	$ (169,884)	$ (124,314)

XML

REVENUE - DISAGGREGATED REVENUE - PRODUCT (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									$ 833,677	$ 782,331
Alternative revenue programs (2)									15,750	10,364
Derivative Instruments									1,105,357	1,807,588
Revenues out of scope									1,119,991	1,809,714
Total operating revenues	$ 400,044	$ 298,974	$ 639,614	$ 615,036	$ 479,081	$ 434,942	$ 866,255	$ 811,767	1,953,668	2,592,045	$ 2,915,109
Natural gas utility sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									695,858	680,151
Wholesale natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									69,239
Wholesale natural gas services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers										31,459
Service contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									32,455	31,499
Installations and maintenance
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									18,562	19,403
Renewable Energy Certificates
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									1,384
Electricity sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									20,099	22,121
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues									1,907,687	2,551,683	$ 2,916,044
Operating Segments | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									695,858	680,151
Alternative revenue programs (2)									15,750	10,364
Derivative Instruments									18,315	20,278
Revenues out of scope									34,065	30,642
Total operating revenues									729,923	710,793
Operating Segments | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									21,483	22,121
Alternative revenue programs (2)									0	0
Derivative Instruments									81,134	75,978
Revenues out of scope									81,134	75,978
Total operating revenues									102,617	98,099
Operating Segments | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									24,511	31,459
Alternative revenue programs (2)									0	0
Derivative Instruments									1,005,908	1,711,332
Revenues out of scope									1,004,792	1,703,094
Total operating revenues									1,029,303	1,734,553
Operating Segments | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									42,015	0
Alternative revenue programs (2)									0	0
Derivative Instruments									0	0
Revenues out of scope									0	0
Total operating revenues									42,015	0
Operating Segments | Natural gas utility sales | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									695,858	680,151
Operating Segments | Natural gas utility sales | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Natural gas utility sales | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Natural gas utility sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Wholesale natural gas services | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0
Operating Segments | Wholesale natural gas services | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0
Operating Segments | Wholesale natural gas services | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									24,511
Operating Segments | Wholesale natural gas services | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									44,728
Operating Segments | Wholesale natural gas services | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers										0
Operating Segments | Wholesale natural gas services | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers										0
Operating Segments | Wholesale natural gas services | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers										31,459
Operating Segments | Wholesale natural gas services | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers										0
Operating Segments | Service contracts | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Service contracts | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Service contracts | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Service contracts | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Installations and maintenance | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Installations and maintenance | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Installations and maintenance | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Installations and maintenance | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Renewable Energy Certificates | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0
Operating Segments | Renewable Energy Certificates | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									1,384
Operating Segments | Renewable Energy Certificates | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0
Operating Segments | Renewable Energy Certificates | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0
Operating Segments | Electricity sales | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Electricity sales | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									20,099	22,121
Operating Segments | Electricity sales | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments | Electricity sales | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues out of scope									0	0
Total operating revenues									49,810	48,600
Home Services and Other | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									49,810	48,600
Alternative revenue programs (2)									0	0
Derivative Instruments									0	0
Revenues out of scope									0	0
Total operating revenues									49,810	48,600
Home Services and Other | Natural gas utility sales | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Home Services and Other | Wholesale natural gas services | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0
Home Services and Other | Wholesale natural gas services | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers										0
Home Services and Other | Service contracts | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									32,455	31,499
Home Services and Other | Installations and maintenance | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									18,562	19,403
Home Services and Other | Renewable Energy Certificates | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0
Home Services and Other | Electricity sales | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(3,920)	(2,302)
Revenues out of scope									(1,116)	(8,238)
Eliminations | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Revenues out of scope									0	0
Eliminations | Clean Energy Ventures
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Revenues out of scope									0	0
Eliminations | Energy Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Revenues out of scope									(1,116)	(8,238)
Eliminations | Storage and Transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(2,713)	0
Revenues out of scope									0	0
Eliminations | Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(1,207)	(2,302)
Revenues out of scope									$ 0	$ 0

XML

REVENUE - DISAGGREGATED REVENUE - TYPE (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									$ 833,677	$ 782,331
Revenues out of scope									1,119,991	1,809,714
Total operating revenues	$ 400,044	$ 298,974	$ 639,614	$ 615,036	$ 479,081	$ 434,942	$ 866,255	$ 811,767	1,953,668	2,592,045	$ 2,915,109
Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									549,333	497,445
Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									208,665	216,879
Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									69,357	61,370
Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									6,322	6,637
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues									1,907,687	2,551,683	$ 2,916,044
Home Services and Other
Disaggregation of Revenue [Line Items]
Revenues out of scope									0	0
Total operating revenues									49,810	48,600
Home Services and Other | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									48,867	47,655
Home Services and Other | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									943	945
Home Services and Other | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Home Services and Other | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Natural Gas Distribution | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									695,858	680,151
Revenues out of scope									34,065	30,642
Total operating revenues									729,923	710,793
Natural Gas Distribution | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									490,233	440,787
Natural Gas Distribution | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									129,946	171,357
Natural Gas Distribution | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									69,357	61,370
Natural Gas Distribution | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									6,322	6,637
Clean Energy Ventures | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									21,483	22,121
Revenues out of scope									81,134	75,978
Total operating revenues									102,617	98,099
Clean Energy Ventures | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									10,233	9,003
Clean Energy Ventures | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									11,250	13,118
Clean Energy Ventures | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Clean Energy Ventures | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Energy Services | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									24,511	31,459
Revenues out of scope									1,004,792	1,703,094
Total operating revenues									1,029,303	1,734,553
Energy Services | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Energy Services | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									24,511	31,459
Energy Services | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Energy Services | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Storage and Transportation | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									42,015	0
Revenues out of scope									0	0
Total operating revenues									42,015	0
Storage and Transportation | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Storage and Transportation | Operating Segments | Commercial and industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									42,015	0
Storage and Transportation | Operating Segments | Firm transportation
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Storage and Transportation | Operating Segments | Interruptible and off-tariff
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									$ 0	$ 0

XML

REVENUE - TIMING OF REVENUE RECOGNITION (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Timing of Revenue Recognition [Roll Forward]
Billed, beginning	$ 139,263
Unbilled, beginning	6,510
Customers' credit, beginning	27,116
Increase (decrease) for accounts receivable, billed	(5,090)
Increase (decrease) for unbilled revenue	2,716
Increase (decrease) for customers' credits	(1,182)
Billed, end	134,173
Unbilled, end	9,226
Customers' credit, end	$ 25,934

XML

REVENUE - TIMING OF REVENUE RECOGNITION - BALANCE SHEET (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Customer accounts receivable:
Billed	$ 134,173	$ 139,263
Unbilled revenues	9,226	6,510
Customers' credit balances and deposits	(25,934)	(27,116)
Customers accounts receivables & Customers' credit balances and deposits	117,465	118,657
Operating Segments | Natural Gas Distribution
Customer accounts receivable:
Billed	52,134	36,302
Unbilled revenues	7,842	6,510
Customers' credit balances and deposits	(25,934)	(27,114)
Customers accounts receivables & Customers' credit balances and deposits	34,042	15,698
Operating Segments | Clean Energy Ventures
Customer accounts receivable:
Billed	5,282	3,233
Unbilled revenues	1,384	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	6,666	3,233
Operating Segments | Energy Services
Customer accounts receivable:
Billed	70,457	97,301
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	70,457	97,301
Operating Segments | Storage and Transportation
Customer accounts receivable:
Billed	3,905	0
Unbilled revenues	0	0
Customers' credit balances and deposits	0	0
Customers accounts receivables & Customers' credit balances and deposits	3,905	0
Home Services and Other
Customer accounts receivable:
Billed	2,395	2,427
Unbilled revenues	0	0
Customers' credit balances and deposits	0	(2)
Customers accounts receivables & Customers' credit balances and deposits	$ 2,395	$ 2,425

XML

REGULATION - REGULATORY FILINGS (Details) $ in Thousands																						1 Months Ended			3 Months Ended	4 Months Ended	8 Months Ended	12 Months Ended		13 Months Ended
	Oct. 28, 2020 USD ($)	Sep. 29, 2020 USD ($)	Sep. 25, 2020 USD ($)	Sep. 09, 2020 USD ($)	Jun. 25, 2020 USD ($)	May 29, 2020 USD ($)	Mar. 30, 2020 USD ($)	Mar. 27, 2020 USD ($)	Mar. 16, 2020 USD ($)	Nov. 15, 2019 USD ($)	Nov. 01, 2019 USD ($)	Sep. 27, 2019 USD ($)	Jul. 02, 2019 USD ($)	Jun. 24, 2019 USD ($)	Apr. 30, 2019 USD ($)	Feb. 28, 2019 USD ($) lease	Jan. 01, 2019 USD ($)	Sep. 30, 2018 USD ($)	Sep. 17, 2018 USD ($)	May 22, 2018 USD ($)	Mar. 01, 2018 USD ($)	Sep. 30, 2019 USD ($)	Mar. 31, 2019 USD ($)	Sep. 30, 2018 USD ($)	Jun. 30, 2020 USD ($)	Jul. 24, 2020 USD ($)	Sep. 30, 2019 USD ($)	Sep. 30, 2020 USD ($) filings project	Sep. 30, 2018 USD ($)	Sep. 30, 2019 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory assets-current																						$ 32,871					$ 32,871	$ 36,530		$ 32,871
Regulatory assets-noncurrent																						496,637					496,637	$ 527,459		496,637
Number of interim filings during each fiscal year | filings																												2
Number of days notice for refund																												5 days
Change in tax rate, deferred tax liability, provisional income tax (expense) benefit																													$ 228,400
Change in tax rate, deferred income taxes																													164,300
Change in tax rate, provisional income tax expense (benefit)																													$ 64,100
Regulatory liability, excess deferred income taxes																												$ 195,000
Environmental Remediation Costs
Public Utilities, General Disclosures [Line Items]
Regulatory assets, amortization period																												7 years
Postemployment and Other Benefit Costs
Public Utilities, General Disclosures [Line Items]
Regulatory assets, amortization period																												7 years
Deferred Storm Damage Costs
Public Utilities, General Disclosures [Line Items]
Regulatory assets, amortization period																												7 years
Other Regulatory Asset Noncurrent, PIM
Public Utilities, General Disclosures [Line Items]
Regulatory assets-noncurrent																												$ 1,800
Regulatory assets, amortization period																												7 years
SAVEGREEN
Public Utilities, General Disclosures [Line Items]
Capital investments approved by the BPU			$ 127,000															$ 354,300						$ 135,000
Public Utility, Program Term, Extension			3 years
Financing options			$ 113,000
Operations and maintenance expense			$ 23,000
Increase in regulatory funding obligations																	$ 8,800
SAVEGREEN | Minimum
Public Utilities, General Disclosures [Line Items]
Regulatory assets, amortization period																												2 years
Program recovery term																												3 years
SAVEGREEN | Maximum
Public Utilities, General Disclosures [Line Items]
Regulatory assets, amortization period																												10 years
Program recovery term																												10 years
USF
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount																														1,000
RAC
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount		$ 1,300																												1,400
NJCEP
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount		$ 6,000																												$ 1,900
SAFE Program
Public Utilities, General Disclosures [Line Items]
Capital investments approved by the BPU																												$ 130,000
Capital investments approved by the BPU, period																												4 years
Capital investments to be recovered approved by the Board of Public Utilities																												$ 200,000
Recovery amount																												$ 157,500
SAFE II
Public Utilities, General Disclosures [Line Items]
Capital investments approved by the BPU, period																												5 years
NJ RISE Program
Public Utilities, General Disclosures [Line Items]
Return on equity																												9.75%
Program recovery term																												5 years
Number of capital investment projects | project																												6
Originally filed petition for capital investments to Board of Public Utilities																												$ 102,500
NJ RISE Program | Minimum
Public Utilities, General Disclosures [Line Items]
Public utilities, approved equity capital structure, percentage																												6.74%
NJ RISE Program | Maximum
Public Utilities, General Disclosures [Line Items]
Public utilities, approved equity capital structure, percentage																												6.90%
SAFE II and NJ RISE
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount												$ 7,800							$ 6,800
March 2018 BGSS/CIP Filing
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount																					$ 19,700
Requested customer refunds																					$ 31,000
Approved customer refunds																				$ 31,000
NJNG EE Recovery Rate | NJNG
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount						$ 11,400					$ 11,300
Base Rate Stipulation
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Percentage																												6.95%
Return on equity																												9.60%
Public utilities, approved equity capital structure, percentage																												54.00%
Approved rate increase (decrease), amount										$ 62,200
Public Utilities, Approved Depreciation Rate, Percentage																												2.78%
NJNG | BPU
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount													$ 129,800									$ 134,300	$ 128,200
Requested return on equity, percentage																							7.87%
NJNG | BGSS
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount				$ (20,400)				$ (17,600)							$ 10,300
NJNG | Conservation Incentive Program
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount				16,500				10,600							$ (30,900)
NJNG | BGSS/CIP Filing
Public Utilities, General Disclosures [Line Items]
Interim rate increase (decrease), amount																											$ 10,900
NJNG | BGSS Balancing
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount				$ (3,800)				$ 15,600
NJNG | RAC
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount									$ 1,200			1,400
NJNG | NJCEP
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount									$ (600)			$ 3,300
NJNG | June 2019 Annual USF Compliance Filing
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount														$ 1,200
NJNG | Infrastructure Investment Program (IIP)
Public Utilities, General Disclosures [Line Items]
Program recovery term																5 years
Number of project components | lease																2
Public utilities, investments																$ 507,000
NJNG | Infrastructure Investment Program (IIP) | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Program recovery term	5 years
Public utilities, investments	$ 150,000
NJNG | NJ RISE And SAFE II Capital Investments
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount							$ 7,400
Approved rate increase (decrease), amount																										$ 7,100
Capital investment costs																									$ 57,900	$ 55,100
NJNG | June 2020 Annual USF Compliance Filing
Public Utilities, General Disclosures [Line Items]
Requested base rate increase (decrease), amount					$ (400)
Storage and Transportation
Public Utilities, General Disclosures [Line Items]
Regulatory assets-current																												$ 158
Regulatory assets-noncurrent																												$ 997

