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A Culture of
INNOVATION
2023 ANNUAL REPORT
We are committed to enhancing
our customers’ quality of life
by meeting their expectations
for reliability and value in an
environmentally responsible way
— every day.
These core values drive our Commitment
to Stakeholders:
• Safe and Reliable Service
• Customer Satisfaction
• Sustainable Growth and Innovation
• Engaged and High-Performing Workforce
• Social Responsibility
• Superior Financial Performance
Cover: NJR’s culture of innovation is helping decarbonize the
energy we deliver and lead the way to a cleaner energy future.
CEV’s Old Bridge Community Solar Project is transforming
a landfill to provide clean energy to local communities.
1
1
¶
Financial Summary
NET FINANCIAL EARNINGS
PER SHARE*,†
DIVIDENDS DECLARED
PER SHARE
$2.70
$2.50
$2.16
$1.74
$1.45
$3.00
$2.50
$2.00
$1.50
$1.00
$0.50
$0.00
$1.75
$1.50
$1.25
$1.00
$0.75
$0.50
$0.25
$0.00
$1.48
$1.36
$1.59
$1.19
$1.27
FY2019
FY2020
FY2021
FY2022
FY2023
FY2019
FY2020
FY2021
FY2022
FY2023
infrastructure investments, NJR’s environmental
sustainability, decarbonization and clean energy goals,
CEV projects under construction, contract or
exclusivity, expansion of our solar footprint, asset
management agreements, emissions reduction
strategies, initiatives and targets, our investments in
infrastructure, low-carbon fuels and renewables and
emerging technologies such as renewable natural
gas and hydrogen gas.
Additional information and factors that could cause
actual results to differ materially from NJR’s
expectations are contained in NJR’s filings with
the U.S. Securities and Exchange Commission
(SEC), including NJR’s Annual Report 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 website,
http://www.sec.gov. Information included in this
report 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.
§
As measured by leaks per mile.
# NJNG’s service territory consists of part of six counties
in New Jersey: Monmouth, Ocean, Morris, Middlesex,
Burlington and Sussex.
± Rating determined by Shopper Approved. See
njrhomeservices.com for more information.
Information Regarding Forward-Looking Statements —
This report contains 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. NJR cautions
readers that the assumptions forming the basis for
forward-looking statements include many factors
that are beyond NJR’s ability to control or estimate
precisely, such as estimates of future market conditions
and the behavior of other market participants. Words
such as “anticipates,” “estimates,” “expects,”
“projects,” “may,” “will,” “intends,” “plans,” “believes,”
“should” and similar expressions may identify forward-
looking statements and such forward-looking
statements are made based upon management’s
current expectations, assumptions and beliefs as
of this date concerning future developments and
their potential effect upon NJR. There can be no
assurance that future developments will be in
accordance with management’s expectations,
assumptions and beliefs or that the effect of future
developments on NJR will be those anticipated by
management. Forward-looking statements in this
report include, but are not limited to, certain statements
regarding NJR’s NFE guidance, future growth of
NJNG’s customer base, investment programs and
* Net Financial Earnings or NFE is a financial measure
not calculated in accordance with Generally Accepted
Accounting Principles (GAAP) of the United States as
it excludes all unrealized and certain realized gains
and losses associated with derivative instruments
and net applicable tax adjustments. NFE also excludes
certain transactions associated with equity method
investments, including impairment charges, which
are non-cash charges, and return of capital in
excess of the carrying value of NJR’s investment.
For further discussion and reconciliation to GAAP
of this non-GAAP financial measure, see our fiscal
2023 Report on Form 10-K.
† All periods revised to reflect the deferral method
of accounting for federal investment tax credits.
** Peer Group Companies, include: Atmos Energy
Corporation, Avista Corporation, Black Hills Corporation,
Inc.,
National Fuel Gas Company, NiSource
Northwest Natural Holding Company, ONE Gas, Inc.,
Southwest Gas Corporation, Spire Inc.
µ
Utility Gross Margin is defined as operating revenues
less natural gas purchases, sales tax and regulatory
rider expenses. This measure differs from gross
margin as presented on a GAAP basis, as it excludes
certain operations and maintenance expense
and depreciation and amortization. For further
discussion and a reconciliation to GAAP of this non-
GAAP financial measure, please see our fiscal 2023
report on Form 10-K.
∞ Investments include SAVEGREEN. For GAAP
purposes, SAVEGREEN investments are included as
part of cash flows from operations.
2
2
2
Dear Shareowner,
Innovation has always influenced the energy landscape.
Rarely, however, have we experienced the level of
transformation seen today. Technological advancements
are driving progress and making the energy we use cleaner.
As the energy outlook continues to evolve, New Jersey
Resources (NJR) has a clear vision of our role in a clean
energy future.
It begins with leveraging our existing energy infrastructure,
investing in emerging technologies, ensuring safety and
reliability and effectively aligning with public policy on climate
goals. NJR is leading the way by investing in innovations,
such as carbon capture, blowdown mitigation equipment
and high-efficiency natural gas heat pumps, to reduce
emissions. We also support the use of new, low-carbon fuels,
like clean hydrogen and renewable natural gas. And we
continue to execute on solar investments, all while growing
our business and providing value to our shareowners.
In fiscal 2023, NJR achieved our long-term growth rate of
7-9% and delivered net financial earnings (NFE)* per share
of $2.70, compared with $2.50 per share last year. Building
on our strong track record of returning value to shareowners,
we increased our dividend 7.7% to $1.68 per share. NJR has
paid quarterly dividends continuously since 1952 and raised
the dividend every year for the last 28 years.
New Jersey Natural Gas (NJNG) added 8,800 new customers
— including our first in Sussex County, New Jersey. This
growth rate is among the highest in our peer group**. NJNG
also leveraged our Basic Gas Supply Service incentives to
create $97 million in savings for customers and $20 million
in utility gross marginµ, exceeding the prior year’s results.
NJNG invested over $450 million∞ this year, including on
key infrastructure projects throughout our distribution
system that enhance safety and reliability while maintaining
the most environmentally sound natural gas delivery
network in the state§.
We believe our world-class energy infrastructure will play a
critical role in achieving climate goals. Today, 82% of homes
in NJNG’s service territory# rely on our natural gas delivery
network to heat their homes. Our system also provides
$261.8
million consolidated
NFE, or $2.70 per share,
compared with $240.3
million, or $2.50 per
share, in fiscal 2022.
$264.7
million consolidated
net income, compared
with $274.9 million in
fiscal 2022.
28th
consecutive year
of dividend growth.
576,000
natural gas
customers served.
essential primary and back-up energy to more than 1,500
critical infrastructure facilities, including hospitals, schools
and military facilities. By continuing to invest in our delivery
network and applying new technologies, we can achieve
emission reduction targets at a lower cost and with greater
reliability for customers.
3
NJNG is deploying new, cutting-edge blowdown recapture
technology to reduce emissions and reclaim vented gas.
4
Energy efficiency also plays a vital role. It is the fastest,
most cost-effective way to help customers reduce their
carbon footprint. This year, NJNG invested $60 million in
SAVEGREEN™ — the highest annual investment in our
company’s history.
NJR Clean Energy Ventures (CEV) provided improved
year-over-year results. In fiscal 2023, CEV acquired two
operational assets and placed eight commercial projects
into service — including the largest floating solar array and
the largest capped landfill solar array in North America —
and added a total of 82 megawatts (MW) of installed capacity,
the largest capacity increase in the company’s history.
CEV also grew our development pipeline in fiscal 2023 and
now has a record number of projects under construction,
contract or exclusivity. We expect to further expand our solar
footprint with approximately 750 MW of potential investment
options that would grow our existing capacity by nearly 160%.
Our Storage and Transportation business continued to
contribute NFE in fiscal 2023 and ensured customers’
needs were met, especially during severe weather events
and periods of volatility. Adelphia Gateway performed well
in its first full year of operation, achieving the Pennsylvania
Governor’s Award for Safety Excellence. Leaf River Energy
Center benefitted from attractive market conditions and
is uniquely positioned for growth in a high-demand region.
Over
272
million pounds of
CO2 emissions reduced
since inception of
SAVEGREEN™.
Approximately
750
MW pipeline of
solar projects under
construction, contract
or exclusivity.
Nearly
4,000
hours of volunteer
service and more than
1,800 nonprofit and
community organizations
supported by NJR.
Net-Zero
emissions goal for NJR’s
New Jersey operations
by 2050.
Approximately
469
MW of installed
solar capacity.
A near
5-Star
online customer rating
for HVAC services.±
NJR Energy Services leveraged its portfolio of strategically
positioned assets to deliver outsized performance in fiscal
2023. These strong results were supported by its asset
management agreements, which provide consistent cash
and earnings contributions well into the future.
and policymakers, and look forward to working together
to advance our shared goals. We also benefit from an
exceptional board of directors whose integrity and expertise
guide our strategy for continued performance for our
shareowners, customers and communities.
NJR Home Services continued to meet customers’ home
comfort needs. This year, our team completed over 76,000
service calls and more than 3,700 HVAC, plumbing and
generator installations.
Our accomplishments in fiscal 2023 speak volumes about
our team and our ability to identify opportunities in dynamic
market conditions. NJR’s strong culture of innovation
provides a solid foundation to continue to meet our customers’
energy needs, support public policy and grow our business
in a disciplined and environmentally responsible way. Looking
ahead, we remain committed to delivering the energy of the
future and ensuring long-term value for our shareowners.
We hope you’ll join us for our Annual Meeting on January 24,
2024, at 9:30 a.m. EST, via webcast. Please see your proxy
statement for details.
On behalf of our entire company, thank you for your
investment and confidence in NJR. We remain committed
to always giving our best to meeting your expectations and
rewarding your trust.
Sincerely,
Our more than 1,300 employees, including the members
of IBEW Local 1820, are the driving force behind all our
accomplishments. Fiscal 2023 is no exception. We appreciate
the collaborative relationships we have with our regulators
Steve Westhoven
President and CEO
5
Corporate Profile
New Jersey Resources (NYSE: NJR) is a Fortune 1000 company that, through its subsidiaries, provides safe and
reliable natural gas and clean energy services, including transportation, distribution, storage, asset management and
home services. NJR is composed of five primary businesses:
New Jersey Natural Gas, NJR’s principal subsidiary, operates and maintains natural gas transportation and
distribution infrastructure to serve 576,000 customers in New Jersey’s Monmouth, Ocean, Morris, Middlesex,
Burlington and Sussex counties.
NJR Clean Energy Ventures, one of the largest solar owner/operators in New Jersey, invests in, owns and
operates solar projects with a total capacity of approximately 469 megawatts, providing residential and commercial
customers with low-carbon solutions.
NJR Energy Services manages a diversified portfolio of natural gas storage and transportation assets and
provides physical natural gas services and customized energy solutions to its customers across North America.
Storage and Transportation serves customers from local distributors and producers to electric generators and
wholesale marketers through its ownership of Leaf River Energy Center and the Adelphia Gateway pipeline, as well
as its 50% equity ownership in the Steckman Ridge natural gas storage facility.
NJR Home Services provides service contracts, as well as heating, central air conditioning, water heaters, standby
generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey.
NJR and its more than 1,300 employees are committed to helping customers save energy and money by promoting
conservation and encouraging efficiency through Conserve to Preserve® and initiatives such as SAVEGREEN™ and
The Sunlight Advantage®.