XML

REGULATION - REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Regulatory Assets [Line Items]
Regulatory assets-current	$ 36,530	$ 32,871
Regulatory assets-noncurrent	527,459	496,637
Regulatory Liabilities [Line Items]
Regulatory liability-current	26,188	0
Regulatory liabilities-noncurrent	196,450	202,435
Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-current	36,372	32,871
Regulatory assets-noncurrent	526,462	496,637
Regulatory Liabilities [Line Items]
Regulatory liability-current	26,188	0
Regulatory liabilities-noncurrent	196,286	202,435
Overrecovered natural gas costs | Natural Gas Distribution
Regulatory Liabilities [Line Items]
Regulatory liability-current	25,914	0
Derivatives at fair value, net | Natural Gas Distribution
Regulatory Liabilities [Line Items]
Regulatory liability-current	274	0
Regulatory liabilities-noncurrent	352	0
Tax Act impact | Natural Gas Distribution
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	195,425	200,417
New Jersey Clean Energy Program | Natural Gas Distribution
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	0	197
Other noncurrent regulatory liabilities | Natural Gas Distribution
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	509	1,821
New Jersey Clean Energy Program | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-current	15,570	15,468
Conservation Incentive Program | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-current	19,120	3,371
Underrecovered natural gas costs | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-current	0	9,506
Derivatives at fair value, net | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-current	0	4,526
Regulatory assets-noncurrent	1	486
Other current regulatory assets | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-current	1,682	0
Environmental remediation costs, Expended, net of recoveries
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	36,500
Environmental remediation costs, Expended, net of recoveries | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	36,516	38,351
Environmental remediation costs, Liability for future expenditures
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	150,600	131,100
Environmental remediation costs, Liability for future expenditures | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	150,590	131,080
Deferred income taxes | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	28,241	19,631
SAVEGREEN | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	21,281	10,201
Postemployment and other benefit costs | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	188,170	212,461
Deferred storm damage costs | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	6,515	8,687
Cost of removal | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	75,080	65,660
Other noncurrent regulatory assets | Natural Gas Distribution
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	$ 20,068	$ 10,080

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DERIVATIVE INSTRUMENTS - BALANCE SHEET RELATED DISCLOSURES (Details) - USD ($) $ in Thousands		12 Months Ended
	Mar. 13, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Jul. 31, 2020	May 30, 2018	May 15, 2018	May 11, 2018	Jan. 26, 2018	Jun. 30, 2015
Derivatives, Fair Value [Line Items]
Gain (loss) amortized in earning		$ 50
Asset Derivatives, current		23,310	$ 25,103
Asset Derivatives, noncurrent		3,349	7,426
Liability Derivatives, current		33,865	57,623
Liability Derivatives, noncurrent		13,352	18,821
Derivatives not designated as hedging instruments:
Derivatives, Fair Value [Line Items]
Loss recognized in income on derivatives		(56,705)	7,412	$ 34,175
Asset Derivatives		26,659	32,529
Liability Derivatives		47,217	76,444
Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Amounts reclassified from accumulated other comprehensive income, net of tax		108	0
Treasury lock
Derivatives, Fair Value [Line Items]
Benchmark interest rate										3.26%
Interest rate, stated percentage								4.01%
Loss recognized in income on derivatives	$ 2,600
Unsecured senior notes | Credit Agreement Due August 16, 2019 | Interest rate swap
Derivatives, Fair Value [Line Items]
Benchmark interest rate									2.84%
Debt issued									$ 100,000
Home Services and Other | Treasury lock
Derivatives, Fair Value [Line Items]
Loss recognized in income on derivatives		13,700
Home Services and Other | Debt Issued In September 2020
Derivatives, Fair Value [Line Items]
Debt issued		200,000
Home Services and Other | Debt Issued In July 2020
Derivatives, Fair Value [Line Items]
Debt issued					$ 260,000
Natural Gas Distribution | Derivatives not designated as hedging instruments:
Derivatives, Fair Value [Line Items]
Loss recognized in income on derivatives		1,826	1,774	(11,543)
Natural Gas Distribution | Treasury lock
Derivatives, Fair Value [Line Items]
Loss recognized in income on derivatives		6,600
Natural Gas Distribution | Physical commodity contracts | Derivatives not designated as hedging instruments:
Derivatives, Fair Value [Line Items]
Loss recognized in income on derivatives		(2,077)	(5,926)	(1,232)
Asset Derivatives, current		78	67
Liability Derivatives, current		76	245
Natural Gas Distribution | Financial commodity contracts | Derivatives not designated as hedging instruments:
Derivatives, Fair Value [Line Items]
Loss recognized in income on derivatives		3,903	7,700	$ (1,844)
Asset Derivatives, current		71	382
Liability Derivatives, current		282	570
Natural Gas Distribution | Series LL
Derivatives, Fair Value [Line Items]
Debt issued							$ 125,000
Interest rate, stated percentage							5.60%
Natural Gas Distribution | Debt Issued In September 2020
Derivatives, Fair Value [Line Items]
Debt issued		75,000
Natural Gas Distribution | First Mortgage | Series VV
Derivatives, Fair Value [Line Items]
Debt issued						$ 125,000		$ 125,000
Energy Services | Physical commodity contracts | Derivatives not designated as hedging instruments:
Derivatives, Fair Value [Line Items]
Asset Derivatives, current		6,454	6,847
Asset Derivatives, noncurrent		1,264	1,710
Liability Derivatives, current		20,438	27,540
Liability Derivatives, noncurrent		12,003	12,641
Energy Services | Financial commodity contracts | Derivatives not designated as hedging instruments:
Derivatives, Fair Value [Line Items]
Asset Derivatives, current		16,671	17,806
Asset Derivatives, noncurrent		2,037	5,716
Liability Derivatives, current		12,965	29,057
Liability Derivatives, noncurrent		1,346	6,105
Energy Services | Foreign currency contracts | Derivatives not designated as hedging instruments:
Derivatives, Fair Value [Line Items]
Asset Derivatives, current		36	1
Asset Derivatives, noncurrent		48	0
Liability Derivatives, current		104	211
Liability Derivatives, noncurrent		$ 3	$ 75

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DERIVATIVE INSTRUMENTS - OFFSETTING OF ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Energy Services
Derivative assets:
Amounts Presented on the Balance Sheets	$ 26,510	$ 32,080
Offsetting Derivative Instruments	(17,982)	(22,553)
Financial Collateral Received/Pledged	(200)	(200)
Net Amounts	8,328	9,327
Derivative liabilities:
Amounts Presented in Balance Sheets	46,859	75,629
Offsetting Derivative Instruments	(17,982)	(22,553)
Financial Collateral Received/Pledged	0	(15,516)
Net Amounts	28,877	37,560
Energy Services | Physical commodity contracts
Derivative assets:
Amounts Presented on the Balance Sheets	7,718	8,557
Offsetting Derivative Instruments	(3,587)	(2,906)
Financial Collateral Received/Pledged	(200)	(200)
Net Amounts	3,931	5,451
Derivative liabilities:
Amounts Presented in Balance Sheets	32,441	40,181
Offsetting Derivative Instruments	(3,587)	(2,906)
Financial Collateral Received/Pledged	0	0
Net Amounts	28,854	37,275
Energy Services | Financial commodity contracts
Derivative assets:
Amounts Presented on the Balance Sheets	18,708	23,522
Offsetting Derivative Instruments	(14,311)	(19,646)
Financial Collateral Received/Pledged	0	0
Net Amounts	4,397	3,876
Derivative liabilities:
Amounts Presented in Balance Sheets	14,311	35,162
Offsetting Derivative Instruments	(14,311)	(19,646)
Financial Collateral Received/Pledged	0	(15,516)
Net Amounts	0	0
Energy Services | Foreign currency contracts
Derivative assets:
Amounts Presented on the Balance Sheets	84	1
Offsetting Derivative Instruments	(84)	(1)
Financial Collateral Received/Pledged	0	0
Net Amounts	0	0
Derivative liabilities:
Amounts Presented in Balance Sheets	107	286
Offsetting Derivative Instruments	(84)	(1)
Financial Collateral Received/Pledged	0	0
Net Amounts	23	285
Natural Gas Distribution
Derivative assets:
Amounts Presented on the Balance Sheets	149	449
Offsetting Derivative Instruments	(136)	(391)
Financial Collateral Received/Pledged	0	0
Net Amounts	13	58
Derivative liabilities:
Amounts Presented in Balance Sheets	358	815
Offsetting Derivative Instruments	(136)	(391)
Financial Collateral Received/Pledged	0	(188)
Net Amounts	222	236
Natural Gas Distribution | Physical commodity contracts
Derivative assets:
Amounts Presented on the Balance Sheets	78	67
Offsetting Derivative Instruments	(65)	(9)
Financial Collateral Received/Pledged	0	0
Net Amounts	13	58
Derivative liabilities:
Amounts Presented in Balance Sheets	76	245
Offsetting Derivative Instruments	(65)	(9)
Financial Collateral Received/Pledged	0	0
Net Amounts	11	236
Natural Gas Distribution | Financial commodity contracts
Derivative assets:
Amounts Presented on the Balance Sheets	71	382
Offsetting Derivative Instruments	(71)	(382)
Financial Collateral Received/Pledged	0
Net Amounts	0	0
Derivative liabilities:
Amounts Presented in Balance Sheets	282	570
Offsetting Derivative Instruments	(71)	(382)
Financial Collateral Received/Pledged	0	(188)
Net Amounts	$ 211	$ 0

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DERIVATIVE INSTRUMENTS - INCOME STATEMENT RELATED DISCLOSURES (Details) - Derivatives not designated as hedging instruments: - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 56,705	$ (7,412)	$ (34,175)
Energy Services | Physical commodity contracts | Operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	1,163	(5,732)	(9,311)
Energy Services | Physical commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	(3,366)	(521)	(197)
Energy Services | Financial commodity contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	58,949	(643)	(24,622)
Energy Services | Foreign currency contracts | Natural gas purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	(41)	(283)	(379)
Natural Gas Distribution
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	(1,826)	(1,774)	11,543
Natural Gas Distribution | Physical commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	2,077	5,926	1,232
Natural Gas Distribution | Financial commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	(3,903)	(7,700)	1,844
Natural Gas Distribution | Interest rate contract
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	0	0	8,467
Home Services and Other | Interest rate contract | Interest expense
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	$ 0	$ (233)	$ 334