For more information about NJR, visit njresources.com,
follow us on Linkedin @New Jersey Resources,
X (formerly Twitter) @NJNaturalGas, Instagram @njnglife
and like us on facebook.com/NewJerseyNaturalGas.
6
Through its Coastal Climate Initiative, NJR supports education, research
and innovative restoration techniques that enhance resilience, improve
ecosystems and increase carbon sequestration in our local communities.
7
Directors and Officers
NEW JERSEY RESOURCES
Directors
Donald L. Correll, 73 (A,B,C)
Chairman of the Board
New Jersey Resources
Chief Executive Officer, Co-founder
Water Capital Partners, LLC
(2008)
Gregory E. Aliff, 70 (A,B,D)
Partner (retired)
Deloitte & Touche LLP
(2019)
James H. DeGraffenreidt Jr., 70
(A,D)
Chairman and
Chief Executive Officer (retired)
WGL Holdings, Inc.
(2019)
M. Susan Hardwick, 61 (A)
President and
Chief Executive Officer
American Water Works Company, Inc.
(2020)
Peter C. Harvey, 65
Partner
Patterson Belknap Webb & Tyler LLP
(2023)
Jane M. Kenny, 72 (B,C,D)
Founder and Managing Partner
The Whitman Strategy Group, LLC
(2006)
Thomas C. O’Connor, 67 (A,C)
Chairman, President and
Chief Executive Officer (retired)
DCP Midstream, LLC
(2017)
Michael A. O’Sullivan, 63
Senior Vice President, NextEra
Energy Resources (retired)
(2022)
Sharon C. Taylor, 69 (B,C,D)
Senior Vice President
Human Resources (retired)
Prudential Financial
(2012)
Stephen D. Westhoven, 55 (B)
President and
Chief Executive Officer
New Jersey Resources
(2018)
George R. Zoffinger, 75 (A,D)
President and
Chief Executive Officer
Constellation Capital Corporation
(1996)
Date represents year director joined NJR board.
(A) Member of Audit Committee
(B) Member of Executive Committee
(C) Member of Leadership Development and Compensation Committee
(D) Member of Nominating/Corporate Governance Committee
Ages as of September 30, 2023.
8
NEW JERSEY RESOURCES AND SUBSIDIARIES
Officers
Stephen D. Westhoven, 55
(1,2,3,4,5,7)
President and
Chief Executive Officer
(1990)
Sean N. Annitto, 54 (4)
Vice President—NJR Energy
Services
(1996)
Roberto Bel, 50 (1,2,3,4,5,6,7)
Senior Vice President and
Chief Financial Officer
(2019)
Francis J. Casey, 59 (3,6,7)
President—NJR Home Services
(2011)
Amy Cradic, 52 (1,3,4,5)
Senior Vice President and Chief
Operating Officer—Non-Utility
Businesses, Strategy and
External Affairs
(2018)
Lori DelGiudice, 48 (1,7)
Senior Vice President—
Human Resources
(2022)
James Eckert, 54 (5)
Vice President—
Storage and Transportation
(2023)
David Johnson, 55 (1)
Vice President—Corporate
Business Development
(2002)
Mark G. Kahrer, 61 (2)
Senior Vice President—
Regulatory Affairs
New Jersey Natural Gas
(2017)
James W. Kent, 54 (1,7)
Vice President—Corporate
Risk Management
(2013)
Thomas J. Massaro Jr., 57 (3,6,7)
Senior Vice President—
NJR Retail
(1989)
Tejal K. Mehta, 40 (1,2,3,4,5,7)
Corporate Secretary and
Assistant General Counsel
(2022)
Patrick J. Migliaccio, 49 (2)
Senior Vice President
and Chief Operating Officer—
New Jersey Natural Gas
(2009)
Robert F. Pohlman, 40 (1,3)
Vice President—NJR Clean
Energy Ventures and
Corporate Strategy
(2011)
Richard Reich, 48 (1,2,3,4,5,7)
Senior Vice President and
General Counsel
(2006)
Ginger P. Richman, 59 (5)
Vice President—Storage
and Transportation
(2003)
Date represents year of affiliation with an NJR company.
Affiliations:
(1) New Jersey Resources
(2) New Jersey Natural Gas
(3) NJR Clean Energy Ventures
(4) NJR Energy Services
(5) Storage and Transportation
(6) NJR Home Services
(7) NJR Service Corporation
Ages as of September 30, 2023.
Kraig E. Sanders, 58 (2)
Vice President—Operations,
New Jersey Natural Gas
(1987)
Daniel B. Sergott, 48 (1,2,3,4,5,7)
Treasurer
(2006)
Jacqueline K. Shea, 59 (1,7)
Senior Vice President and
Chief Information Officer
(2016)
Stephen M. Skrocki, 47 (1)
Corporate Controller and
Principal Accounting Officer
(2017)
Marissa Travaline, 44 (2)
Vice President—Customer Service,
Energy Efficiency and Marketing
New Jersey Natural Gas
(2023).
Mark F. Valori, 60 (3)
Vice President—NJR Clean
Energy Ventures
(2010)
John B. Wyckoff, 55 (2)
Vice President—
Energy Delivery
New Jersey Natural Gas
(1989)
9
Presenting our Fiscal 2023 Form 10-K
Our fiscal 2023 Report on Form 10-K (the “10-K”)
includes financial statements for New Jersey Resources
Corporation (“NJR”). It also includes detailed information
about each of our subsidiaries and the competitive
environments of our businesses, properties we own and
other matters.
All publicly held companies in the United States are
required to file a 10-K report with the U.S. Securities and
Exchange Commission (the “SEC”) every year. Our
10-K is required by the rules and regulations of the SEC
to contain certain company information in addition to
the financial information included in our previous annual
reports to shareowners. We are supplying our 2023 10-K
(without exhibits) consistent with our commitment to
provide transparency and full disclosure to
our shareowners.
The fiscal 2023 10-K is amended, supplemented
and updated by any amendment we may file, and by
all of the quarterly reports on Form 10-Q and current
reports on Form 8-K we file or furnish with the SEC
during the year. We urge you to read all such reports.
Copies may be obtained as described under
“Request for Documents” on the inside back cover
of this Annual Report.
Form 10-K Overview
This Annual Report is not a part of, and should not
be considered to be included in, our 2023 10-K.
The following listing, which includes highlights of the
2023 Form 10-K, can help you find information easily.
A comprehensive Table of Contents with the page
number for each item can be found on page
“i” of the 2023 10-K.
Part I: NJR’s Business includes:
• Detailed descriptions of NJR’s subsidiaries
• Information about our executive officers
• Risk factors related to our business
• Description of properties owned and operated
by NJR
• Legal proceedings
Part II: Market for Common Shares and Financial
Statements in Items 5 and 6 include:
• Selected financial data for NJR
Items 7 and 7A include:
• Management’s discussion and analysis of financial
condition and results of operations
• Quantitative and qualitative disclosures about
market risk
Items 8 and 9 include:
• Management’s report on internal control over
financial reporting
• Report of independent registered public
accounting firm
• Financial statements and notes for NJR
• Controls and procedures and other information
Part III: Information about Board Members,
Executive Officers, Governance, Shareowners
and Auditors includes:
• Members of the board of directors and
executive officers
• Corporate governance
• Executive compensation
• NJR’s shareowners and related matters
• Related-person transactions
• Director independence
• Accounting fees, each of which are incorporated
by reference to NJR’s proxy statement
Part IV: Exhibits and Signatures include:
• Index of exhibits
• Signatures of members of the board of directors
and certain officers
10
NJR is embracing new technologies, like carbon capture, to further
reduce emissions and support state and federal public policy goals.
11
Form 10-K
12
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
☒ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended September 30, 2023
OR
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission file number 001-08359
NEW JERSEY RESOURCES CORPORATION
(Exact name of registrant as specified in its charter)
New Jersey
(State or other jurisdiction of
incorporation or organization)
1415 Wyckoff Road, Wall, New Jersey 07719
(Address of principal executive offices)
22-2376465
(I.R.S. Employer
Identification Number)
(732) 938-1000
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12 (b) of the Act:
Title of each class
Common Stock - $2.50 Par Value
Trading symbol(s)
NJR
Securities registered pursuant to Section 12 (g) of the Act:
None
Name of each exchange on which registered
New York Stock Exchange
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☒ Yes ☐ No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. ☐ Yes ☒ No
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during
the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for
the past 90 days.
☒ Yes ☐ No
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation
S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
☒ Yes ☐ No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging
growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of
the Exchange Act.
Large accelerated filer
Non-accelerated filer
☒
☐
Accelerated filer
Smaller reporting company
Emerging growth company
☐
☐
☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or
revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
☐
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over
financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit
report.
☒
If securities are registered pursuant to Section 12(b) of the Act, indicate by checkmark whether the financial statements of the registrant included in the filing
reflect the correction of an error to previously issued financial statements.
☐
Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any
of the registrant’s executive officers during the relevant recovery period pursuant to § 240.10D-1(b).
☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
☐ Yes ☒ No
The aggregate market value of the registrant’s common stock held by non-affiliates was $5,138,493,161 based on the closing price of $53.20 per share on
March 31, 2023, as reported on the New York Stock Exchange.
The number of shares outstanding of $2.50 par value common stock as of November 17, 2023 was 97,707,564.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant’s definitive Proxy Statement for the Annual Meeting of Shareowners (Proxy Statement) to be held on January 24, 2024, are incorporated
by reference into Part I and Part III of this report.
New Jersey Resources Corporation
TABLE OF CONTENTS
Glossary of Terms . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Information Concerning Forward-Looking Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
PART I
ITEM 1.
ITEM 1A.
ITEM 1B.
ITEM 2.
ITEM 3.
ITEM 4.
PART II
ITEM 5.
ITEM 6.
ITEM 7.
ITEM 7A.
ITEM 8.
ITEM 9.
ITEM 9A.
ITEM 9B.
PART III*
ITEM 10.
ITEM 11.
ITEM 12.
ITEM 13.
ITEM 14.
PART IV
ITEM 15.
Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Organizational Structure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Reporting Segments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Natural Gas Distribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Clean Energy Ventures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Energy Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Storage and Transportation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other Business Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Home Services and Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Environment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Human Capital Resources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Information About our Executive Officers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Risk Factors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unresolved Staff Comments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Mine Safety Disclosures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities . . . . . . . .
[Reserved] . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Management’s Discussion and Analysis of Financial Condition and Results of Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Quantitative and Qualitative Disclosures About Market Risk . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Management’s Report on Internal Control over Financial Reporting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Report of Independent Registered Public Accounting Firm (PCAOB ID No. 34) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Notes to Consolidated Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 1. Nature of the Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 2. Summary of Significant Accounting Policies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 3. Revenue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 4. Regulation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 5. Derivative Instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 6. Fair Value . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 7. Investments in Equity Investees . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 8. Earnings Per Share . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 9. Debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 10. Stock-Based Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 11. Employee Benefit Plans . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 12. Income Taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 13. Leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 14. Commitments and Contingent Liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 15. Reporting Segment and Other Operations Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 16. Related Party Transactions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Controls and Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Directors, Executive Officers and Corporate Governance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters . . . . . . . . . . . . . . . . . . . .
Certain Relationships and Related Transactions and Director Independence . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Principal Accountant Fees and Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Exhibits and Financial Statement Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Index to Financial Statement Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Exhibit Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Signatures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
* Portions of Item 10 and Items 11-14 are Incorporated by Reference from the Proxy Statement.
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New Jersey Resources Corporation
GLOSSARY OF KEY TERMS
Adelphia
AFUDC
AMA
ARO
ASC
ASU
B
Bcf
BGSS
BPU
CARES Act
CIP
Clean Energy Ventures or CEV
CME
COVID-19
CR&R
CSI
Degree-day
DEI
DRP
Dths
EDECA
EE
EMP
Energy Services or ES
Exchange Act
FASB
FCM
FERC
Financial Margin
Adelphia Gateway, LLC
Allowance for Funds Used During Construction
Asset Management Agreement
Asset Retirement Obligations
Accounting Standards Codification
Accounting Standards Update
Billion
Billion Cubic Feet
Basic Gas Supply Service
New Jersey Board of Public Utilities
Coronavirus Aid, Relief, and Economic Security Act
Conservation Incentive Program
Clean Energy Ventures segment
Chicago Mercantile Exchange
Novel coronavirus disease
Commercial Realty & Resources Corp.
Competitive Solar Incentive
The measure of the variation in the weather based on the extent to which the average
daily temperature falls below 65 degrees Fahrenheit
Diversity, equity and inclusion
NJR Direct Stock Purchase and Dividend Reinvestment Plan
Dekatherms
Electric Discount and Energy Competition Act
Energy Efficiency
New Jersey Energy Master Plan
Energy Services segment
Securities Exchange Act of 1934, as amended
Financial Accounting Standards Board
Futures Commission Merchant
Federal Energy Regulatory Commission
A non-GAAP financial measure, which represents revenues earned from the sale of
natural gas less costs of natural gas sold including any transportation and storage costs,
and excludes certain operations and maintenance expense and depreciation and
amortization, as well as any accounting impact from the change in the fair value of
certain derivative instruments
Fitch Ratings Company
First Mortgage Bond
Generally Accepted Accounting Principles of the United States
Global Warming Response Act of 2007
Health Care Cost Trend Rate
Fitch
FMB
GAAP
GWRA
HCCTR
Home Services and Other or HSO Home Services and Other Operations
ICE
IIP
Inflation Reduction Act
IRS
ISDA
ITC
LDCC
Leaf River
LNG
M
MGP
MMBtu
Moody’s
Mortgage Indenture
Intercontinental Exchange
Infrastructure Investment Program
Inflation Reduction Act of 2022
Internal Revenue Service
The International Swaps and Derivatives Association
Federal Investment Tax Credit
Leadership Development and Compensation Committee
Leaf River Energy Center LLC
Liquefied Natural Gas
Million
Manufactured Gas Plant
Million British Thermal Units
Moody’s Investors Service, Inc.
The Amended and Restated Indenture of Mortgage, Deed of Trust and Security
Agreement between NJNG and U.S. Bank National Association dated as of September 1,
2014, as amended
Megawatts
MW
Page 1
New Jersey Resources Corporation
Megawatt Hour
The North American Energy Standards Board
Net Asset Value
Net Financial Earnings
New Jersey Reinvestment in System Enhancement
New Jersey’s Clean Energy Program
New Jersey Department of Environmental Protection
New Jersey Natural Gas Company or our Natural Gas Distribution segment
The $250M unsecured committed credit facility expiring in September 2027
The $650M unsecured committed credit facility expiring in September 2027
New Jersey Resources Corporation
NJR Retail Company
NJR Clean Energy Ventures Corporation
NJR Energy Services Company, LLC
NJR Home Services Company
Not in accordance with GAAP
Normal Purchase/Normal Sale
New York Mercantile Exchange
Old Age, Survivors and Disability Insurance tax
Other Comprehensive Income
Operations and Maintenance
Other Postemployment Benefit Plans
Projected Benefit Obligation
PennEast Pipeline Company, LLC
Pension Equalization Plan
Pipeline Integrity Management
Power Purchase Agreement
Remediation Adjustment Clause
Renewable Energy Certificate
Safety Acceleration and Facility Enhancement Program, Phase II
Sarbanes-Oxley Act of 2002
The SAVEGREEN Project®
Employees’ Retirement Savings Plan
Societal Benefits Charge
Securities and Exchange Commission
Securities Act of 1933, as amended
Secured Overnight Financing Rate
Solar Renewable Energy Certificate
Southern Reliability Link
Standard & Poor’s Financial Services, LLC
Collectively, Steckman Ridge GP, LLC and Steckman Ridge, LP
GLOSSARY OF KEY TERMS (cont.)
MWh
NAESB
NAV
NFE
NJ RISE
NJCEP
NJDEP
NJNG
NJNG Credit Facility
NJR Credit Facility
NJR or The Company
NJR Retail
NJRCEV
NJRES
NJRHS
Non-GAAP
NPNS
NYMEX
OASDI
OCI
O&M
OPEB
PBO
PennEast
PEP
PIM
PPA
RAC
REC
SAFE II
Sarbanes-Oxley
SAVEGREEN
Savings Plan
SBC
SEC
Securities Act
SOFR
SREC
SRL
S&P
Steckman Ridge
Storage and Transportation or S&T Storage and Transportation segment
TETCO
TREC
Trustee
TSR
U.S.
Union
USF
Utility Gross Margin
Texas Eastern Transmission
Transition Renewable Energy Certificate
U.S. Bank National Association
Total Shareholder Return
The United States of America
International Brotherhood of Electrical Workers Local 1820
Universal Service Fund
A non-GAAP financial measure, which represents operating revenues less natural gas
purchases, sales tax, and regulatory rider expense, and excludes certain operations and
maintenance expense and depreciation and amortization
Page 2
New Jersey Resources Corporation
INFORMATION CONCERNING FORWARD-LOOKING STATEMENTS
Certain statements contained in this report, including, without limitation, statements as to management expectations, assumptions and
beliefs presented in Part I, Item 1. Business and Item 3. Legal Proceedings, and in Part II, Item 7. Management’s Discussion and Analysis of
Financial Condition and Results of Operations and Item 7A. Quantitative and Qualitative Disclosures About Market Risk, and in the notes to
the financial statements, are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended,
Section 21E of the Exchange Act and the Private Securities Litigation Reform Act of 1995. Forward-looking statements can also be identified
by the use of forward-looking terminology such as “anticipate,” “estimate,” “may,” “could,” “might,” “intend,” “expect,” “believe,” “will,”
“plan,” “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 2024 and thereafter include many
factors that are beyond our ability to control or estimate precisely, such as estimates of future market conditions, the behavior of other market
participants and changes in the debt and equity capital markets. The factors that could cause actual results to differ materially from our
expectations, assumptions and beliefs include, but are not limited to, those discussed in Part I, Item 1A. Risk Factors, as well as the following,
which are neither presented in order of importance nor weighted:
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our ability to obtain governmental and regulatory approvals, permits, certificates, 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 S&T infrastructure projects, in a timely manner;
our ability to address concerns over long-term climate change;
risks associated with our investments in clean energy projects, including the availability of regulatory incentives and federal tax credits, the
availability of viable projects, our eligibility for ITCs, the future market for RECs and electricity prices, our ability to complete construction of
the projects and operational risks related to projects in service;
risks associated with acquisitions and the related integration of acquired assets with our current operations;
our ability to comply with current and future regulatory requirements;
risks associated with our pipeline of projects and timely completion of such projects
commercial and wholesale credit risks, including the availability of creditworthy customers and counterparties, and liquidity in the wholesale
energy trading market;
volatility of natural gas and other commodity prices and their impact on NJNG customer usage, NJNG’s BGSS incentive programs, ES
operations and our risk management efforts;
the performance of our subsidiaries;
access to adequate supplies of natural gas and dependence on third-party S&T 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;
impacts of inflation, including the current inflationary environment, and increased natural gas costs;
the impact of a disallowance of recovery of environmental-related expenditures and other regulatory changes;
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 events causing volatility in the equity and credit markets on our access to capital, including natural disasters, pandemic illness and
other extreme events and risks, political and economic disruption and uncertainty related to Russia’s military invasion of Ukraine, the Israel-
Hamas War, and the international community’s responses;
risks of prolonged constriction of credit availability in the markets and our ability to secure short-term financing;
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, including ransomware, terrorism, other malicious acts against, 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, including, but not limited to, inflationary pressures, recessionary pressures, or rising interest rates,
and/or reductions in bond yields;
accounting effects and other risks associated with hedging activities and use of derivatives contracts;
our ability to optimize our physical assets;
weather and economic conditions, including those changes in weather and weather patterns that could be attributable to climate change;
the costs of compliance with present and future environmental laws, potential climate change-related legislation or any legislation resulting from
the 2019 New Jersey Energy Master Plan, as well as future executive orders and the outcomes of regulatory proceedings concerning natural gas;
uncertainties related to litigation, regulatory, administrative or environmental proceedings;
changes to tax laws and regulations, including our ability to optimize those changes brought about by the passage of the Inflation Reduction Act;
any potential need to record a valuation allowance for our deferred tax assets;
the delay or prevention of a favorable transaction due to changes in control provisions or laws;
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, including, but not limited to, cloud computing and generative artificial
intelligence.
Forward-looking statements made in this report apply only as of the date of this report. 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.
Page 3
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS
ORGANIZATIONAL STRUCTURE
New Jersey Resources Corporation is a New Jersey corporation and a diversified energy services holding company
whose principal business is the distribution of natural gas through a regulated utility, investing in and operating clean energy
projects and natural gas storage and transportation assets, and providing other retail and wholesale energy services to
customers. We are an exempt holding company under Section 1263 of the Energy Policy Act of 2005.
Our primary subsidiaries include the following:
New Jersey Natural Gas Company provides regulated natural gas utility service to approximately 576,000
residential and commercial customers throughout Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex
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.
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.
NJR Energy Services Company, LLC 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.
NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, invests in
energy-related ventures through its subsidiaries: NJR Midstream Company, which includes our wholly-owned
subsidiaries of Leaf River, located in southeastern Mississippi, and Adelphia, located in eastern Pennsylvania, which
are subject to FERC regulation, along with our 20% ownership interest in PennEast, which ceased operations in fiscal
2022; and NJR Steckman Ridge Storage Company, which holds our 50% combined ownership interest in Steckman
Ridge, located in Pennsylvania.
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 101,500 service contract customers, as well as solar installation projects, and is the primary
contributor to Home Services and Other operations.
Page 4
New Jersey Resources Corporation
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.
NJNG consists of regulated natural gas services, off-system sales, capacity and storage management operations. ES consists
of unregulated wholesale and retail energy operations, as well as energy management services. CEV consists of capital investments
in clean energy projects. S&T consists of operations and 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:
S&T incurred a net loss of $67.8M during fiscal 2021, which is not shown clearly in the above graph.
Assets composition by reporting segment and other business operations at September 30, are as follows:
2023
2022
Page 5
($ in Thousands)$264,724$274,922$117,890$131,414$140,124$107,375$44,458$39,403$16,789$78,848$69,650$58,957$13,154$26,598NJNGCEVESS&THSO202320222021$0$20,000$40,000$60,000$80,000$100,000$120,000$140,000$160,000$180,000$200,000$220,000$240,000$260,000$280,000$300,000NJNG 64%CEV 16%ES 2%S&T 15%HSO 3%NJNG 62%CEV 15%ES 5%S&T 15%HSO 3%
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
Management uses NFE, a non-GAAP financial measure, when evaluating its 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. ES economically hedges its natural gas inventory with financial
derivative instruments and calculates the related tax effect based on the statutory rate. NFE also excludes certain transactions
associated with equity method investments, including impairment charges, which are non-cash charges, and return of capital in
excess of the carrying value of our investment. These are considered unusual in nature and occur infrequently and are not
indicative of the Company’s performance for its ongoing operations. Included in the tax effects are current and deferred income tax
expense corresponding with the components of NFE.