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DERIVATIVE INSTRUMENTS - EFFECT OF DERIVATIVE INSTRUMENTS DESIGNATED AS CASH FLOW HEDGES ON OCI (Details) (Details) - Treasury lock - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Derivative [Line Items]
Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives	$ (13,568)	$ 0
Interest expense
Derivative [Line Items]
Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income	$ 140	$ 0

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DERIVATIVE INSTRUMENTS - VOLUME (Details) certificate in Thousands, $ in Millions	Sep. 30, 2020 USD ($) Bcf certificate	Sep. 30, 2019 USD ($) Bcf certificate
Foreign currency contracts
Derivative [Line Items]
Derivative, notional amount | $	$ 5.1	$ 6.2
Natural Gas Distribution | Long | Futures
Derivative [Line Items]
Outstanding long (short) derivatives (in Bcf)	23.7	27.6
Natural Gas Distribution | Long | Physical Commodity
Derivative [Line Items]
Outstanding long (short) derivatives (in Bcf)	6.0	11.6
Energy Services | Physical commodity contracts
Derivative [Line Items]
Number of SRECs (in certificates) | certificate	960	796
Energy Services | Long | Physical Commodity
Derivative [Line Items]
Outstanding long (short) derivatives (in Bcf)	5.0	44.5
Energy Services | Long | Options
Derivative [Line Items]
Outstanding long (short) derivatives (in Bcf)	0	1.0
Energy Services | Short | Futures
Derivative [Line Items]
Outstanding long (short) derivatives (in Bcf)	27.5	29.6
Energy Services | Short | Swaps
Derivative [Line Items]
Outstanding long (short) derivatives (in Bcf)	1.8	5.0

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DERIVATIVE INSTRUMENTS - BROKER MARGIN DEPOSITS (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Natural Gas Distribution
Derivative [Line Items]
Broker margin - Current assets	$ 13,525	$ 1,982
Energy Services
Derivative [Line Items]
Broker margin - Current assets	$ 55,919	$ 71,741

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DERIVATIVE INSTRUMENTS - CREDIT RISK EXPOSURE (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 177,750
Investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	132,105
Noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	8,527
Internally-rated investment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	24,647
Internally-rated noninvestment grade
Credit Risk Exposure [Line Items]
Gross Credit Exposure	$ 12,471

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FAIR VALUE - DEBT (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total lease liability	$ 74,159	$ 35,400
NJNG
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	9,195	9,027
Fair market value | Solar Asset Financing | Clean Energy Ventures
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	149,200	98,600
NJR
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt issuance costs	3,400	2,000
Significant Other Observable Inputs (Level 2) | NJNG | Carrying value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	1,092,845	892,845
Significant Other Observable Inputs (Level 2) | NJNG | Fair market value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	1,271,715	984,129
Significant Other Observable Inputs (Level 2) | NJR | Carrying value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	1,010,000	550,000
Significant Other Observable Inputs (Level 2) | NJR | Fair market value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 1,146,033	$ 584,735

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FAIR VALUE - HIERARCHY (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Assets
Other	$ 1,840	$ 1,706
Total assets at fair value	140,790	34,235
Liabilities
Total liabilities at fair value	47,217	76,444
Money market funds
Assets
Derivative assets	112,291
Physical commodity contracts
Assets
Derivative assets	7,796	8,624
Liabilities
Derivative liabilities	32,517	40,426
Financial commodity contracts
Assets
Derivative assets	18,779	23,904
Liabilities
Derivative liabilities	14,593	35,732
Foreign currency contracts
Assets
Derivative assets	84	1
Liabilities
Derivative liabilities	107	286
Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets
Other	1,840	1,706
Total assets at fair value	132,410	21,734
Liabilities
Total liabilities at fair value	14,593	35,732
Quoted Prices in Active Markets for Identical Assets (Level 1) | Money market funds
Assets
Derivative assets	112,291
Quoted Prices in Active Markets for Identical Assets (Level 1) | Physical commodity contracts
Assets
Derivative assets	0	0
Liabilities
Derivative liabilities	0	0
Quoted Prices in Active Markets for Identical Assets (Level 1) | Financial commodity contracts
Assets
Derivative assets	18,279	20,028
Liabilities
Derivative liabilities	14,593	35,732
Quoted Prices in Active Markets for Identical Assets (Level 1) | Foreign currency contracts
Assets
Derivative assets	0	0
Liabilities
Derivative liabilities	0	0
Significant Other Observable Inputs (Level 2)
Assets
Other	0	0
Total assets at fair value	8,380	12,501
Liabilities
Total liabilities at fair value	32,624	40,712
Significant Other Observable Inputs (Level 2) | Money market funds
Assets
Derivative assets	0
Significant Other Observable Inputs (Level 2) | Physical commodity contracts
Assets
Derivative assets	7,796	8,624
Liabilities
Derivative liabilities	32,517	40,426
Significant Other Observable Inputs (Level 2) | Financial commodity contracts
Assets
Derivative assets	500	3,876
Liabilities
Derivative liabilities	0	0
Significant Other Observable Inputs (Level 2) | Foreign currency contracts
Assets
Derivative assets	84	1
Liabilities
Derivative liabilities	107	286
Significant Unobservable Inputs (Level 3)
Assets
Other	0	0
Total assets at fair value	0	0
Liabilities
Total liabilities at fair value	0	0
Significant Unobservable Inputs (Level 3) | Money market funds
Assets
Derivative assets	0
Significant Unobservable Inputs (Level 3) | Physical commodity contracts
Assets
Derivative assets	0	0
Liabilities
Derivative liabilities	0	0
Significant Unobservable Inputs (Level 3) | Financial commodity contracts
Assets
Derivative assets	0	0
Liabilities
Derivative liabilities	0	0
Significant Unobservable Inputs (Level 3) | Foreign currency contracts
Assets
Derivative assets	0	0
Liabilities
Derivative liabilities	$ 0	$ 0

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INVESTMENTS IN EQUITY INVESTEES (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($) mi	Sep. 30, 2019 USD ($)
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 208,375	$ 200,268
Deferred tax gross up	4,600	4,100
Steckman Ridge
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	112,378	114,428
Outstanding principal balance	$ 70,400	70,400
Ownership interest, percent	50.00%
PennEast
Schedule of Equity Method Investments [Line Items]
Investments in equity investees	$ 95,997	$ 85,840
Ownership interest, percent	20.00%
Construction plan, pipeline distance (in miles) | mi	120
NJR Pipeline | PennEast
Schedule of Equity Method Investments [Line Items]
Ownership interest, percent	20.00%

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EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Earnings Per Share [Abstract]
Net income, as reported	$ 32,707	$ (19,298)	$ 73,846	$ 75,752	$ (12,027)	$ (13,080)	$ 73,671	$ 75,371	$ 163,007	$ 123,935	$ 231,013
Basic earnings per share
Weighted average shares of common stock outstanding-basic (in shares)									94,798,000	89,242,000	87,689,000
Basic earnings per common share (in dollars per share)	$ 0.34	$ (0.20)	$ 0.78	$ 0.82	$ (0.16)	$ (0.15)	$ 0.83	$ 0.87	$ 1.72	$ 1.39	$ 2.63
Diluted earnings per share
Weighted average shares of common stock outstanding-basic (in shares)									94,798,000	89,242,000	87,689,000
Incremental shares (in shares)									305,000	354,000	626,000
Diluted (in shares)									95,103,000	89,596,000	88,315,000
Diluted earnings per common share (in dollars per share)	$ 0.34	$ (0.20)	$ 0.77	$ 0.82	$ (0.17)	$ (0.15)	$ 0.83	$ 0.87	$ 1.71	$ 1.38	$ 2.62
Anti-dilutive securities excluded from the calculation of diluted earnings per share (in shares)									74,000	0	0

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DEBT - SCHEDULE OF LONG-TERM DEBT (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Debt Instrument [Line Items]
Finance lease liabilities	$ 63,743
Total long-term debt	2,259,466	$ 1,537,177
NJNG
Debt Instrument [Line Items]
Less: Debt issuance costs	(9,195)	(9,027)
Less: Current maturities of long-term debt	(10,416)	(10,420)
Total long-term debt	1,147,393	908,779
NJNG | Finance lease obligation-buildings
Debt Instrument [Line Items]
Finance lease liabilities	47,597	5,637
NJNG | Finance lease obligation-meters
Debt Instrument [Line Items]
Finance lease liabilities	$ 26,562	29,744
NJNG | First mortgage bonds: | Series OO
Debt Instrument [Line Items]
Stated interest rate	3.00%
Long-term debt	$ 46,500	46,500
NJNG | First mortgage bonds: | Series PP
Debt Instrument [Line Items]
Stated interest rate	3.15%
Long-term debt	$ 50,000	50,000
NJNG | First mortgage bonds: | Series QQ
Debt Instrument [Line Items]
Stated interest rate	3.58%
Long-term debt	$ 70,000	70,000
NJNG | First mortgage bonds: | Series RR
Debt Instrument [Line Items]
Stated interest rate	4.61%
Long-term debt	$ 55,000	55,000
NJNG | First mortgage bonds: | Series SS
Debt Instrument [Line Items]
Stated interest rate	2.82%
Long-term debt	$ 50,000	50,000
NJNG | First mortgage bonds: | Series TT
Debt Instrument [Line Items]
Stated interest rate	3.66%
Long-term debt	$ 100,000	100,000
NJNG | First mortgage bonds: | Series UU
Debt Instrument [Line Items]
Stated interest rate	3.63%
Long-term debt	$ 125,000	125,000
NJNG | First mortgage bonds: | Series VV
Debt Instrument [Line Items]
Stated interest rate	4.01%
Long-term debt	$ 125,000	125,000
NJNG | First mortgage bonds: | Series WW
Debt Instrument [Line Items]
Stated interest rate	3.50%
Long-term debt	$ 10,300	10,300
NJNG | First mortgage bonds: | Series XX
Debt Instrument [Line Items]
Stated interest rate	3.38%
Long-term debt	$ 10,500	10,500
NJNG | First mortgage bonds: | Series YY
Debt Instrument [Line Items]
Stated interest rate	2.45%
Long-term debt	$ 15,000	15,000
NJNG | First mortgage bonds: | Series ZZ
Debt Instrument [Line Items]
Stated interest rate	3.76%
Long-term debt	$ 100,000	100,000
NJNG | First mortgage bonds: | Series AAA
Debt Instrument [Line Items]
Stated interest rate	3.86%
Long-term debt	$ 85,000	85,000
NJNG | First mortgage bonds: | Series BBB
Debt Instrument [Line Items]
Stated interest rate	2.75%
Long-term debt	$ 9,545	9,545
NJNG | First mortgage bonds: | Series CCC
Debt Instrument [Line Items]
Stated interest rate	3.00%
Long-term debt	$ 41,000	41,000
NJNG | First mortgage bonds: | Series DDD
Debt Instrument [Line Items]
Stated interest rate	3.13%
Long-term debt	$ 50,000	0
NJNG | First mortgage bonds: | Series EEE
Debt Instrument [Line Items]
Stated interest rate	3.13%
Long-term debt	$ 50,000	0
NJNG | First mortgage bonds: | Series FFF
Debt Instrument [Line Items]
Stated interest rate	3.33%
Long-term debt	$ 25,000	0
NJNG | First mortgage bonds: | Series GGG
Debt Instrument [Line Items]
Stated interest rate	2.87%
Long-term debt	$ 25,000	0
NJNG | First mortgage bonds: | Series HHH
Debt Instrument [Line Items]
Stated interest rate	2.97%
Long-term debt	$ 50,000	0
NJR
Debt Instrument [Line Items]
Less: Debt issuance costs	(3,424)	(2,004)
Less: Current maturities of long-term debt	0	0
Total long-term debt	$ 1,006,576	547,996
NJR | Unsecured senior notes 3.25%
Debt Instrument [Line Items]
Stated interest rate	3.25%
Long-term debt	$ 50,000	50,000
NJR | Unsecured senior notes 3.20%
Debt Instrument [Line Items]
Stated interest rate	3.20%
Long-term debt	$ 50,000	50,000
NJR | Unsecured senior notes 3.48%
Debt Instrument [Line Items]
Stated interest rate	3.48%
Long-term debt	$ 100,000	100,000
NJR | Unsecured senior notes 3.54%
Debt Instrument [Line Items]
Stated interest rate	3.54%
Long-term debt	$ 100,000	100,000
NJR | Unsecured senior notes 3.96%
Debt Instrument [Line Items]
Stated interest rate	3.96%
Long-term debt	$ 100,000	100,000
NJR | Unsecured senior notes 3.29%
Debt Instrument [Line Items]
Stated interest rate	3.29%
Long-term debt	$ 150,000	150,000
NJR | Unsecured senior note 3.60%
Debt Instrument [Line Items]
Stated interest rate	3.60%
Long-term debt	$ 130,000	0
NJR | Unsecured senior note 3.5%
Debt Instrument [Line Items]
Stated interest rate	3.50%
Long-term debt	$ 130,000	0
NJR | Unsecured senior notes 3.25%
Debt Instrument [Line Items]
Long-term debt		0
NJR | Unsecured senior note 3.13%
Debt Instrument [Line Items]
Long-term debt		0
Clean Energy Ventures
Debt Instrument [Line Items]
Long-term debt	122,317	91,401
Less: Current maturities of long-term debt	(16,820)	(10,999)
Total Clean Energy Ventures long-term debt	$ 105,497	$ 80,402

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DEBT - REDEMPTION REQUIREMENTS (Details) $ in Thousands	Sep. 30, 2020 USD ($)
NJR
Debt Instrument [Line Items]
2021	$ 0
2022	50,000
2023	50,000
2024	100,000
2025	0
Thereafter	810,000
NJNG
Debt Instrument [Line Items]
2021	0
2022	0
2023	0
2024	70,000
2025	50,000
Thereafter	$ 972,845

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DEBT - FIRST MORTGAGE BONDS (Details) $ in Thousands	Aug. 01, 2019 USD ($) First_mortgage_bond	Apr. 18, 2019 USD ($) First_mortgage_bond	Sep. 30, 2020 USD ($)	Sep. 01, 2020 USD ($)	Jul. 23, 2020 USD ($)	Jun. 30, 2020 USD ($)	May 14, 2020 USD ($)	Sep. 30, 2019 USD ($)	Jul. 17, 2019 USD ($)
Debt Instrument [Line Items]
NJBPU dividend restriction, equity to capitalization ratio			0.30
Debt to equity ratio			0.531
First mortgage bonds:
Debt Instrument [Line Items]
Maximum amount that can be issued			$ 1,100,000
NJNG
Debt Instrument [Line Items]
Number of first mortgage bonds completed | First_mortgage_bond	3	3
Proceeds from reissuance of first mortgage bond	$ 97,000	$ 35,800
NJNG | First mortgage bonds:
Debt Instrument [Line Items]
Weighted average interest rate		3.02%
NJNG | First mortgage bonds: | Series OO
Debt Instrument [Line Items]
Long-term debt			$ 46,500					$ 46,500
Stated interest rate			3.00%
NJNG | First mortgage bonds: | Series CCC
Debt Instrument [Line Items]
Long-term debt			$ 41,000					41,000
Stated interest rate			3.00%
NJNG | First mortgage bonds: | Series BBB
Debt Instrument [Line Items]
Long-term debt			$ 9,545					$ 9,545
Stated interest rate			2.75%
NJNG | Unsecured Senior Note 3.76%
Debt Instrument [Line Items]
Long-term debt									$ 100,000
Stated interest rate									3.76%
NJNG | Unsecured Senior Note 3.86%
Debt Instrument [Line Items]
Long-term debt									$ 85,000
Stated interest rate									3.86%
NJNG | Senior Notes
Debt Instrument [Line Items]
Note purchase agreement amount				$ 75,000			$ 125,000
NJNG | Senior Notes | Fixed Interest Rate Maturing 2050
Debt Instrument [Line Items]
Stated interest rate				2.87%	3.13%	3.13%	3.13%
Note purchase agreement amount				$ 25,000	$ 50,000	$ 50,000	$ 100,000
NJNG | Senior Notes | Fixed Interest Rate Maturing 2060
Debt Instrument [Line Items]
Stated interest rate				2.97%	3.33%		3.33%
Note purchase agreement amount				$ 50,000	$ 25,000		$ 25,000

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DEBT - SALE-LEASEBACKS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Debt Instrument [Line Items]
Proceeds from sale-leaseback transaction	$ 4,000	$ 9,895	$ 7,820
NJNG
Debt Instrument [Line Items]
Sale leaseback transaction, lease term	16 years
Proceeds from sale leaseback transaction - natural gas meters	$ 4,000
Proceeds from sale-leaseback transaction		9,900	7,800
Sale leaseback transaction, other payments required	$ 1,200	$ 1,100
Sale leaseback transaction, other payments required			$ 2,200

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DEBT - CONTRACTUAL COMMITMENTS (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Finance Leases
2021	$ 54,992
2022	6,004
2023	4,622
2024	5,279
2025	3,396
Thereafter	2,324
Total future lease payments	76,617
Less: Interest component	(2,458)
Total lease liability	74,159	$ 35,400
NJR
Finance Leases
2021	54,992
2022	6,004
2023	4,622
2024	5,279
2025	3,396
Thereafter	2,324
Total future lease payments	76,617
Less: Interest component	(2,458)
Total lease liability	74,159
Clean Energy Ventures
Sale Leaseback Transaction, Net Book Value [Abstract]
2021	12,928
2022	12,926
2023	13,003
2024	12,904
2025	8,985
Thereafter	47,268
Subtotal	108,014
Less: Interest component	(23,052)
Total	$ 84,962

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DEBT - NJR LONG-TERM DEBT (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 01, 2020	May 14, 2020	Aug. 15, 2019	Jul. 17, 2019	Jan. 26, 2018
Debt Instrument [Line Items]
Proceeds from sale leaseback transaction - solar	$ 42,927	$ 0	$ 71,538
Clean Energy Ventures
Debt Instrument [Line Items]
Proceeds from sale leaseback transaction - solar	$ 42,900
Interest rate swap | Credit Agreement Due August 16, 2019 | Unsecured senior notes
Debt Instrument [Line Items]
Long-term debt								$ 100,000
Fixed treasury rate								2.84%
NJR | Senior Notes
Debt Instrument [Line Items]
Note purchase agreement amount				$ 200,000	$ 260,000
NJR | Unsecured senior notes 3.29% | Senior Notes
Debt Instrument [Line Items]
Note purchase agreement amount							$ 150,000
Stated interest rate							3.29%
Long-term debt						$ 100,000	$ 50,000
NJR | Fixed Interest Rate Maturing 2030 | Senior Notes
Debt Instrument [Line Items]
Note purchase agreement amount					$ 130,000
Stated interest rate					3.50%
NJR | Fixed Interest Rate Maturing 2032 | Senior Notes
Debt Instrument [Line Items]
Note purchase agreement amount					$ 130,000
Stated interest rate					3.60%
NJR | Unsecured senior note 3.13% | Senior Notes
Debt Instrument [Line Items]
Stated interest rate	3.13%			3.13%
Long-term debt	$ 120,000			$ 120,000
NJR | Unsecured senior notes 3.25% | Senior Notes
Debt Instrument [Line Items]
Stated interest rate	3.25%			3.25%
Long-term debt	$ 80,000			$ 80,000
Minimum | Clean Energy Ventures
Debt Instrument [Line Items]
Term of lease	5 years
Maximum | Clean Energy Ventures
Debt Instrument [Line Items]
Term of lease	15 years

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DEBT - SHORT-TERM BANK FACILITIES (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Apr. 24, 2020	Dec. 13, 2019	Sep. 30, 2019	Dec. 05, 2018	Jun. 25, 2018
NJR | Letters of Credit on Behalf of NJRES
Short-term Debt [Line Items]
Letters of credit outstanding, amount	$ 10,300,000			$ 4,800,000
NJR | Bank revolving credit facilities
Short-term Debt [Line Items]
Commitment fee percentage	0.075%
NJNG | Letters of credit
Short-term Debt [Line Items]
Letters of credit outstanding, amount	$ 731,000			731,000
NJNG | Committed Credit Facilities Due December 2023
Short-term Debt [Line Items]
Outstanding at end of period	$ 0
NJNG | Bank revolving credit facilities
Short-term Debt [Line Items]
Commitment fee percentage	0.075%
Bank revolving credit facilities | NJR
Short-term Debt [Line Items]
Bank revolving credit facilities		$ 250,000,000			$ 425,000,000	$ 425,000,000
Bank revolving credit facilities | NJR | Committed Credit Facilities Due December 2023
Short-term Debt [Line Items]
Bank revolving credit facilities	$ 425,000,000			425,000,000
Outstanding at end of period	$ 125,350,000			$ 25,450,000
Weighted average interest rate at end of period	1.49%			3.04%
Amount available at end of period	$ 289,356,000			$ 394,800,000
Bank revolving credit facilities | NJR | Credit Facilities Due April 2021
Short-term Debt [Line Items]
Bank revolving credit facilities	250,000,000		$ 150,000,000	0
Outstanding at end of period	$ 0			$ 0
Weighted average interest rate at end of period	0.00%			0.00%
Amount available at end of period	$ 250,000,000			$ 0
Bank revolving credit facilities | NJNG | Committed Credit Facilities Due December 2023
Short-term Debt [Line Items]
Bank revolving credit facilities	$ 250,000,000			250,000,000
Outstanding at end of period				$ 0
Weighted average interest rate at end of period	0.00%			0.00%
Amount available at end of period	$ 249,269,000			$ 249,269,000

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DEBT - NJR SHORT-TERM DEBT (Details)	Apr. 24, 2020 USD ($)	Oct. 09, 2019 USD ($)	Dec. 05, 2018 USD ($)	Dec. 05, 2018 USD ($) Mutual_option	Dec. 05, 2018 USD ($) lease	Oct. 24, 2020 USD ($)	Sep. 30, 2020 USD ($) debt_instrument	Dec. 13, 2019 USD ($)	Sep. 30, 2019 USD ($)	Jun. 25, 2018 USD ($)
Short-term Debt [Line Items]
Short-term debt							$ 125,350,000		$ 25,450,000
Bridge Loan
Short-term Debt [Line Items]
Note purchase agreement amount		$ 350,000,000
Bridge Loan | Debt Instrument, Interest Rate, First 180 Days
Short-term Debt [Line Items]
Basis spread on variable rate		0.875%
Bridge Loan | Debt Instrument, Interest Rate, After 180 Days
Short-term Debt [Line Items]
Basis spread on variable rate		1.075%
NJR | Letters of Credit on Behalf of NJRES
Short-term Debt [Line Items]
Number of debt instruments (in debt instruments) | debt_instrument							7
Letters of credit outstanding, amount							$ 10,300,000		4,800,000
NJR | Bank revolving credit facilities
Short-term Debt [Line Items]
Debt instrument, term	364 days
Line of credit facility, maximum borrowing capacity	$ 250,000,000		$ 425,000,000	$ 425,000,000	$ 425,000,000					$ 425,000,000
Number of mutual options				2	2
Number of mutual options, extension period			1 year
Line of credit facility, maximum borrowing capacity, incremental increase			$ 50,000,000	$ 50,000,000	$ 50,000,000
Line of credit facility, maximum borrowing capacity, maximum increase			$ 250,000,000	$ 250,000,000	$ 250,000,000
NJR | Credit Facilities Due April 2021 | Bank revolving credit facilities
Short-term Debt [Line Items]
Line of credit facility, maximum borrowing capacity							$ 250,000,000	$ 150,000,000	$ 0
NJR | Credit Facilities Due April 2021 | Bank revolving credit facilities | Subsequent Event
Short-term Debt [Line Items]
Short-term debt						$ 0