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)
Net income
Add:
Unrealized (gain) loss on derivative instruments and related transactions
Tax effect
Effects of economic hedging related to natural gas inventory
Tax effect
(Gain on) impairment of equity method investment
Tax effect
NFE
Basic earnings per share
Add:
2023
2022
$ 264,724 $ 274,922 $ 117,890
2021
(38,081)
9,050
34,699
(8,246)
(300)
(19)
(59,906)
14,248
19,939
(4,738)
(5,521)
1,377
54,203
(12,887)
(42,405)
10,078
92,000
(11,167)
$ 261,827 $ 240,321 $ 207,712
$
1.23
2.73 $
2.86 $
Unrealized (gain) loss on derivative instruments and related transactions
Tax effect
Effects of economic hedging related to natural gas inventory
Tax effect
(Gain on) impairment of equity method investment
Tax effect
Basic NFE per share
(0.39)
0.09
0.36
(0.09)
—
—
2.70 $
(0.62)
0.15
0.21
(0.05)
(0.06)
0.01
2.50 $
0.56
(0.13)
(0.44)
0.10
0.96
(0.12)
2.16
$
NFE by reporting segment and other business operations for the fiscal years ended September 30, are as follows:
Page 6
($ in Thousands)$240,321$207,712$261,827$131,414$140,124$107,375$44,458$39,403$16,789$68,517$39,121$71,117$12,835$22,454$13,046NJNGCEVESS&THSO202320222021$0$25,000$50,000$75,000$100,000$125,000$150,000$175,000$200,000$225,000$250,000$275,000$300,000
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
Natural Gas Distribution
General
NJNG consists of regulated utility operations that provide natural gas service to approximately 576,000 customers.
NJNG’s service territory includes Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex counties in New Jersey. It
encompasses 1,516 square miles, covering 110 municipalities with an estimated population of 1.5 million people. It is primarily
suburban, highlighted by approximately 100 miles of New Jersey coastline. It is in close proximity to New York City,
Philadelphia and the metropolitan areas of northern New Jersey, and is accessible through a network of major roadways and
mass transportation.
NJNG’s business is subject to various risks, such as those associated with adverse economic conditions, which can
negatively impact customer growth and operating and financing costs; fluctuations in commodity prices, which can impact
customer usage; certain regulatory actions; and environmental remediation. It is often difficult to predict the impact of trends
associated with these risks. NJNG employs strategies to pursue customer conversions from other fuel sources and monitor new
construction markets through contact with developers, utilize incentive programs through BPU-approved mechanisms to reduce
natural gas costs, pursue rate and other regulatory strategies designed to stabilize and decouple gross margin, and work actively
with consultants and the NJDEP to manage expectations related to its obligations associated with its former MGP sites.
Operating Revenues/Throughput
For the fiscal years ended September 30, operating revenues and throughput by customer class for NJNG are as follows:
($ in thousands)
Residential
Commercial and other
Firm transportation
Total residential and commercial
Interruptible/off-tariff agreements/other
Total system
BGSS incentive programs (1)
Total
Bcf
2023
Operating
Revenue
$ 643,756
137,343
79,537
860,636
9,996
870,632
142,001
43.4
8.4
12.1
63.9
29.5
93.4
34.9
$ 1,012,633 128.3
2022
2021
Bcf
Operating
Revenue
$ 598,433
140,727
80,915
820,075
9,740
829,815
298,952
45.5
8.7
13.0
67.2
32.4
99.6
44.5
$ 1,128,767 144.1
Bcf
Operating
Revenue
$ 484,407
103,341
69,353
657,101
7,239
664,340
67,456
46.2
8.6
13.7
68.5
22.9
91.4
20.8
$ 731,796 112.2
(1) Does not include 37.7, 50.7 and 80.5 Bcf for the capacity release program and related amounts of approximately $0.9M, $0.7M and $3.1M, which are
recorded as a reduction of natural gas purchases on the Consolidated Statements of Operations during fiscal 2023, 2022 and 2021, respectively.
NJNG added 8,800 and 7,808 new customers during fiscal 2023 and 2022, respectively. NJNG expects its annual
customer growth rate to be approximately 1.9%. This anticipated customer growth represents approximately $8.5M in new
annual Utility Gross Margin, a non-GAAP financial measure, as calculated under NJNG’s current CIP tariff. For a
reconciliation of Utility Gross Margin to gross margin see Item 7. Management’s Discussion and Analysis of Financial
Condition and Results of Operations-Natural Gas Distribution.
In fiscal 2023, no single customer represented more than 10% 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. 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.
CIP, a mechanism authorized by the BPU, stabilizes NJNG’s Utility Gross Margin, regardless of variations in weather. In
addition, 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. The BPU approved the continuation
of the CIP program with no expiration date.
Page 7
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
Concurrent with its annual BGSS filing, NJNG files for an annual review of its CIP, at which time it can request rate
changes, as appropriate. For additional information regarding 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.
Natural Gas Supply
Firm Natural Gas Supplies
In fiscal 2023, NJNG purchased natural gas from approximately 58 suppliers under contracts ranging from one day to
seven months and purchased over 10% of its natural gas from two suppliers. NJNG believes the loss of either of these suppliers
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 11 citygate stations located in Burlington, 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
Transcontinental Gas Pipe Line Corp.
Texas Eastern Transmission, L.P.
Columbia Gas Transmission Corp.
Tennessee Gas Pipeline Co.
Algonquin Gas Transmission
Total
Dths (1)
332,531
383,588
50,000
25,166
12,000
803,285
Expiration
Various dates between 2024 and 2033
Various dates between 2024 and 2025
Various dates between 2024 and 2030
Various dates between 2028 and 2029
2025
(1) Numbers are shown net of any capacity release contracted amounts.
Eastern Gas Transmission and Storage, Inc., Tennessee Gas Pipeline Co., Transcontinental Gas Pipe Line Corp. and
Adelphia provide NJNG upstream firm contract transportation service and supply 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
Texas Eastern Transmission, L.P.
Transcontinental Gas Pipe Line Corp.
Total
Dths
94,557
8,384
102,941
Expiration
2025
2028
NJNG also has upstream storage contracts. The maximum daily deliverability and contract expiration dates are as
follows:
Company
Eastern Gas Transmission and Storage
Steckman Ridge, L.P.
Stagecoach Pipeline & Storage Company LLC
Total
Dths
286,829
38,000
25,337
350,166
Expiration
Various dates between 2024 and 2026
2025
2028
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 customer demand for natural gas within its service territory.
Citygate Supplies from ES
NJNG has one AMA with ES. NJNG and ES have an agreement where NJNG releases 7,150 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
Page 8
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
capacity and 1.6 million Dths of Stagecoach Pipeline & Storage Company LLC storage capacity to ES through March 31, 2024.
NJNG can call upon a supply of up to 14,300 Dths/day delivered to NJNG’s TETCO citygate through March 31, 2024. ES
manages the storage inventory and NJNG can call on that storage supply as needed at NJNG’s Tennessee citygate or storage
point.
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% 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 5% 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.
Federal
FERC regulates rates charged by interstate pipeline companies for the transportation and storage of natural gas. This may
affect 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% 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.
Page 9
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
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, 2023, NJNG had 15,457 residential and
8,033 commercial and industrial customers utilizing the transportation service.
Clean Energy Ventures
CEV invests in, owns and operates clean energy projects, including commercial and residential solar installations located
in six states including New Jersey, Rhode Island, New York, Connecticut, Michigan and Indiana.
As of September 30, 2023, CEV has approximately 468.8 MW of solar capacity in service, including a combination of
residential and commercial net-metered and grid-connected solar systems.
As part of its solar investment portfolio, CEV operates a residential and small commercial solar program, The Sunlight
Advantage®, that provides qualifying homeowners and small business owners with the opportunity to have a solar system
installed at their home or place of business with no installation or maintenance expenses. CEV owns, operates and maintains the
system over the life of the lease in exchange for monthly lease payments. The program is operated by CEV 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. CEV competes on price, quality
and brand reputation, leveraging its partner network and customer referrals.
CEV’s 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 eighth 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. CEV 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.
In July 2021, the BPU approved the first portion of the solar successor program for net-metered projects under 5 MWs.
The new program opened to new applications on August 28, 2021. Incentives are structured as a 15-year fixed incentive
ranging from $85 to $130/MWh depending on market segment, project siting and size. The second phase of the successor
program, the CSI Program, was established on December 7, 2022. The CSI program was designed to encourage grid scale solar
generation with a goal of incentivizing development of at least 300 MW of solar annually until 2026. Solicitations take place
annually, and all projects that meet pre-qualification requirements will compete on price only. The next solicitation will open on
November 27, 2023, and will close to bids on February 29, 2024.
CEV is subject to various risks including those associated with adverse federal and state legislation and regulatory
policies, electric grid connection, supply chain and/or construction delays that can impact the timing or eligibility of tax
incentives, technological changes and the future market of RECs. See Item 1A. Risk Factors for additional information
regarding these risks.
Energy Services
ES consists of unregulated wholesale and retail natural gas operations and provides producer and asset management
services to a diverse customer base across North America. ES 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. ES’s activities are conducted in the market areas in which it has strong expertise,
including the U.S. and Canada. ES 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. ES’s
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.
Page 10
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
While focusing on maintaining a low-risk operating and counterparty credit profile, ES’s 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;
• 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 an effort to deliver more predictable earnings contributions, reduce earnings volatility and monetize the value of its
natural gas transportation portfolio, ES entered into a series of AMAs in December 2020 with an investment grade public utility
to release pipeline capacity associated with certain natural gas transportation contracts. The AMAs include a series of initial and
permanent releases, which commenced in November 2021. NJR will receive a total of approximately $260M in cash from fiscal
2022 through fiscal 2024 and $34M per year from fiscal 2025 through fiscal 2031 under the agreements.
During fiscal 2023, ES did not purchase over 10% of its natural gas from any one supplier.
Transportation and Natural Gas Storage Transactions
ES 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, ES may hedge these price
differentials through the use of financial instruments. In addition, ES 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 ES
to capture geographic pricing differences across various regions, as delivered natural gas prices may change favorably as a
result of market conditions. ES 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.
ES also engages in park and loan transactions with storage and pipeline operators, where ES 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, ES evaluates the economics of the transaction to determine if it can capture
pricing differentials in the marketplace and generate Financial Margin. ES evaluates deal attributes such as fixed fees and
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, ES may enter into the transaction and hedge with natural
gas futures contracts, thereby locking in Financial Margin.
ES 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 2023 and 2022, ES managed and sold 150.4 Bcf and 231.1 Bcf of natural
gas, respectively. In addition, as of September 30, 2023 and 2022, ES had 14.6 Bcf or $24.5M of natural gas in storage and 10.8
Bcf or $82.5M of natural gas in storage, respectively.
Weather/Seasonality
ES 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, ES can be subject to variations in earnings and working capital throughout the year as a result of
changes in weather.
Page 11
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
Volatility
ES’s 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 ES’s Financial Margin, which, as described below, is generated from the optimization of
transportation and storage assets. With its focus on risk management, ES continues to diversify its revenue stream by
identifying new growth opportunities in producer and asset management services. ES monitors changing market dynamics and
strategically adjusts its portfolio of transportation and storage assets, which currently includes an average of approximately 21.8
Bcf of firm storage and 0.6 Bcf 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, ES 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. ES views Financial Margin, a non-GAAP financial measure, as
a key internal financial metric. For additional information regarding Financial Margin, see Item 7. Management’s Discussion
and Analysis of Financial Condition and Results of Operations-Energy Services.
Risk Management
In conducting its business, ES mitigates risk by following formal risk management guidelines, including transaction
limits, segregation of duties and formal contract and credit review approval processes. ES 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
S&T includes investments in FERC-regulated interstate natural gas storage and transportation assets and is comprised of
the following subsidiaries:
• NJR Midstream Company owns and operates Leaf River, a 32.2M Dth salt dome natural gas facility, located in
southeastern Mississippi, and the FERC-regulated Adelphia, which owns and operates an 84-mile pipeline in
southeastern Pennsylvania. NJR Midstream Company also holds a 20% equity method investment in PennEast,
whose project was cancelled in September 2021 and subsequently is dissolving the partnership; and
• NJR Steckman Ridge Storage Company holds our 50% equity method 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.
OTHER BUSINESS OPERATIONS
Home Services and Other
HSO operations consist primarily of the following unregulated affiliates:
• NJR Home Services, Inc., which provides heating, ventilation and cooling service, sales and installation of appliances
to approximately 101,500 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.
Page 12
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
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 $137.3M to $201.5M.
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 2023. 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,
2023, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $169.4M 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, 2023, the Company and our subsidiaries employed 1,350 employees compared with 1,288
employees as of September 30, 2022. Of the total number of employees, NJNG had 509 and 498 and NJRHS had 117 and 113
Union or Represented employees as of September 30, 2023 and 2022, 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. NJNG and the Union are in active negotiations to extend the collective bargaining agreement, which is
scheduled to expire on December 7, 2023. The collective bargaining agreement between NJRHS and the Union is scheduled to
expire April 2, 2024. 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.
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 talent for key positions. To promote a collaborative and rewarding work environment and
support the communities we serve, NJR sponsors numerous charitable, philanthropic and social awareness programs.
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 employees. 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, DEI and employee engagement. Moreover, DEI and employee engagement are integral to
NJR’s vision, strategy and business success. Fostering an environment that values DEI and ethics helps create an organization
Page 13
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
that is able to embrace, leverage and respect the differences of employees, customers and the communities where we live, work
and serve. We are proud of the strides we have made in furthering our DEI strategy and increasing employee engagement. NJR
is committed to this journey and knows our success makes us stronger as a company and community. Complementing our
efforts are a DEI Council and our seven employee-led Business Resource Groups, cross-functional teams of employees whose
core mission is to advance their own professional development and cultivate deeper connections with co-workers and
communities.
NJR periodically 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 most recent
employee survey.
NJR 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 is innovative, talent- and team-focused and inclusive.
Management regularly reports to the LDCC of the Board of Directors on human capital management topics, including
corporate culture, DEI, employee development, compensation and benefits. The LDCC maintains oversight of matters related to
human capital management, including talent retention, development and succession planning, and the Board of Directors
provides input on important decisions in each of these areas.
NJR conducts an annual employee feedback survey, which is reviewed by the LDCC, designed to help the Company
measure overall employee engagement. The feedback employees provide through the survey helps NJR evaluate the
Company’s culture and the employee experience and monitor its current practices for potential areas of improvement.
Employee Benefits
The LDCC believes employee benefits are an essential component of the Company’s competitive total rewards package.
These benefits are designed to attract and retain our employees and include medical, vision and dental insurance, short- and
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 matches 85% of the first 6% of compensation contributed by the employee into the 401(k) Plan,
subject to the Internal Revenue Code and NJR’s 401(k) Plan limits. Additionally, for employees who are not eligible to
participate in the defined benefit plans, NJR annually contributes between 3.5% and 4.5% 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.
The following documents are available free of charge on our website at https://investor.njresources.com/governance/
governance-documents/default.aspx
NJR Code of Conduct;
•
Amended and Restated Bylaws;
•
•
Corporate Governance Guidelines;
• Wholesale Trading Code of Conduct;
•
Charters of the following Board of Directors Committees: Audit, Nominating/Corporate Governance and
Leadership Development and Compensation;
Audit Complaint Procedure;
Communicating with Non-Management Directors Procedure;
Statement of Policy with Respect to Related Person Transactions; and
Legal Procedure.
•
•
•
•
In Part III of this Form 10-K, we incorporate certain information by reference from our Proxy Statement for our 2023
Annual Meeting of Shareowners. We expect to file the Proxy Statement with the SEC on or about December 14, 2023. We will
make it available on our website as soon as reasonably possible following the filing date. Please refer to the Proxy Statement
when it is available.
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New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
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
Stephen D. Westhoven
Age
55
Officer
since Business experience during last five years
2004
Roberto Bel
50
2019
Patrick J. Migliaccio
Amy Cradic
49
52
2013
2018
Richard Reich
48
2016
Lori DelGiudice
48
2023
Jacqueline K. Shea
Stephen M. Skrocki
59
47
2016
President and Chief Executive Officer (October 2019 - present)
President and Chief Operating Officer (October 2018 - September 2019)
Senior Vice President and Chief Financial Officer (January 2022 - present)
Vice President, Treasury and Investor Relations (April 2019 - December 2021)
Assistant Treasurer at Refinitiv (October 2018 - March 2019)
Senior Vice President and Chief Operating Officer (January 2022 - present)
Senior Vice President and Chief Financial Officer (January 2016 - December 2021)
Senior Vice President and Chief Operating Officer of Nonutility 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)
Senior Vice President and General Counsel (June 2022 - present)
Senior Vice President, General Counsel and Corporate Secretary (September 2021 - June
2022)
Corporate Secretary and Assistant General Counsel (January 2016 - September 2021)
Senior Vice President, Human Resources (November 2022 - present)
Vice President of Human Resources for Honeywell Advanced Materials (September 2017 -
October 2022)
Senior Vice President and Chief Information Officer (January 2023 - present)
Vice President and Chief Information Officer (June 2016 - December 2022)
2023 Corporate Controller (Principal Accounting Officer) (January 2023 - present)
Corporate Controller (January 2021 - December 2022)
Assistant Corporate Controller (March 2017 - January 2021)
ITEM 1A. RISK FACTORS
When considering any investment in our securities, investors should consider the following risk factors, as well as the
information contained under the caption “Information Concerning Forward-Looking Statements,” in analyzing our present and
future business performance. While this list is not exhaustive, management also places no priority or likelihood based on their
descriptions or order of presentation. Listed below, not necessarily in order of importance or probability of occurrence, are the
most significant risk factors applicable to us. Unless indicated otherwise or the content requires otherwise, references below to
“we,” “us,” and “our” should be read to refer to the Company and its subsidiaries and affiliates.
Risks Related to Our Business Operations
Our investments in solar energy projects are subject to substantial risks and uncertainties. Our investments in
commercial and residential solar energy projects are dependent, in part, upon current state regulatory incentives and federal tax
credits in order for the projects to be economically viable. Our return on investment for these solar projects is based
substantially on our eligibility for ITCs and the future market value of SRECs that are traded in a competitive marketplace in
the State of New Jersey. These projects face the risk that the current state regulatory programs and tax laws may expire or be
adversely modified. A sustained decrease in the value of SRECs could negatively impact the return on our investments and
could impair our portfolio of solar assets.
In addition, there are risks associated with our ability to execute on our investment strategy of clean energy projects,
which includes our ability to develop and manage such projects profitably. These include logistical risks and potential delays
related to construction, permitting and regulatory approvals (including any approvals by the BPU required pursuant to solar
energy legislation in the State of New Jersey, and similar approvals required by the other states where our solar projects are
located); electric grid interconnection delays associated with the PJM Interconnection, LLC queue reform process; and the
operational risk that the projects in service will not perform according to expectations due to equipment failure, suboptimal
weather conditions or other economic factors beyond our control. All of the aforementioned risks could reduce the availability
of viable solar energy projects for development. Furthermore, at the development or acquisition stage, our ability to predict
actual performance results may be hindered or inaccurate and the projects may not perform as predicted.
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New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Actions or limitations to address concerns over long-term climate change, both globally and within our utilities'
service areas, may affect our operations and financial performance. Legislative, regulatory and advocacy efforts at the local,
state and national levels concerning climate change and other environmental issues could have significant impacts on our
operations. The natural gas utility industry may be affected by proposals to curb greenhouse gas and other air emissions.
Various regulatory and legislative proposals have been made to limit or further restrict byproducts of combustion, including
byproducts resulting from the use of natural gas by our customers. In addition, regionally, a number of regulatory and
legislative initiatives have been passed that are designed to limit greenhouse gas emissions and increase the use of renewable
sources of energy, such as the ban of natural gas equipment in new construction in New York. In addition, regulatory and
legislative initiatives may restrict customers’ access to natural gas and/or require or limit natural gas infrastructure in buildings.
Other initiatives may seek to promote social interests expressed as energy equity, environmental justice or similar frameworks.
Any such legislation could direct and/or restrict the operation and raise the costs of our energy delivery infrastructure as well as
the distribution of natural gas to our customers.
Uncertainties associated with our pipeline of projects could adversely affect our business, results of operations,
financial condition and cash flows. Business development projects involve many risks. We are currently engaged in business
development projects, including projects in various stages of development tied to decarbonization efforts. Timely completion of
our projects is subject to certain risks, including those related to regulatory proceedings regarding permitting and adverse
outcomes from legal challenges related to the projects’ authorizations from federal and state regulatory agencies. We could also
experience issues such as: technological challenges; ineffective scalability; failure to achieve expected outcomes; unsuccessful
business models; startup and construction delays; construction cost overruns; disputes with contractors; the inability to
negotiate acceptable agreements such as rights-of-way, easements, construction, gas supply or other material contracts; changes
in customer demand, perception or commitment; public opposition to projects; marketing risk and changes in market regulation,
behavior or prices; market volatility or unavailability, including markets for RNG and its associated attributes or other
environmental attributes; the inability to receive expected tax or regulatory treatment; and operating cost increases.
Additionally, we may be unable to finance our business development projects at acceptable costs or within a scheduled time
frame necessary for completing the project. Any of the foregoing risks, if realized, could result in business development efforts
failing to produce expected financial results and the project investment becoming impaired, and such failure or impairment
could have an adverse effect on our business, results of operations, financial condition and cash flows.
ES’s earnings and cash flows are dependent upon optimization of its physical assets. ES’s earnings and cash flows are
based, in part, on its ability to optimize its portfolio of contractually based natural gas storage and pipeline assets. The
optimization strategy involves utilizing its physical assets to take advantage of differences in natural gas prices between
geographic locations and/or time periods. Any change among various pricing points could affect these differentials. In addition,
significant increases in the supply of natural gas in ES’s market areas, including as a result of increased production along the
Marcellus Shale, can reduce ES’s ability to take advantage of pricing fluctuations in the future. Changes in pricing dynamics
and supply could have an adverse impact on ES’s optimization activities, earnings and cash flows. ES incurs fixed demand fees
to acquire its contractual rights to transportation and storage assets. Should commodity prices at various locations or time
periods change in such a way that ES is not able to recoup these costs from its customers, the cash flows and earnings at ES,
and ultimately the Company, could be adversely impacted.