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DEBT - NJNG SHORT-TERM DEBT (Details) - NJNG	Dec. 05, 2018 USD ($)	Sep. 30, 2020 USD ($) debt_instrument	Sep. 30, 2019 USD ($)
Letters of credit
Line of Credit Facility [Line Items]
Number of debt instruments (in debt instruments) | debt_instrument		2
Letters of credit outstanding, amount		$ 731,000	$ 731,000
Bank revolving credit facilities
Line of Credit Facility [Line Items]
Number of mutual options, extension period	1 year
Line of credit facility, maximum borrowing capacity, incremental increase	$ 50,000,000
Line of credit facility, maximum borrowing capacity, maximum increase	100,000,000
Committed Credit Facilities Due May 2019 | Bank revolving credit facilities
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	$ 250,000,000

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STOCK-BASED COMPENSATION - NARRATIVE (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for future issuance (in shares)	3,189,550
Performance Shares, Market Condition Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)	33,123	36,392	31,836
Performance Shares, Subject to Performance Conditions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)	48,941	63,870	59,341
Deferred compensation related to unvested performance shares, period	1 year 8 months 12 days
Performance share awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)	155,731	130,509	145,176	156,587
Deferred compensation related to unvested restricted and performance shares	$ 2,400
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)	73,486	58,156	44,168	51,154
Deferred compensation related to unvested restricted and performance shares	$ 1,000
Deferred compensation related to unvested performance shares, period	1 year 9 months 18 days
Vesting September 30, 2022 | Performance Shares, Subject to Performance Conditions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)	30,473
Vesting Annually Over Three Year Period Beginning September 2020 | Performance Shares, Subject to Performance Conditions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)	18,468
Award vesting period	3 years
Vesting September 30, 2021 | Performance Shares, Subject to Performance Conditions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)		33,844
Vesting Annually Over Three Year Period Beginning September 30, 2019 | Performance Shares, Subject to Performance Conditions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)		30,026
Award vesting period		3 years
Vesting September 30, 2020 | Performance Shares, Subject to Performance Conditions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)			29,608
Vesting Annually Over Three Year Period Beginning September 30, 2018 | Performance Shares, Subject to Performance Conditions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)			29,733
Award vesting period			3 years
Vesting Annually Over Three Year Period Beginning October 2020 | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)	42,478
Award vesting period	3 years
Vesting Annually Over Three Year Period Beginning October 2019 | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)		29,222
Award vesting period		3 years
Vesting Annually Over Three Year Period Beginning April 2020 | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)		6,062
Award vesting period		3 years
Vesting Annually Over Three Year Period Beginning October 2018 | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted but not issued (in shares)			27,949
Award vesting period			3 years

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STOCK-BASED COMPENSATION - STOCK-BASED COMPENSATION EXPENSE (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense included in operation and maintenance expense	$ 6,536	$ 9,796	$ 12,845
Income tax benefit	(1,900)	(2,848)	(3,734)
Total, net of tax	4,636	6,948	9,111
Tax benefit of delivered shares from stock based compensation	647	1,290	2,950
Performance share awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense included in operation and maintenance expense	1,943	5,804	3,526
Restricted and non-restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense included in operation and maintenance expense	2,868	2,492	2,191
Deferred retention stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense included in operation and maintenance expense	$ 1,725	$ 1,500	$ 7,128

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STOCK-BASED COMPENSATION - PERFORMANCE SHARES AND RESTRICTED STOCK ACTIVITY (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Nov. 09, 2020	Nov. 12, 2019	Nov. 13, 2018
Performance share awards
Shares
Outstanding at beginning of period (in shares)	130,509	145,176	156,587
Granted (in shares)	82,064	100,262	91,177
Vested (in shares)	(55,025)	(103,009)	(100,146)
Cancelled/forfeited (in shares)	(1,817)	(11,920)	(2,442)
Outstanding at end of period (in shares)	155,731	130,509	145,176
Weighted Average Grant Date Fair Value
Outstanding at beginning of period (in dollars per share)	$ 46.53	$ 39.67	$ 30.12
Granted (in dollars per share)	40.61	47.98	44.67
Vested (in dollars per share)	44.27	38.52	29.49
Cancelled/forfeited (in dollars per share)	44.38	44.34	31.45
Outstanding at end of period (in dollars per share)	$ 44.22	$ 46.53	$ 39.67
Total Fair Value of Vested Shares	$ 2,083	$ 4,622	$ 4,714
Percent of awards to common stock					117.00%	121.00%
Number of common shared issued (in shares)					26,413	39,694
Percent of awards to common stock, target					100.00%	100.00%
Performance share awards | Minimum
Weighted Average Grant Date Fair Value
Percent of awards to common stock	0.00%
Performance share awards | Maximum
Weighted Average Grant Date Fair Value
Percent of awards to common stock	150.00%
Performance Shares, Subject to Performance Conditions
Shares
Outstanding at beginning of period (in shares)	63,870	59,341
Outstanding at end of period (in shares)	48,941	63,870	59,341
Weighted Average Grant Date Fair Value
Percent of awards to common stock						99.00%
Number of common shared issued (in shares)						38,660
Performance-based Restricted Stock
Weighted Average Grant Date Fair Value
Percent of awards to common stock					100.00%	100.00%
Number of common shared issued (in shares)					24,468	36,998
Performance Shares, TSR
Weighted Average Grant Date Fair Value
Percent of awards to common stock					119.00%
Number of common shared issued (in shares)					43,641
Restricted Stock
Shares
Outstanding at beginning of period (in shares)	58,156	44,168	51,154
Granted (in shares)	42,478	35,284	27,949
Vested (in shares)	(25,973)	(20,748)	(33,815)
Cancelled/forfeited (in shares)	(1,175)	(548)	(1,120)
Outstanding at end of period (in shares)	73,486	58,156	44,168
Weighted Average Grant Date Fair Value
Outstanding at beginning of period (in dollars per share)	$ 46.18	$ 41.24	$ 32.40
Granted (in dollars per share)	40.61	48.24	45.00
Vested (in dollars per share)	44.71	39.26	31.23
Cancelled/forfeited (in dollars per share)	43.62	42.96	33.54
Outstanding at end of period (in dollars per share)	$ 43.52	$ 46.18	$ 41.24
Total Fair Value of Vested Shares	$ 1,073	$ 935	$ 1,438
Subsequent Event | Performance share awards
Weighted Average Grant Date Fair Value
Percent of awards to common stock				114.00%
Number of common shared issued (in shares)				28,513
Percent of awards to common stock, target				100.00%
Subsequent Event | Performance-based Restricted Stock
Weighted Average Grant Date Fair Value
Percent of awards to common stock				100.00%
Number of common shared issued (in shares)				11,139
Subsequent Event | Performance Shares, TSR
Weighted Average Grant Date Fair Value
Number of common shared issued (in shares)				0

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STOCK-BASED COMPENSATION - DEFERRED RETENTION STOCK/NON-EMPLOYEE DIRECTOR STOCK (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Scheduled to Vest Immediately | Director
Shares
Number of shares granted (in shares)	27,696	26,165	26,524
Weighted Average Grant Date Fair Value
Granted (in dollars per share)	$ 42.88	$ 44.80	$ 39.85
Total Fair Value of Vested Shares
Compensation costs not yet recognized	$ 311
Deferred retention stock
Shares
Outstanding at beginning of period (in shares)	243,561	242,082	672,578
Number of shares granted (in shares)	42,358	167,407	24,167
Delivered (in shares)	(57,673)	(158,733)	(452,694)
Forfeited (in shares)		(7,195)	(1,969)
Outstanding at end of period (in shares)	228,246	243,561	242,082
Weighted Average Grant Date Fair Value
Outstanding at beginning of period (in dollars per share)	$ 44.67	$ 32.99	$ 29.54
Granted/Vested (in dollars per share)	40.72	47.95	45.00
Delivered (in dollars per share)	35.25	30.32	29.42
Forfeited (in dollars per share)		44.41	35.56
Outstanding at end of period (in dollars per share)	$ 46.32	$ 44.67	$ 32.99
Total Fair Value of Vested Shares
Delivered	$ 2,423	$ 7,145	$ 19,581

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EMPLOYEE BENEFIT PLANS - PENSION AND OTHER POSTEMPLOYMENT BENEFIT PLANS, NARRATIVE (Details)	12 Months Ended
	Sep. 30, 2020 USD ($) plan	Sep. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Number of noncontributory defined benefit retirement plans (in plans) | plan	2
Required number of years of service (more than)	1 year
Years of service and average compensation, basis period for plan benefits	60 months
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer discretionary contributions	$ 0	$ 0	$ 0
Employer contributions	596,000	231,000
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer contributions	8,400,000	$ 7,926,000	6,200,000
OPEB | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Estimated future employer contributions over the next five years	5,000,000
OPEB | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Estimated future employer contributions over the next five years	$ 10,000,000
Special Termination Benefits | Voluntary Early Retirement Program
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and other postretirement benefits cost			4,200,000
Other Severance Benefits | Voluntary Early Retirement Program
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and other postretirement benefits cost			2,200,000
Home Services and Other | Voluntary Early Retirement Program
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and other postretirement benefits cost			1,300,000
NJNG | Voluntary Early Retirement Program
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and other postretirement benefits cost			$ 5,100,000

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EMPLOYEE BENEFIT PLANS - SUMMARY OF CHANGE IN FUNDED STATUS AND LIABILITIES (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Postemployment employee (liability)
Noncurrent	$ (237,221)	$ (246,517)
Pension
Change in Benefit Obligation
Benefit obligation at beginning of year	360,477	298,575
Service cost	8,223	7,381	$ 8,139
Interest cost	10,587	12,173	10,493
Plan participants’ contributions	25	43
Actuarial loss (gain)	29,738	52,549
Benefits paid, net of retiree subsidies received	(11,886)	(10,244)
Benefit obligation at end of year	397,164	360,477	298,575
Change in plan assets
Fair value of plan assets at beginning of year	288,634	279,410
Actual return on plan assets	30,632	19,194
Employer contributions	596	231
Benefits paid, net of plan participants’ contributions	(11,894)	(10,201)
Fair value of plan assets at end of year	307,968	288,634	279,410
Funded status	(89,196)	(71,843)
Postemployment employee (liability)
Current	(531)	(603)
Noncurrent	(88,665)	(71,240)
Total	(89,196)	(71,843)
OPEB
Change in Benefit Obligation
Benefit obligation at beginning of year	260,003	196,785
Service cost	4,854	4,404	4,607
Interest cost	7,026	8,324	6,365
Plan participants’ contributions		210
Actuarial loss (gain)		54,700
Benefits paid, net of retiree subsidies received		(4,420)
Benefit obligation at end of year		260,003	196,785
Change in plan assets
Fair value of plan assets at beginning of year	83,926	77,980
Actual return on plan assets		2,499
Employer contributions	8,400	7,926	6,200
Benefits paid, net of plan participants’ contributions		(4,479)
Fair value of plan assets at end of year	96,406	83,926	$ 77,980
Funded status		(176,077)
Postemployment employee (liability)
Current	(900)	(800)
Noncurrent	(148,556)	(175,277)
Total	(149,456)	(176,077)
OPEB | Affordable Care Act, Cadillac Tax Repeal
Change in Benefit Obligation
Benefit obligation at beginning of year	260,003
Service cost	4,854
Interest cost	7,026
Plan participants’ contributions	194
Actuarial loss (gain)	(23,226)
Benefits paid, net of retiree subsidies received	(2,989)
Benefit obligation at end of year	245,862	260,003
Change in plan assets
Fair value of plan assets at beginning of year	83,925
Actual return on plan assets	6,872
Employer contributions	8,436
Benefits paid, net of plan participants’ contributions	(2,827)
Fair value of plan assets at end of year	96,406	$ 83,925
Funded status	$ (149,456)

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EMPLOYEE BENEFIT PLANS - REGULATORY ASSETS AND AOCI (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Pension
Amounts amortized to net periodic costs:
Net actuarial (loss)	$ (10,424)	$ (5,765)	$ (7,537)
Prior service credit	(102)	(102)	(106)
OPEB
Amounts amortized to net periodic costs:
Net actuarial (loss)	(7,442)	(6,466)	(4,660)
Prior service credit	197	365	365
Regulatory Assets | Pension
Regulatory Assets and Accumulated Other Comprehensive Income (Loss)
Regulatory Assets, Balance at beginning of period	99,606	66,233
Amounts arising during the period, Net actuarial loss (gain)	11,953	38,137
Amounts amortized to net periodic costs:
Net actuarial (loss)	(7,893)	(4,662)
Prior service credit	(102)	(102)
Regulatory Assets, Balance at end of period	103,564	99,606	66,233
Regulatory Assets | OPEB
Regulatory Assets and Accumulated Other Comprehensive Income (Loss)
Regulatory Assets, Balance at beginning of period	111,629	68,685
Amounts arising during the period, Net actuarial loss (gain)	(21,974)	48,452
Amounts amortized to net periodic costs:
Net actuarial (loss)	(6,536)	(5,820)
Prior service credit	182	312
Regulatory Assets, Balance at end of period	83,301	111,629	68,685
Accumulated Other Comprehensive Income (Loss) | Pension
Regulatory Assets and Accumulated Other Comprehensive Income (Loss)
Accumulated Other Comprehensive Income (Loss), Balance at beginning of period	27,801	14,633
Amounts arising during the period, Net actuarial loss (gain)	7,731	14,271
Amounts amortized to net periodic costs:
Net actuarial (loss)	(2,528)	(1,103)
Prior service credit	0	0
Accumulated Other Comprehensive Income (Loss), Balance at end of period	33,004	27,801	14,633
Accumulated Other Comprehensive Income (Loss) | OPEB
Regulatory Assets and Accumulated Other Comprehensive Income (Loss)
Accumulated Other Comprehensive Income (Loss), Balance at beginning of period	16,328	7,659
Amounts arising during the period, Net actuarial loss (gain)	(1,614)	9,264
Amounts amortized to net periodic costs:
Net actuarial (loss)	(907)	(648)
Prior service credit	16	53
Accumulated Other Comprehensive Income (Loss), Balance at end of period	$ 13,823	$ 16,328	$ 7,659

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EMPLOYEE BENEFIT PLANS - AMOUNTS NOT YET RECOGNIZED AS NET PERIODIC COST (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Regulatory Assets | Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net actuarial loss	$ 103,197	$ 99,139
Prior service cost (credit)	367	467
Regulatory Assets, Total	103,564	99,606	$ 66,233
Regulatory Assets | OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net actuarial loss	83,600	112,109
Prior service cost (credit)	(299)	(480)
Regulatory Assets, Total	83,301	111,629	68,685
Accumulated Other Comprehensive Income (Loss) | Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net actuarial loss	33,004	27,801
Prior service cost (credit)	0	0
Accumulated Other Comprehensive Income (Loss), Total	33,004	27,801	14,633
Accumulated Other Comprehensive Income (Loss) | OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net actuarial loss	13,847	16,367
Prior service cost (credit)	(24)	(39)
Accumulated Other Comprehensive Income (Loss), Total	$ 13,823	$ 16,328	$ 7,659

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EMPLOYEE BENEFIT PLANS - AMOUNTS EXPECTED TO BE RECOGNIZED IN NET PERIODIC BENEFIT COST (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Pension
Regulatory Assets
Net actuarial loss	$ 8,269
Prior service cost (credit)	102
Total	8,371
Accumulated Other Comprehensive Income (Loss)
Net actuarial loss	3,178
Prior service cost (credit)	0
Total	3,178
OPEB
Regulatory Assets
Net actuarial loss	6,846
Prior service cost (credit)	(166)
Total	6,680
Accumulated Other Comprehensive Income (Loss)
Net actuarial loss	1,064
Prior service cost (credit)	(13)
Total	$ 1,051

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EMPLOYEE BENEFIT PLANS - ACCUMULATED BENEFIT OBLIGATION (Details) - Pension - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 397,164	$ 360,477
Accumulated benefit obligation	352,320	319,527
Fair value of plan assets	$ 307,968	$ 288,634

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EMPLOYEE BENEFIT PLANS - COMPONENTS OF NET PERIODIC COST (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	$ 8,223	$ 7,381	$ 8,139
Interest cost	10,587	12,173	10,493
Expected return on plan assets	(20,579)	(19,054)	(19,639)
Recognized actuarial loss	10,424	5,765	7,537
Prior service cost (credit) amortization	102	102	106
Net periodic benefit cost	8,757	6,367	6,636
Special termination benefit	0	0	3,730
Net periodic benefit cost recognized as expense	8,757	6,367	10,366
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	4,854	4,404	4,607
Interest cost	7,026	8,324	6,365
Expected return on plan assets	(6,510)	(5,515)	(5,352)
Recognized actuarial loss	7,442	6,466	4,660
Prior service cost (credit) amortization	(197)	(365)	(365)
Net periodic benefit cost	12,615	13,314	9,915
Special termination benefit	0	0	490
Net periodic benefit cost recognized as expense	$ 12,615	$ 13,314	$ 10,405

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EMPLOYEE BENEFIT PLANS - WEIGHTED AVERAGE ASSUMPTIONS (Details)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Represented
Obligations:
Compensation increase		3.00%	3.25%
Nonrepresented
Obligations:
Compensation increase		3.50%	3.50%
Pension
Benefit costs:
Expected asset return	7.25%	7.00%	7.50%
Pension | Represented
Benefit costs:
Discount rate	3.37%	4.36%	4.04%
Compensation increase	3.00%	3.25%	3.25%
Obligations:
Discount rate	2.95%	3.37%	4.36%
Compensation increase	3.00%	3.00%	3.25%
Pension | Nonrepresented
Benefit costs:
Discount rate	3.35%	4.35%	4.03%
Compensation increase	3.50%	3.50%	3.50%
Obligations:
Discount rate	2.92%	3.35%	4.35%
Compensation increase	3.50%	3.50%	3.50%
OPEB
Benefit costs:
Expected asset return	7.25%	7.00%	7.50%
OPEB | Represented
Benefit costs:
Discount rate	3.48%	4.38%	4.12%
Compensation increase	3.00%	3.25%	3.25%
Obligations:
Discount rate	3.08%	3.48%	4.38%
Compensation increase	3.00%
OPEB | Nonrepresented
Benefit costs:
Discount rate	3.44%	4.37%	4.08%
Compensation increase	3.50%	3.50%	3.50%
Obligations:
Discount rate	3.03%	3.44%	4.37%
Compensation increase	3.50%

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EMPLOYEE BENEFIT PLANS - ASSUMED HCCTR (Details) - OPEB - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
HCCTR	7.60%	7.60%	7.90%
Ultimate HCCTR	4.50%	4.50%	4.50%
Effect of a 1 percentage point increase in the HCCTR on:
Year-end benefit obligation	$ 49,106	$ 49,061	$ 36,260
Total service and interest cost	2,799	2,923	2,482
Effect of a 1 percentage point decrease in the HCCTR on:
Year-end benefit obligation	(38,844)	(38,747)	(28,743)
Total service and interest costs	$ (2,151)	$ (2,250)	$ (1,937)

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EMPLOYEE BENEFIT PLANS - MIX AND TARGETED ALLOCATION (Details)	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	100.00%
Assets	100.00%	100.00%
U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	34.00%
Assets	38.00%	37.00%
International equity securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	17.00%
Assets	18.00%	17.00%
Fixed income
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	38.00%
Assets	39.00%	42.00%
Other assets
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	11.00%
Assets	5.00%	4.00%

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EMPLOYEE BENEFIT PLANS - EXPECTED BENEFIT PAYMENTS (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Pension
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
2021	$ 12,799
2022	13,765
2023	14,512
2024	15,345
2025	16,267
2026 - 2030	95,969
OPEB
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
2021	6,179
2022	6,837
2023	7,420
2024	7,988
2025	8,625
2026 - 2030	$ 52,480

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EMPLOYEE BENEFIT PLANS - ESTIMATED SUBSIDY PAYMENTS (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Defined Benefit Plan, Expected Future Prescription Drug Subsidy Receipt [Abstract]
2021	$ 292
2022	316
2023	349
2024	384
2025	420
2026 - 2030	$ 2,789

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EMPLOYEE BENEFIT PLANS - FAIR VALUE (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Pension
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	$ 307,968	$ 288,634	$ 279,410
OPEB
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	96,406	83,926	$ 77,980
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	292,886	276,014
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Money market funds
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Large Cap Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	95,542	89,374
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Extended Market Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	21,085	16,548
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | International Stock
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	56,912	49,929
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Emerging Markets
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	16,008	15,794
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Core Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Opportunistic Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Ultra Short Duration
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | High Yield Bond Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	26,303	24,328
Quoted Prices in Active Markets for Identical Assets (Level 1) | Pension | Long Duration Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	77,036	80,041
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	92,295	80,484
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Money market funds
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	15	21
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Large Cap Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	29,908	25,474
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Extended Market Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	6,470	5,036
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | International Stock
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	17,390	14,564
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Emerging Markets
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	4,958	4,764
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Core Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	11,146	10,570
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Opportunistic Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	7,128	6,365
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Ultra Short Duration
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	7,057	6,340
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | High Yield Bond Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	8,223	7,350
Quoted Prices in Active Markets for Identical Assets (Level 1) | OPEB | Long Duration Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Fair Value, Inputs, Level 1, 2 and 3 | Pension
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	292,886	276,014
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Money market funds
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Large Cap Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	95,542	89,374
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Extended Market Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	21,085	16,548
Fair Value, Inputs, Level 1, 2 and 3 | Pension | International Stock
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	56,912	49,929
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Emerging Markets
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	16,008	15,794
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Core Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Opportunistic Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Ultra Short Duration
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Fair Value, Inputs, Level 1, 2 and 3 | Pension | High Yield Bond Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	26,303	24,328
Fair Value, Inputs, Level 1, 2 and 3 | Pension | Long Duration Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	77,036	80,041
Fair Value, Inputs, Level 1, 2 and 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	92,295	80,484
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Money market funds
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	15	21
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Large Cap Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	29,908	25,474
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Extended Market Index
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	6,470	5,036
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | International Stock
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	17,390	14,564
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Emerging Markets
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	4,958	4,764
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Core Fixed Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	11,146	10,570
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Opportunistic Income
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	7,128	6,365
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Ultra Short Duration
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	7,057	6,340
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | High Yield Bond Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	8,223	7,350
Fair Value, Inputs, Level 1, 2 and 3 | OPEB | Long Duration Fund
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	0	0
Investments measured at net asset value | Pension | Common collective trusts
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	15,082	12,620
Investments measured at net asset value | OPEB | Common collective trusts
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of plan assets	$ 4,111	$ 3,442

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EMPLOYEE BENEFIT PLANS - DEFINED CONTRIBUTION (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Defined contribution, company match of employee contribution	80.00%
Defined contribution plan, maximum employer contribution by percentage of employee salary	6.00%
Defined contribution plan, cost recognized	$ 4,500	$ 3,900	$ 3,900
Deferred compensation arrangement with individual, employer contribution	$ 1,600	$ 1,300	$ 959
NJRHS | Minimum
Defined Benefit Plan Disclosure [Line Items]
Defined contribution plan, employer contribution for employees not qualifying for the defined benefit plan	3.50%
NJRHS | Maximum
Defined Benefit Plan Disclosure [Line Items]
Defined contribution plan, employer contribution for employees not qualifying for the defined benefit plan	4.50%

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ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Estimated Accretion
2021	$ 1,717
2022	1,789
2023	1,869
2024	1,948
2025	2,029
Total	9,352
NJNG
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at period beginning	26,944	$ 25,640
Accretion	1,476	1,427
Additions	0	135
Change in estimated useful life	0	0
Change in assumptions	1,104	0
Retirements	(244)	(258)
Other	0	0
Balance at period end	29,280	26,944
Clean Energy Ventures
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at period beginning	4,102	3,048
Accretion	196	150
Additions	1,306	904
Change in estimated useful life	(1,160)	0
Change in assumptions	0	0
Retirements	0	0
Other	0	0
Balance at period end	$ 4,444	$ 4,102