NJNG and ES rely on storage, transportation assets and suppliers, which they do not own or control, to deliver natural
gas. NJNG and ES depend on natural gas pipelines and other transportation and storage facilities owned and operated by third
parties to deliver natural gas to wholesale and retail markets and to provide retail energy services to customers. Their ability to
provide natural gas for their present and projected sales will depend upon their suppliers’ ability to obtain and deliver additional
supplies of natural gas, as well as NJNG’s ability to acquire supplies directly from new sources. Factors beyond the control of
NJNG, its suppliers and the independent suppliers that have obligations to provide natural gas to certain NJNG customers may
affect NJNG’s ability to deliver such supplies. These factors include other parties’ control over the drilling of new wells and the
facilities to transport natural gas to NJNG’s citygate stations; development of additional interstate pipeline infrastructure;
availability of supply sources; third-party pipelines or other midstream facilities interconnected to our gathering or
transportation system, such as the TETCO or Transcontinental Pipeline, becoming partially or fully unavailable; competition for
the acquisition of natural gas; priority allocations; impact of severe weather disruptions to natural gas supplies; and the
regulatory and pricing policies of federal and state regulatory agencies, as well as the availability of Canadian reserves for
export to the U.S. Energy deregulation legislation may increase competition among natural gas utilities and impact the
quantities of natural gas requirements needed for sales service. ES also relies on a firm supply source to meet its energy
management obligations to its customers. If supply, transportation or storage is disrupted, including for reasons of force
majeure, the ability of NJNG and ES to sell and deliver their products and services may be hindered. As a result, they may be
responsible for damages incurred by their customers, such as the additional cost of acquiring alternative supply at then-current
Page 16
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
market rates. Particularly for ES, these conditions could have a material impact on our financial condition, results of operations
and cash flows.
Failure to attract and retain an appropriately qualified employee workforce could adversely affect operations. Our
ability to implement our business strategy and serve our customers is dependent upon our continuing ability to attract and retain
talented professionals and a technically skilled workforce, and being able to transfer the knowledge and expertise of our
workforce to new employees as our aging employees retire. Failure to hire and adequately train replacement employees,
including the transfer of significant internal historical knowledge and expertise to the new employees, or the future availability
and cost of contract labor could adversely affect the ability to manage and operate our business. NJNG and the Union are in
active negotiations to extend the collective bargaining agreement, which is scheduled to expire on December 7, 2023. The
collective bargaining agreement between NJRHS and the Union is scheduled to expire April 2, 2024. Disputes with the Union
over terms and conditions of the agreements could result in instability in our labor relationship and work stoppages that could
impair the timely delivery of natural gas and other services from our utility and Home Services business, which could strain
relationships with customers and state regulators and cause a loss of revenues that could adversely affect our results of
operations. Our collective bargaining agreements may also increase the cost of employing NJNG and Home Services
workforce, affect our ability to continue offering market-based salaries and employee benefits, limit our flexibility in dealing
with our workforce and limit our ability to change work rules and practices and implement other efficiency-related
improvements to successfully compete in today’s challenging marketplace.
Our success depends upon our ability to attract, effectively transition, motivate and retain key employees and identify and
develop talent to succeed senior management. We depend on senior executive officers and other key personnel to develop,
implement and execute on our overall business strategy. The inability to recruit and retain or effectively transition key
personnel or the unexpected loss of key personnel may adversely affect our operations.
We may be unable to obtain governmental approvals, property rights and/or financing for the construction,
development and operation of our proposed energy investments and projects in a timely manner or at all. Construction,
development and operation of energy investments, such as Leaf River and other natural gas storage facilities, NJNG
infrastructure improvements, pipeline transportation systems, such as the Adelphia pipeline project, and solar energy projects,
are subject to federal and state regulatory oversight and require certain property rights, such as easements and rights-of-way
from public and private property owners, as well as regulatory approvals, including environmental and other permits and
licenses for such facilities and systems. We or our joint venture partnerships may be unable to obtain, in a cost-efficient or
timely manner, all such needed property rights, permits and licenses to construct and develop our energy facilities and systems.
Successful financing of our energy investments requires participation by willing financial institutions and lenders, as well as
acquisition of capital at reasonable interest rates. If we do not obtain the necessary regulatory approvals or property rights, or if
we are unable to enter into contracts with counterparties at reasonable rates, or obtain financing, our assets or equity method
investments could be impaired. Such impairment could have a materially adverse effect on our financial condition, results of
operations and cash flows.
Weather and weather patterns, including normal seasonal and quarterly fluctuations of weather, as well as extreme
weather events that, individually or in aggregate, may be associated with climate change, could adversely affect our ability to
manage our operational requirements to serve our customers, and ultimately adversely affect our results of operations and
liquidity. NJNG’s business is seasonal, and weather patterns can have a material impact on our financial performance. Demand
for natural gas is often greater in the summer and winter months associated with cooling and heating. Because natural gas is
heavily used for residential and commercial heating, the demand for this product depends heavily upon weather patterns
throughout our market areas, and a significant amount of natural gas revenues are recognized in the first and second quarters
related to the heating season. Accordingly, our operations have historically generated less revenue and income when weather
conditions are milder in the winter and cooler in the summer. Unusually mild winters or cool summers could adversely affect
our results of operations and financial position. In addition, exceptionally hot summer weather or unusually cold winter weather
could add significantly to working capital needs to fund higher than normal supply purchases to meet customer demand for
natural gas. While we believe the CIP mitigates the impact of weather variations on NJNG’s Utility Gross Margin, severe
weather conditions may have an impact on the ability of suppliers and pipelines to deliver the natural gas to NJNG, which can
negatively affect our earnings. The CIP does not mitigate the impact of severe weather conditions on our cash flows.
Future results at ES are subject to volatility in the natural gas market due to weather. Variations in weather may affect
earnings and working capital needs throughout the year. During periods of milder temperatures, demand and volatility in the
natural gas market may decrease, which can negatively impact ES’s earnings and cash flows.
Page 17
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Severe weather impacts, including, but not limited to, hurricanes, thunderstorms, high winds, microbursts, fires,
tornadoes, blizzards and snow or ice storms, can disrupt energy generation, transmission and distribution. Extreme weather
conditions, especially those of prolonged duration, create high energy demand on our own and/or other systems and increase the
risk that we may be unable to reliably serve customers. Risk of losing gas supply during extreme weather carries significant
consequences, as without our services our customers may be subjected to dire circumstances. Additionally, extreme weather
conditions may cause the breakdown of or damage to equipment essential to the operation of our assets, and could also raise
market prices as we buy short-term energy to serve our own system. To the extent the frequency of extreme weather events
increases, this could increase our cost of providing service. In addition, we may not recover all costs related to mitigating these
physical and financial risks.
There is also a concern that the physical risks of climate change could include changes in weather conditions, such as
changes in the amount or type of precipitation and extreme weather events. Climate change and the costs that may be associated
with its impacts have the potential to affect our business in many ways, including increasing the cost incurred in providing
natural gas, impacting the demand for and consumption of natural gas (due to change in both costs and weather patterns) and
affecting the economic health of the regions in which we operate.
We may be adversely impacted by natural disasters, pandemic illness, war or terrorist activities and other extreme
events to which we may be unable to promptly respond. Local or national natural disasters, pandemic illness, actual or
threatened acts of war or terrorist activities, including the political and economic disruption and uncertainty related to Russia’s
military invasion of Ukraine and the Israel-Hamas war, catastrophic failure of the interstate pipeline system and other extreme
events are a threat to our assets and operations. Companies in our industry that are located in our service territory may face a
heightened risk due to exposure to acts of terrorism that could target or impact our natural gas distribution, transmission and
storage facilities and disrupt our operations and ability to meet customer requirements. In addition, the threat of terrorist
activities could lead to increased economic instability and volatility in the price of natural gas that could affect our operations.
Natural disasters, political unrest or actual or threatened terrorist activities may also disrupt capital markets and our ability to
raise capital or may impact our suppliers or our customers directly.
A local disaster or pandemic illness could result in part of our workforce being unable to operate or maintain our
infrastructure or perform other tasks necessary to conduct our business. In addition, these risks could result in loss of human
life, significant damage to property, environmental damage, impairment of our operations and substantial loss to the Company.
Such uncertain conditions may also impact the ability of certain customers to pay for services, which could affect the
collectability and recognition of our revenues and adversely affect our financial results. Our regulators may not allow us to
recover from our customers part or all of the increased cost related to the foregoing events, which could negatively affect our
financial condition, results of operations and cash flows.
A slow or inadequate response to events that could cause business interruption may have an adverse impact on operations
and earnings. We may be unable to obtain sufficient insurance (or such insurance may be costly) to cover all risks associated
with local and national disasters, pandemic illness, terrorist activities, catastrophic failure of the interstate pipeline system and
other events, which could increase the risk that an event adversely affects our financial condition, results of operations and cash
flows.
Risks Related to Technologies
Cyberattacks, ransomware, terrorism, other malicious acts against, or failure of, information technology systems
could adversely affect our business operations, financial condition and results of operations. We continue to place ever-
greater reliance on technological tools that support our business operations and corporate functions, including tools that help us
manage our natural gas distribution and energy trading operations and infrastructure. The failure of, or security breaches related
to, these technologies could materially adversely affect our business operations, financial position, results of operations and
cash flows.
We rely on information technology to manage our natural gas distribution and storage, energy trading and other corporate
operations; maintain customer, employee, Company and vendor data; and prepare our financial statements and perform other
critical business processes. This technology may fail due to cyberattack, physical disruption, design and implementation defects
or human error. Disruption or failure of business operations and information technology systems could harm our facilities or
otherwise adversely impact our ability to safely deliver natural gas to our customers, serve our customers effectively or manage
our assets. Additionally, an attack on, or failure of, information technology systems could result in the unauthorized release of
customer, employee or other confidential or sensitive data. Cyberattacks, ransomware, terrorism, increased use of artificial
intelligence technologies or other malicious acts could damage, destroy or disrupt these systems for an extended period of time.
The energy sector, including natural gas utility companies has become the subject of cyberattacks with increased frequency.
Page 18
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Additionally, the facilities and systems of clients, suppliers and third-party service providers could be vulnerable to the same
cyber or terrorism risks as our facilities and systems, and such third-party systems may be interconnected to our systems both
physically and technologically. Therefore, an event caused by cyberattacks, ransomware or other malicious acts at an
interconnected third party could impact our business and facilities. Any failure or unexpected or unauthorized use of technology
systems could result in the unavailability of such systems, and could result in a loss of operating revenues, an increase in
operating expenses and costs to repair or replace damaged assets. Any of the above could also result in the loss or release of
confidential customer and/or employee information or other proprietary data that could adversely affect our reputation and
competitiveness, could result in costly litigation and negatively impact our results of operations. These cyberattacks have
become more common and sophisticated and, as such, we could be required to incur costs to strengthen our systems and
respond to emerging concerns.
There is no guarantee that redundancies built into our networks and technology, or the procedures we have implemented
to protect against cyberattacks and other unauthorized access to secured data, will guarantee protection against all failures of
technology or security breaches. Furthermore, despite our efforts to investigate, improve and remediate the capability and
performance of our information technology system, we may not be able to discover all weaknesses, breaches and
vulnerabilities, and failure to do so may expose us to higher risk of data loss and adversely affect our business operations and
results of operations.