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INCOME TAXES - COMPONENTS OF INCOME TAX PROVISION (BENEFIT) (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Current:
Federal	$ (2,164)	$ 10,933	$ (2,848)
State	6,763	3,530	4,563
Deferred:
Federal	28,817	4,103	(40,138)
State	3,400	4,003	7,181
Investment/production tax credits	(322)	(4,129)	(10,990)
Income tax expense (benefit)	$ 36,494	$ 18,440	$ (42,232)

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INCOME TAXES - DEFERRED TAX ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Deferred tax assets
Investment tax credits	$ 194,840	$ 156,153
Federal net operating losses	24,091	24,173
State net operating losses	33,233	25,302
Fair value of derivatives	13,979	9,673
Postemployment benefits	8,544	9,192
Incentive compensation	7,071	7,231
Amortization of intangibles	5,892	4,991
Overrecovered natural gas costs	7,244	0
Other	2,370	7,139
Total deferred tax assets	297,264	243,854
Less: Valuation allowance	(17,639)	(4,035)
Total deferred tax assets net of valuation allowance	279,625	239,819
Deferred tax liabilities
Property related items	(359,604)	(313,246)
Remediation costs	(10,207)	(10,720)
Investments in equity investees	(23,395)	(21,730)
Underrecovered natural gas costs	0	(2,657)
Conservation incentive plan	(5,345)	(942)
Other	(6,639)	(4,776)
Total deferred tax liabilities	(405,190)	(354,071)
Total net deferred tax liabilities	(125,565)	(114,252)
Tax credit carryforward	195,200	154,200
NJNG
Deferred tax liabilities
Tax credit carryforward	$ 898	$ 2,000

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INCOME TAXES - INCOME TAX RECONCILIATION (Details) - USD ($) $ in Thousands		3 Months Ended	12 Months Ended
	Jan. 01, 2018	Dec. 31, 2017	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Statutory income tax expense			$ 41,896	$ 29,898	$ 45,961
Change resulting from:
Investment/production tax credits			(322)	(4,129)	(10,990)
Cost of removal of assets placed in service prior to 1981			(5,362)	(6,349)	(5,829)
AFUDC equity			(4,933)	(2,313)	(2,117)
State income taxes, net of federal benefit			11,965	6,262	7,322
NJ Unitary method change			(15,345)	0	0
Valuation allowance			13,604	0	0
Tax Act - utility excess deferred income taxes amortized			(3,573)	(3,573)	(1,786)
Tax Act - nonutility excess deferred income taxes			0	0	(59,627)
Tax Act - utility excess deferred income taxes refunded to customers			0	0	(14,323)
Other			(1,436)	(1,356)	(843)
Income tax expense (benefit)			$ 36,494	$ 18,440	$ (42,232)
Effective income tax rate			18.30%	14.00%	(23.90%)
Federal statutory rate	21.00%	35.00%	21.00%	21.00%	24.50%
Effective income tax rate without the impact of the Tax Act					12.40%

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INCOME TAXES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Thousands			3 Months Ended	12 Months Ended
	May 22, 2018	Jan. 01, 2018	Dec. 31, 2017	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2024	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	May 31, 2019
Income Tax Contingency [Line Items]
Investment tax credit, solar property, percentage										30.00%	30.00%
Deferred employer portion of OASDI				$ 3,100
Deferred tax assets, operating loss carryforwards, domestic, refundable and receivables				22,800	$ 22,800
Federal net operating losses				24,091	24,173
Tax credit carryforward				$ 195,200	154,200
Net operating losses, life				20 years
Valuation allowance				$ 17,600	$ 4,000
Federal statutory rate		21.00%	35.00%	21.00%	21.00%	24.50%
Tax cuts and jobs act, income tax expense (benefit)					$ (59,600)
Change in tax rate, deferred tax liability, provisional income tax (expense) benefit						$ 228,400
Change in tax rate, deferred income taxes						164,300
Change in tax rate, provisional income tax expense (benefit)						64,100
Initial revaluation of excess deferred income taxes	$ 20,100
Overcollection of taxes	9,000
Deferred income tax expense (benefit), remeasurement						14,300
Amortization of excess deferred income taxes						1,800
Revaluation of deferred income taxes not included in base rates						880
Regulatory liability, excess deferred income taxes				$ 195,000
March 2018 BGSS/CIP Filing
Income Tax Contingency [Line Items]
Approved customer refunds	$ 31,000
Forecast
Income Tax Contingency [Line Items]
Investment tax credit, solar property, percentage							10.00%	22.00%	26.00%
Clean Energy Ventures
Income Tax Contingency [Line Items]
Federal net operating losses				24,100
Natural Gas Distribution
Income Tax Contingency [Line Items]
Tax credit carryforward				898	2,000
Income tax expense (benefit) provision						$ 17,000
Domestic Tax Authority
Income Tax Contingency [Line Items]
Net operating losses				134,000	134,000
State and Local Jurisdiction
Income Tax Contingency [Line Items]
Net operating losses				$ 487,700	$ 340,000
State and Local Jurisdiction | Minimum
Income Tax Contingency [Line Items]
Net operating losses, life				7 years
State and Local Jurisdiction | Maximum
Income Tax Contingency [Line Items]
Net operating losses, life				20 years

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INCOME TAXES - RESERVE FOR UNCERTAIN TAX BENEFITS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at October 1,	$ 4,930	$ 0
Additions based on tax positions related to the current fiscal period	0	4,930
Balance at period end	$ 4,930	$ 4,930

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LEASES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Thousands		12 Months Ended
	Aug. 14, 2020	Sep. 30, 2020
Lessee, Lease, Description [Line Items]
ROU asset obtained in exchange for operating lease liability		$ 76,600
ROU asset obtained in exchange for finance lease liability		$ 49,700
Weighted average remaining lease term, operating lease		25 years 6 months
Weighted average remaining lease term, finance lease		11 years 6 months
Operating lease, discount rate		3.18%
Finance lease, discount rate		2.50%
Leaf River Energy Center LLC
Lessee, Lease, Description [Line Items]
Lease, partial termination amount	$ 28,500
Non-compete agreement period	50 years
Solar Property | Maximum
Lessee, Lease, Description [Line Items]
Term of contract		35 years

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LEASES - LEASE COST (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Leases [Abstract]
Amortization of right-of-use assets	$ 5,007
Interest on lease liabilities	1,511
Total finance lease cost	6,518
Operating lease cost	6,404
Short-term lease cost	1,041
Variable lease cost	1,025
Total lease cost	$ 14,988

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LEASES - SUPPLEMENTAL CASH FLOW INFORMATION (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Leases [Abstract]
Operating cash flows from operating leases	$ 8,804
Operating cash flows from finance leases	1,189
Financing cash flows from finance leases	$ 6,985

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LEASES - RIGHT-OF-USE ASSETS AND LEASE LIABILITIES (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
NONCURRENT ASSETS
Operating lease assets	$ 131,769	$ 0
Finance lease assets	$ 71,085
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Utility plant, at cost
Total lease assets	$ 202,854
CURRENT LIABILITIES
Operating lease liabilities	6,724	0
Finance lease liabilities	$ 10,416
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	Current maturities of long-term debt
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Long-term debt
NONCURRENT LIABILITIES
Operating lease liabilities	$ 95,030	$ 0
Finance lease liabilities	63,743
Total lease liabilities	$ 175,913

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LEASES - MATURITIES OF LEASE LIABILITIES (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Operating Leases
2021	$ 6,706
2022	6,634
2023	6,590
2024	6,210
2025	5,646
Thereafter	122,085
Total future lease payments	153,871
Less: Liability accretion	(52,117)
Total lease liability	101,754
Finance Leases
2021	54,992
2022	6,004
2023	4,622
2024	5,279
2025	3,396
Thereafter	2,324
Total future lease payments	76,617
Less: Liability accretion	(2,458)
Total lease liability	$ 74,159	$ 35,400

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LEASES - MATURITIES OF LEASE LIABILITIES UNDER TOPIC 840 (Details) $ in Thousands	Sep. 30, 2019 USD ($)
Operating Leases
2020	$ 4,411
2021	4,698
2022	4,609
2023	4,579
2024	4,199
Thereafter	54,405
Finance Leases
2020	11,707
2021	6,603
2022	7,494
2023	3,995
2024	4,652
Thereafter	$ 4,173

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COMMITMENTS AND CONTINGENT LIABILITIES - SCHEDULE OF FUTURE COMMITTED EXPENSES (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Long-term Purchase Commitment [Line Items]
Current charges recoverable through BGSS	$ 124,700
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	378,626
2021	231,779
2022	166,285
2023	124,321
2024	106,037
Thereafter	$ 593,464
Minimum
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, fixed period	1 year
Maximum
Long-term Purchase Commitment [Line Items]
Storage and pipeline capacity, fixed period	10 years
Energy Services
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	$ 249,589
2021	68,079
2022	38,368
2023	26,435
2024	19,598
Thereafter	37,469
Energy Services | Natural gas purchases
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	151,270
2021	1,600
2022	0
2023	0
2024	0
Thereafter	0
Energy Services | Storage demand fees
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	21,857
2021	13,028
2022	8,632
2023	3,748
2024	2,488
Thereafter	942
Energy Services | Pipeline demand fees
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	76,462
2021	53,451
2022	29,736
2023	22,687
2024	17,110
Thereafter	36,527
Natural Gas Distribution
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	129,037
2021	163,700
2022	127,917
2023	97,886
2024	86,439
Thereafter	555,995
Natural Gas Distribution | Natural gas purchases
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	4,377
2021	0
2022	0
2023	0
2024	0
Thereafter	0
Natural Gas Distribution | Storage demand fees
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	36,096
2021	32,122
2022	20,303
2023	12,768
2024	6,830
Thereafter	3,530
Natural Gas Distribution | Pipeline demand fees
Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	88,564
2021	131,578
2022	107,614
2023	85,118
2024	79,609
Thereafter	$ 552,465

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COMMITMENTS AND CONTINGENT LIABILITIES - CAPITAL EXPENDITURES (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Operating leases, future minimum payments due, next five years (not more than)	$ 1,400
Operating leases, future minimum payments due, thereafter	$ 73

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COMMITMENTS AND CONTINGENT LIABILITIES - GUARANTEES (Details) $ in Millions	Sep. 30, 2020 USD ($)
Guarantee Obligations
Guarantor Obligations [Line Items]
Loss contingency, estimate of possible loss	$ 258

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COMMITMENTS AND CONTINGENT LIABILITIES - LEGAL PROCEEDINGS (Details) - USD ($) $ in Thousands					12 Months Ended
	Sep. 09, 2020	Sep. 08, 2020	Mar. 16, 2020	Sep. 27, 2019	Sep. 30, 2020	Sep. 30, 2019
Loss Contingencies [Line Items]
Regulatory assets					$ 527,459	$ 496,637
Regulatory liabilities-noncurrent					$ 196,450	202,435
Recovery period					7 years
Minimum
Loss Contingencies [Line Items]
Litigation settlement, gross					$ 143,100
Maximum
Loss Contingencies [Line Items]
Litigation settlement, gross					181,700
Environmental remediation costs, Liability for future expenditures
Loss Contingencies [Line Items]
Regulatory assets					150,600	$ 131,100
Environmental remediation costs, Expended, net of recoveries
Loss Contingencies [Line Items]
Regulatory assets					$ 36,500
RAC
Loss Contingencies [Line Items]
Approved rate, amount	$ 9,700	$ 8,500
NJNG | RAC
Loss Contingencies [Line Items]
Requested base rate increase (decrease), amount			$ 1,200	$ 1,400

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COMMON STOCK EQUITY (Details) - USD ($) $ / shares in Units, $ in Thousands		12 Months Ended
	Dec. 04, 2019	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Class of Stock [Line Items]
Number of shares issued in transaction (in shares)	6,545,454
Proceeds from issuance of common stock	$ 212,900	$ 18,080	$ 16,717	$ 17,136
Forward sales agreement, settlement (in shares)		543,150
Directly Issued Common Stock
Class of Stock [Line Items]
Number of shares issued in transaction (in shares)	5,333,334
Forward Sales Agreements
Class of Stock [Line Items]
Number of shares issued in transaction (in shares)	1,212,120
Conversion price per share (usd per share)	$ 40.0125
Forward sales agreement, settlement, amount		$ 14,300

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REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT INCOME TO CONSOLIDATED (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Utility									$ 729,923	$ 710,793	$ 731,865
Nonutility									1,223,745	1,881,252	2,183,244
Total operating revenues	$ 400,044	$ 298,974	$ 639,614	$ 615,036	$ 479,081	$ 434,942	$ 866,255	$ 811,767	1,953,668	2,592,045	2,915,109
Depreciation and amortization									107,368	81,109	76,571
Interest income									2,959	1,623	614
Interest expense, net of capitalized interest									67,597	47,082	46,286
Income tax provision (benefit)									36,494	18,440	(42,232)
Equity in earnings of affiliates									14,311	13,628	13,008
Net financial earnings (loss)									165,333	129,390	238,063
Capital expenditures									448,109	525,932	384,588
Investments in equity investees									2,117	4,102	16,151
Operating Segments
Segment Reporting Information [Line Items]
Total operating revenues									1,907,687	2,551,683	2,916,044
Depreciation and amortization									106,628	80,480	76,037
Interest income									4,387	5,072	4,228
Interest expense, net of capitalized interest									67,628	48,370	49,231
Income tax provision (benefit)									38,687	17,385	(53,841)
Net financial earnings (loss)									159,451	127,572	242,219
Capital expenditures									444,879	523,448	383,375
Operating Segments | Natural Gas Distribution
Segment Reporting Information [Line Items]
Utility									729,923	710,793	731,865
Total operating revenues									729,923	710,793
Depreciation and amortization									71,883	57,980	53,208
Interest income									538	994	614
Interest expense, net of capitalized interest									30,975	26,134	25,299
Income tax provision (benefit)									27,021	9,434	(1,910)
Net financial earnings (loss)									126,902	78,062	84,048
Capital expenditures									290,040	345,004	254,523
Operating Segments | Clean Energy Ventures
Segment Reporting Information [Line Items]
Nonutility									102,617	98,099	71,375
Total operating revenues									102,617	98,099
Depreciation and amortization									25,329	22,376	22,747
Interest income									240	0	0
Interest expense, net of capitalized interest									20,253	14,846	18,320
Income tax provision (benefit)									11,034	7,270	(68,379)
Net financial earnings (loss)									22,111	31,903	73,426
Capital expenditures									133,841	157,828	123,421
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Nonutility									1,029,303	1,734,553	2,064,477
Total operating revenues									1,029,303	1,734,553
Depreciation and amortization									123	118	76
Interest income									99	78	240
Interest expense, net of capitalized interest									3,276	5,205	3,945
Income tax provision (benefit)									(3,615)	(1,573)	24,996
Net financial earnings (loss)									(7,873)	2,918	60,378
Operating Segments | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility									42,015	0	0
Total operating revenues									42,015	0
Depreciation and amortization									9,293	6	6
Interest income									3,510	4,000	3,374
Interest expense, net of capitalized interest									13,124	2,185	1,667
Income tax provision (benefit)									4,247	2,254	(8,548)
Equity in earnings of affiliates									15,903	15,832	16,165
Net financial earnings (loss)									18,311	14,689	24,367
Capital expenditures									20,998	20,616	5,431
Investments in equity investees									2,117	4,102	16,151
Intercompany
Segment Reporting Information [Line Items]
Nonutility									1,207	2,302	2,665
Intercompany | Energy Services
Segment Reporting Information [Line Items]
Nonutility									1,116	8,238	48,327
Intercompany | Storage and Transportation
Segment Reporting Information [Line Items]
Nonutility									2,713	0	0
Home Services and Other
Segment Reporting Information [Line Items]
Nonutility									49,810	48,600	47,392
Total operating revenues									49,810	48,600
Depreciation and amortization									1,032	914	780
Interest income									8,633	1,942	1,476
Interest expense, net of capitalized interest									10,327	1,535	7
Income tax provision (benefit)									(2,478)	1,428	11,944
Net financial earnings (loss)									5,784	1,911	(3,829)
Capital expenditures									3,230	2,484	1,213
Eliminations
Segment Reporting Information [Line Items]
Nonutility									(5,036)	(10,540)	(50,992)
Depreciation and amortization									(292)	(285)	(246)
Interest income									(10,061)	(5,391)	(5,090)
Interest expense, net of capitalized interest									(10,358)	(2,823)	(2,952)
Income tax provision (benefit)									285	(373)	(335)
Equity in earnings of affiliates									(1,592)	(2,204)	(3,157)
Net financial earnings (loss)									$ 98	$ (93)	$ (327)

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REPORTING SEGMENT AND OTHER OPERATIONS DATA - NET FINANCIAL EARNINGS LOSS RECONCILIATION (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting [Abstract]
Consolidated net financial earnings									$ 165,333	$ 129,390	$ 238,063
Less:
Unrealized (gain) loss on derivative instruments and related transactions									(9,644)	2,881	26,770
Unrealized loss (gain) on derivative instruments and related transactions, tax effect									2,296	(711)	(4,512)
Effects of economic hedging related to natural gas inventory									12,690	4,309	(22,570)
Effects of economic hedging related to natural gas inventory, tax effect									(3,016)	(1,024)	7,362
NET INCOME	$ 32,707	$ (19,298)	$ 73,846	$ 75,752	$ (12,027)	$ (13,080)	$ 73,671	$ 75,371	$ 163,007	$ 123,935	$ 231,013

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REPORTING SEGMENT AND OTHER OPERATIONS DATA - RECONCILIATION OF SEGMENT ASSETS TO CONSOLIDATED (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	$ 5,316,477	$ 4,157,942	$ 3,986,304
Operating Segments
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	5,435,389	4,290,550	4,042,679
Operating Segments | Natural Gas Distribution
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	3,531,477	3,064,309	2,663,054
Operating Segments | Clean Energy Ventures
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	814,277	694,439	740,704
Asset held for sale			206,900
Operating Segments | Energy Services
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	244,836	290,847	396,852
Operating Segments | Storage and Transportation
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	844,799	240,955	242,069
Home Services and Other
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	138,375	104,411	114,732
Eliminations
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	$ (257,287)	$ (237,019)	$ (171,107)

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RELATED PARTY TRANSACTIONS (Details) DTH in Thousands, $ in Thousands		12 Months Ended
	Apr. 01, 2010 USD ($) Bcf	Sep. 30, 2020 USD ($) DTH lease Bcf	Sep. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)
Related Party Transaction [Line Items]
Demand fees recognized pertaining to related party agreement		$ 6,083	$ 7,948	$ 8,505
Due to related parties		$ 791	790
Number of asset management agreements | lease		3
NJNG to NJRES Affiliate
Related Party Transaction [Line Items]
Asset management agreement, period	5 years
NJNG to Steckman RIdge Affiliate - National Gas Distribution
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 recognized pertaining to related party agreement		$ 5,900	5,814	5,730
Due to related parties		$ 775	775
NJNG to PennEast Affiliate
Related Party Transaction [Line Items]
Transportation precedent agreement, period		15 years
Transportation capacity under precedent agreement from NJNG with PennEast (in Dths per day) | DTH		180
NJRES to PennEast Affiliate
Related Party Transaction [Line Items]
Transportation precedent agreement, period		5 years
NJRES to Steckman Ridge Affiliate - Energy Services
Related Party Transaction [Line Items]
Demand fees recognized pertaining to related party agreement		$ 183	2,134	$ 2,775
Due to related parties		$ 16	$ 15
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

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ACQUISITIONS AND DISPOSITIONS - ACQUISITIONS (Details) $ in Thousands, DTH in Millions			1 Months Ended	12 Months Ended
	Jan. 13, 2020 USD ($) mi	Oct. 11, 2019 USD ($) DTH	Nov. 30, 2017 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)
Business Acquisition [Line Items]
Purchase price				$ 523,647	$ 0	$ 10,000
Leaf River Energy Center LLC | NJR Pipeline
Business Acquisition [Line Items]
Percentage of voting interests acquired		100.00%
Purchase price		$ 367,500
Natural gas capacity of acquiree | DTH		32.2
Leaf River Energy Center LLC | Minimum | NJR Pipeline
Business Acquisition [Line Items]
Estimated Useful Lives				5 years
Leaf River Energy Center LLC | Maximum | NJR Pipeline
Business Acquisition [Line Items]
Estimated Useful Lives				50 years
Talen Generation, LLC | Talen's Membership Interests In IEC
Business Acquisition [Line Items]
Pipeline length owned | mi	84
Base purchase price	$ 166,000
Initial payment	156,000		$ 10,000
Additional contingent consideration	$ 23,000
Natural Gas Transportation Capacity Agreement, Period	10 years
Talen Generation, LLC | Talen's Membership Interests In IEC | Minimum
Business Acquisition [Line Items]
Estimated Useful Lives				5 years
Talen Generation, LLC | Talen's Membership Interests In IEC | Maximum
Business Acquisition [Line Items]
Estimated Useful Lives				30 years

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ACQUISITIONS AND DISPOSITIONS - NET ASSETS ACQUIRED (Details) - USD ($) $ in Thousands			12 Months Ended
	Jan. 13, 2020	Oct. 11, 2019	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Business Acquisition [Line Items]
Purchase price			$ 523,647	$ 0	$ 10,000
Leaf River Energy Center LLC | NJR Pipeline
Business Acquisition [Line Items]
Purchase price		$ 367,500
Net working capital adjustment		4,111
Transaction costs		1,664
Total costs capitalized		373,275
Identifiable assets acquired
Property, plant and equipment		365,715
Base gas		3,445
Other		4
Net working capital		4,111
Net assets acquired		$ 373,275
Talen Generation, LLC | Talen's Membership Interests In IEC | Adelphia Gateway
Business Acquisition [Line Items]
Purchase price	$ 166,000
Net working capital adjustment	(449)
Transaction costs	9,456
Total costs capitalized	175,007
Identifiable assets acquired
Property, plant and equipment	174,438
Other	1,018
Net working capital	(449)
Net assets acquired	$ 175,007

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ACQUISITIONS AND DISPOSITIONS - DISPOSITIONS (Details) $ in Thousands				12 Months Ended
	Feb. 07, 2019 USD ($)	Jun. 01, 2018 USD ($) MW	Feb. 28, 2018 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of businesses, net				$ 0	$ 645	$ 4,663
Proceeds from sale of businesses, net of closing costs				$ 0	$ 205,745	$ 27,916
Clean Energy Ventures
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Wind farm total capacity (in MW) | MW		9.7
Disposal group consideration	$ 208,600	$ 18,500
Proceeds from sale of business		$ 951
Gain on sale of businesses, net	$ 645
Clean Energy Ventures | Natural Gas
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Derivative gain			$ 14,600
Issued And Outstanding Shares Of NRJ Retail Services
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of business			3,700
Proceeds from sale of businesses, net of closing costs			$ 9,500

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SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Quarterly Financial Information Disclosure [Abstract]
Operating revenues	$ 400,044	$ 298,974	$ 639,614	$ 615,036	$ 479,081	$ 434,942	$ 866,255	$ 811,767	$ 1,953,668	$ 2,592,045	$ 2,915,109
Operating income (loss)	42,655	(16,847)	98,483	104,618	(4,951)	(1,372)	79,606	91,273	228,909	164,556	209,012
Net income (loss)	$ 32,707	$ (19,298)	$ 73,846	$ 75,752	$ (12,027)	$ (13,080)	$ 73,671	$ 75,371	$ 163,007	$ 123,935	$ 231,013
Earnings (loss) per share
Basic (in dollars per share)	$ 0.34	$ (0.20)	$ 0.78	$ 0.82	$ (0.16)	$ (0.15)	$ 0.83	$ 0.87	$ 1.72	$ 1.39	$ 2.63
Diluted (in dollars per share)	$ 0.34	$ (0.20)	$ 0.77	$ 0.82	$ (0.17)	$ (0.15)	$ 0.83	$ 0.87	$ 1.71	$ 1.38	$ 2.62