Failure to keep pace with technological change may limit customer growth and have an adverse effect on our
operations. Advances in technology and changes in laws or regulations are reducing the cost of alternative methods of
producing energy. In addition, customers are increasingly expecting enhanced communications regarding their electric and
natural gas services, which, in some cases, may involve additional investments in technology. New technologies, including, but
not limited to, cloud computing and generative artificial intelligence, may require us to make significant expenditures to remain
competitive and may result in the obsolescence of certain of our operating assets.
Our future success will depend, in part, on our ability to anticipate and successfully adapt to technological changes and to
offer services that meet customer demand. Failure to adapt to advances in technology and manage the related costs could make
us less competitive and negatively impact our financial condition, results of operations and cash flows.
Risks Related to Regulations and Litigation
We are subject to governmental regulation. Compliance with current and future regulatory requirements and
procurement of necessary approvals, permits and certificates may result in substantial costs to us. We are subject to
substantial regulation from federal, state and local authorities. We are required to comply with numerous laws and regulations
and to obtain numerous authorizations, permits, approvals and certificates from governmental agencies. These agencies regulate
various aspects of our business, including customer rates, services, construction and natural gas pipeline operations.
FERC has regulatory authority over some of our operations, including sales of natural gas in the wholesale and retail
markets and the purchase and sale of interstate pipeline and storage capacity, including Steckman Ridge, Leaf River and
Adelphia. Any Congressional legislation or agency regulation that would alter these or other similar statutory and regulatory
structures in a way to significantly raise costs that could not be recovered in rates from customers, that would reduce the
availability of supply or capacity or that would reduce our competitiveness could negatively impact our earnings. In addition,
changes in and compliance with laws such as the Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011 could
increase federal regulatory oversight and administrative costs that may not be recovered in rates from customers, which could
have an adverse effect on our earnings.
We cannot predict the impact of any future revisions or changes in interpretations of existing regulations or the adoption
of new laws and applicable regulations. Changes in regulations or the imposition of additional regulations could influence our
operating environment and may result in substantial costs to us.
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New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Our regulated operations are subject to certain operating risks incidental to handling, storing, transporting and
providing customers with natural gas. Our regulated operations are subject to all operating hazards and risks incidental to
handling, storing, transporting and providing customers with natural gas, including our natural gas vehicle refueling stations
and LNG facilities. These risks include catastrophic failure of the interstate pipeline system, explosions, pollution, release of
toxic substances, fires, storms, safety issues and other adverse weather conditions and hazards, each of which could result in
damage to or destruction of facilities or damage to persons and property. We could suffer substantial losses should any of these
events occur. Although we maintain insurance coverage, insurance may not be sufficient to cover all material expenses related
to these risks, and such insurance may be costly.
We are involved in legal or administrative proceedings before various courts and governmental bodies that could
adversely affect our results of operations, cash flows and financial condition. In the ordinary conduct of business, we are
involved in legal or administrative proceedings before various courts and governmental bodies with respect to general claims,
rates, permitting, taxes, environmental issues, natural gas cost prudence reviews and other matters. Adverse decisions regarding
these matters, to the extent they require us to make payments in excess of amounts provided for in our financial statements or
are not covered by insurance or indemnity rights, could adversely affect our results of operations, cash flows and financial
condition.
Our costs of compliance with present and future environmental laws are significant and could adversely affect our
cash flows and profitability. Our operations are subject to federal, state and local environmental statutes, rules and regulations
relating to air quality, water quality, waste management, natural resources and site remediation. Compliance with these laws
and regulations may require us to expend financial resources to, among other things, conduct site remediation and perform
environmental monitoring. If we fail to comply with applicable environmental laws and regulations, even if we are unable to do
so due to factors beyond our control, we may be subject to civil liabilities or criminal penalties and may be required to incur
expenditures to come into compliance. Additionally, any alleged violations of environmental laws and regulations may require
us to expend resources in our defense against alleged violations.
Furthermore, the U.S. Congress has for some time been considering various forms of climate change legislation. In
addition, in July 2019, the State of New Jersey amended the GWRA, which targets 80% reduction in greenhouse gas emissions
below 2006 levels economy-wide by 2050. In January 2020, Governor Murphy released the EMP confirming his commitment
to achieve 100% clean energy by 2050, and the GWRA mandate of reducing state greenhouse gas emissions. The EMP
addressed New Jersey’s energy system, including electric generation, transportation and buildings, and their associated
greenhouse gas emissions and related air pollutants. The EMP defines 100% clean energy by 2050 to mean 100% carbon-
neutral electric generation and maximum electrification of the transportation and building sectors, which are the greatest carbon
emission-producing sectors in the state, to meet or exceed the GWRA emissions reductions by 2050. Our goals, to reduce our
New Jersey operational emissions by 60% from 2006 levels by 2030 and to achieve net-zero carbon emissions from our New
Jersey operations by 2050, may require additional technological, legislative and regulatory developments, the impacts and costs
of which may not be fully known at this time.
While the EMP does not place a moratorium or end date on natural gas hook ups, further legislation or rulemaking that
de-emphasizes the role of natural gas in providing clean, low-cost energy in the state of New Jersey could put upward pressure
on natural gas prices and place customer growth targets at risk. Higher cost levels could impact the competitive position of
natural gas and negatively affect our growth opportunities, cash flows and earnings.
In February 2023, Governor Murphy issued two executive orders that established, or accelerated, previously established
2050 targets for clean-sourced electricity and electric heat pump adoption, with target dates of 2030 or 2035, as applicable. An
additional executive order opened a proceeding to plan for the future of natural gas utilities in New Jersey. We are unable to
predict the outcomes of these proceedings, but they could have a material impacts on our business, results of operations and
cash flows.
Risks related to regulation could affect the rates we are able to charge, various costs and our profitability. NJNG is
subject to regulation by federal, state and local authorities. These authorities regulate many aspects of NJNG’s distribution and
transmission operations, including construction and maintenance of facilities, operations, safety, tariff rates that NJNG can
charge customers, rates of return, the authorized cost of capital, recovery of pipeline replacement, environmental remediation
costs and relationships with its affiliates. NJNG’s ability to timely construct rate-based assets and obtain rate increases,
including base rate increases, continue its BGSS incentive and CIP programs and maintain its currently authorized rates of
return may be impacted by events, including regulatory or legislative actions. Additionally, in fiscal 2019, NJR began the
process of transitioning away from its enterprise platform, which will no longer receive extended support after 2025. The first
Page 20
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
phase of IT enhancements and upgrades were placed into service in July 2020. The remaining phases of planned upgrades relate
to work order and asset management and customer information systems and experience, which are expected to require
significant capital investment through fiscal year 2024. There can be no assurance that NJNG will be able to obtain rate
increases and continue its BGSS incentive, CIP, RAC, or SAVEGREEN programs and IT upgrades and enhancements or
continue to earn its currently authorized rates of return.
Adelphia is subject to regulation by FERC. FERC regulates many aspects of Adelphia’s transmission operations,
including construction and maintenance of facilities, operations, safety tariff rates that Adelphia can charge customers, rates of
return, the authorized cost of capital, recovery of pipeline replacement and relations with its affiliates. Adelphia’s ability to
obtain rate increases and maintain its currently authorized rates of return may be impacted by events, including regulatory or
legislative actions. There can be no assurance that Adelphia will be able to obtain rate increases or continue to earn its currently
authorized rate of return.
Risks Related to Our Markets
Major changes in the supply and price of natural gas may affect financial results. While NJRES and NJNG expect to
meet customers’ demand for natural gas for the foreseeable future, factors affecting suppliers and other third parties, including
the inability to develop additional interstate pipeline infrastructure, lack of supply sources, increased competition, further
deregulation, transportation costs, possible climate change legislation, energy efficiency mandates or changes in consumer
behaviors, transportation availability and drilling for new natural gas resources, may impact the supply and price of natural gas.
In addition, any significant disruption in the availability of supplies of natural gas could result in increased supply costs, higher
prices for customers and potential supply disruptions to customers.
NJRES and NJNG actively hedge against the fluctuation in the price of natural gas by entering into forward and financial
contracts with third parties. Should these third parties fail to perform, and regulators not allow the pass-through of expended
funds to customers, it may result in a loss that could have a material impact on our financial condition, results of operations and
cash flows.
Supply chain disruptions may adversely affect Company operations. The Company relies on third-party vendors and
manufacturers to supply many of the materials necessary for its operations. Global logistics disruptions have impacted the flow
of materials and restricted global trade flows. Manufacturers are competing for a limited supply of key commodities and
logistical capacity, which has impacted lead times, pricing, supply and demand. Disruptions or delays in receiving materials;
price increases from suppliers or manufacturers; or the inability to source needed materials, which has occurred and could
reoccur, could adversely affect the Company’s results of operations, financial condition and cash flows.
Changes in customer growth may affect earnings and cash flows. NJNG’s ability to increase its Utility Gross Margin is
dependent upon the new construction housing market, as well as the conversion of customers to natural gas from other fuel
sources. During periods of extended economic downturns, prolonged weakness in housing markets or slowdowns in the
conversion market, there could be an adverse impact on NJNG’s Utility Gross Margin, earnings and cash flows. Furthermore,
while our estimates regarding customer growth are based in part upon information from third parties, the estimates have not
been verified by an independent source and are subject to the aforementioned risks and uncertainties, which could cause actual
results to materially deviate from the estimates.
Our economic hedging activities that are designed to protect against commodity and financial market risks, including
the use of derivative contracts in the normal course of our business, may cause fluctuations in reported financial results and
financial losses that negatively impact results of operations and our stock price. We use derivatives, including futures,
forwards, options, swaps and foreign exchange contracts, to manage commodity, financial market and foreign currency risks.
The timing of the recognition of gains or losses associated with our economic hedges in accordance with GAAP does not
always coincide with the gains or losses on the items being hedged. The difference in accounting can result in volatility in
reported results, even though the expected profit margin is essentially unchanged from the dates the transactions were
consummated.
In addition, we could recognize financial losses on these contracts as a result of volatility in the market values of the
underlying commodities or if a counterparty fails to perform under a contract. In the absence of actively quoted market prices
and pricing information from external sources, the valuation of these financial instruments can involve management’s judgment
or use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could adversely
affect the value of the reported fair value of these contracts.
Page 21
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
We are exposed to market risk and may incur losses in our wholesale business. Our transportation and storage portfolios
consist of contracts to transport and store natural gas. The value of our transportation and storage portfolio could be negatively
impacted if the value of these contracts changes in a direction or manner that we do not anticipate. In addition, upon expiration
of these transportation and storage contracts, to the extent that they are renewed or replaced at less favorable terms, our results
of operations and cash flows could be adversely affected.
Inflation and increased natural gas costs could adversely impact our customer base and customer collections and
increase the Company’s level of indebtedness. Inflation has caused, and may continue to cause, increases in certain operating
and capital costs. Our regulated businesses have a process in place to review the adequacy of their rates in relation to the
increasing cost of providing service and the inherent regulatory lag in adjusting those rates. The ability to control expenses is an
important factor that will influence future results.
Rapid increases in the price of purchased gas may cause the Company to experience a significant increase in short-term
debt because it must pay suppliers for gas when it is purchased, which can be significantly in advance of when these costs may
be recovered through the collection from customers and counterparties for gas delivered. Increases in purchased gas costs could
also slow collection efforts as NJNG customers may be more likely to delay the payment of their gas bills, leading to higher-
than-normal accounts receivable. This situation could also result in higher short-term debt levels and increased bad debt
expense.
Risks Related to Acquisition and Investment Strategies
Any acquisitions that we may undertake involve risks and uncertainties. We may not realize the anticipated synergies,
cost savings and growth opportunities as a result of these transactions. The integration of acquisitions requires significant
time and resources. Investments of resources are required to support any acquisition, which could result in significant ongoing
operating expenses, and we may experience challenges when combining separate business cultures, information technology
systems and employees, and those challenges may divert senior management’s time and attention. If we fail to successfully
integrate assets and liabilities through the entities which we acquire, we may not fully realize all of the growth opportunities,
benefits expected from the transaction, cost savings and other synergies and, as a result, the fair value of assets acquired could
be impaired. We assess long-lived assets, including intangible assets associated with acquisitions, for impairment whenever
events or circumstances indicate that an asset’s carrying amount may not be recoverable. To the extent the value of long-lived
assets becomes impaired, the impairment charges could have a material impact on our financial condition and results of
operations.
The benefits that we expect to achieve from acquisitions will depend, in part, on our ability to realize anticipated growth
opportunities and other synergies with our existing businesses. The success of these transactions will depend on our ability to
integrate these transactions within our existing businesses in a timely and seamless manner. We may experience challenges
when combining separate business cultures, information technology systems and employees. Even if we are able to complete an
integration successfully, we may not fully realize all the growth opportunities, cost savings and other synergies that we expect.
Investing through partnerships or joint ventures decreases our ability to manage risk. We have utilized joint ventures
through partnerships for certain S&T investments. Although we currently have no specific plans to do so, we may acquire
interests in other joint ventures or partnerships in the future. In these joint ventures or partnerships, we may not have the right or
power to direct the management and policies of the joint ventures or partnerships, and other participants or investors may take
action contrary to our instructions or requests and against our policies and objectives. In addition, the other participants may
become bankrupt or have economic or other business interests or goals that are inconsistent with those of NJR and our
subsidiaries and affiliates. Our financial condition, results of operations or cash flows could be harmed if a joint venture
participant acts contrary to our interests.
Risks Related to Credit and Liquidity
NJR is a holding company and depends on its operating subsidiaries to meet its financial obligations. NJR is a holding
company with no significant assets other than possible cash investments and the stock of its operating subsidiaries. We rely
exclusively on dividends from our subsidiaries, on intercompany loans from our unregulated subsidiaries and on the repayments
of principal and interest from intercompany loans and reimbursement of expenses from our subsidiaries for our cash flows. Our
ability to pay dividends on our common stock and to pay principal and interest on our outstanding debt depends on the payment
of dividends to us by our subsidiaries or the repayment of loans to us by our subsidiaries. The extent to which our subsidiaries
are unable to pay dividends or repay funds to us may adversely affect our ability to pay dividends to holders of our common
stock and principal and interest to holders of our debt.
Page 22
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Credit rating downgrades could increase financing costs, limit access to the financial markets and negatively affect
NJR and its subsidiaries. Rating agencies Moody’s and Fitch currently rate NJNG’s debt as investment grade. If such ratings
are downgraded below investment grade, borrowing costs could increase, as would the costs of maintaining certain contractual
relationships and obtaining future financing. Even if ratings are downgraded without falling below investment grade, NJR and
NJNG could face increased borrowing costs under their current and future credit facilities. Our ability to borrow and costs of
borrowing have a direct impact on our subsidiaries’ ability to execute their operating strategies, particularly in the case of
NJNG, which relies heavily upon capital expenditures financed by its credit facility.
If we suffer a reduction in our credit and borrowing capacity or in our ability to issue parental guarantees, the business
prospects of ES, CEV and S&T, which rely on our creditworthiness, would be adversely affected. ES could possibly be
required to comply with various margin or other credit enhancement obligations under its trading and marketing contracts, and
it may be unable to continue to trade or be able to do so only on less favorable terms with certain counterparties. CEV could be
required to seek alternative financing for its projects and may be unable to obtain such financing or able to do so only on less
favorable terms.
Additionally, lower credit ratings could adversely affect relationships with NJNG’s state regulators, who may be
unwilling to allow NJNG to pass along increased costs to its natural gas customers.
If we are unable to access the financial markets or there are adverse conditions in the equity or credit markets,
including, but not limited to, inflationary pressures, recessionary pressures, or rising interest rates, it could affect
management’s ability to execute our business plans. We rely on access to both short-term and long-term credit markets as
significant sources of liquidity for capital requirements not satisfied by our cash flow from operations. Any deterioration in our
financial condition could hamper our ability to access the equity or credit markets or otherwise obtain debt financing on terms
favorable to us or at all. In addition, because certain state regulatory approvals may be necessary for NJNG to incur debt, NJNG
may be unable to access credit markets on a timely basis.
General economic factors beyond our control might create uncertainty that could increase our cost of capital or impair or
eliminate our ability to access the debt, equity, or credit markets, including our ability to draw on bank credit facilities. External
events could also increase the cost of borrowing or adversely affect our ability to access the financial markets. Such external
events could include the following:
economic weakness and/or political instability in the U.S. or in the regions where we operate;
political conditions, such as a shutdown of the U.S. federal government;
financial difficulties of unrelated energy companies;
capital market conditions generally;
volatility in the equity markets;
•
•
•
•
•
• market prices for natural gas;
•
•
the overall health of the natural gas utility industry; and
fluctuations in interest rates and increased borrowing costs.
Failure by NJR and/or NJNG to comply with debt covenants may impact our financial condition. Our long-term debt
obligations contain financial covenants related to debt-to-capital ratios. These debt obligations also contain provisions that put
limitations on our ability to finance future operations or capital needs or to expand or pursue certain business activities. For
example, certain of these agreements contain provisions that, among other things, put limitations on our ability to make loans or
investments, make material changes to the nature of our businesses, merge, consolidate or engage in asset sales, grant liens or
make negative pledges. Furthermore, the debt obligations and our sale leaseback agreements contain covenants and other
provisions requiring us to provide timely delivery of accurate financial statements prepared in accordance with GAAP. The
failure to comply with any of these covenants could result in an event of default, which, if not cured or waived, could result in
the acceleration of outstanding debt obligations and/or the inability to borrow under existing revolving credit facilities and term
loans. We have relied, and continue to rely, upon short-term bank borrowings or commercial paper supported by our revolving
credit facilities to finance the execution of a portion of our operating strategies. NJNG is dependent on these capital sources to
purchase its natural gas supply and maintain its properties. The acceleration of our outstanding debt obligations and our
inability to borrow under the existing revolving credit facilities would cause a material adverse change in NJR’s and NJNG’s
financial condition.
Page 23
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Our ability to secure short-term financing is subject to conditions in the credit markets. A prolonged constriction of
credit availability could affect management’s ability to execute our business plan. An inability to access capital may limit
our ability to pursue improvements or acquisitions that we may otherwise rely on for both current operations and future
growth. ES and NJNG execute derivative transactions with financial institutions as a part of their economic hedging strategy
and could incur losses associated with the inability of a financial counterparty to meet or perform under its obligations as a
result of adverse conditions in the credit markets or their ability to access capital or post collateral.
Risks Related to Tax and Accounting Matters
A valuation allowance may be required for our deferred tax assets. Our deferred tax assets are comprised primarily of
investment tax credits and state net operating losses. Any revaluation of our deferred tax assets that may be required in the
future could have a material adverse impact on our financial condition and results of operations.
The cost of providing pension and postemployment health care benefits to employees and eligible former employees is
subject to changes in pension fund values, interest rates and changing demographics and may have a material adverse effect
on our financial results. We have two defined benefit pension plans and two OPEB plans for the benefit of eligible full-time
employees and qualified retirees, which were closed to all employees hired on or after January 1, 2012. The cost of providing
these benefits to eligible current and former employees is subject to changes in the market value of the pension and OPEB fund
assets, changing discount rates and changing actuarial assumptions based upon demographics, including longer life expectancy
of beneficiaries, an expected increase in the number of eligible former employees over the next five years, impacts from
healthcare legislation and increases in health care costs.
Significant declines in equity markets and/or reductions in bond yields can have a material adverse effect on the funded
status of our pension and OPEB plans. In these circumstances, we may be required to recognize increased pension and OPEB
expenses and/or be required to make additional cash contributions into the plans.
The funded status of these plans, and the related cost reflected in our financial statements, are affected by various factors
that are subject to an inherent degree of uncertainty. Under the Pension Protection Act of 2006, losses of asset values may
necessitate increased funding of the plans in the future to meet minimum federal government requirements. A significant
decrease in the asset values of these plans can result in funding obligations earlier than we had originally planned, which would
have a negative impact on cash flows from operations, decrease our borrowing capacity and increase our interest expense.
Changes in tax laws, rates or adverse outcomes resulting from examinations by tax authorities may negatively affect
our results of operations, net income, financial condition and cash flows. We are subject to taxation and audit by various
taxing authorities at the federal, state and local levels. We cannot predict how our federal and state regulators will apply such
tax changes in our future rates. While we believe we comply with all applicable tax laws, rules and regulations in the relevant
jurisdictions, tax authorities may elect to audit us and determine that we owe additional taxes, which could result in a significant
increase in our liabilities for taxes, interest and penalties in excess of our accrued liabilities.
New tax legislative initiatives may be proposed from time to time, such as proposals for comprehensive tax reform in the
United States, which may impact our effective tax rate and which could adversely affect our tax positions or tax liabilities. On
August 16, 2022, the Inflation Reduction Act was signed into law and imposed a 15% minimum tax rate on book earnings for
corporations with higher than $1B of annual income, along with a 1% excise tax on corporate stock repurchases while
providing tax incentives to promote various clean energy initiatives. We are currently assessing the potential impact of these
legislative changes.
Any future change in tax laws or interpretation of such laws could adversely affect our results of operations, net income,
financial condition and cash flows.
Page 24
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Significant regulatory assets recorded by our regulated companies could be disallowed for recovery from customers in
the future. NJNG records regulatory assets on its financial statements to reflect the ratemaking and regulatory decision-making
authority of the BPU as allowed by GAAP. The creation of a regulatory asset allows for the deferral of costs, which, absent a
mechanism to recover such costs from customers in rates approved by the BPU, would be charged to expense on its income
statement in the period incurred. Primary regulatory assets that are subject to BPU approval include the recovery of BGSS and
USF costs, remediation costs associated with NJNG’s MGP sites, CIP, NJCEP, economic stimulus plans, certain deferred
income taxes and pension and OPEB. If there were to be a change in regulatory positions surrounding the collection of these
deferred costs, there could be a material impact on NJNG’s existing tariff or a future base rate case, as well as our financial
condition, results of operations and cash flows.
Adelphia records regulatory assets on its financial statements to reflect the ratemaking and regulatory decision-making
authority of FERC as allowed by GAAP. The creation of a regulatory asset allows for the deferral of costs, which, absent a
mechanism to recover such costs from customers in rates approved by FERC, would be recorded as a charge to earnings on its
Statement of Operations in the period incurred. If there were to be a change in regulatory positions surrounding the collection of
these deferred costs, there could be a material impact on Adelphia’s existing rates or a future rate case, as well as our financial
condition, results of operations and cash flows.
Risks Related to Takeovers
Our restated certificate of incorporation, as amended, and amended and restated bylaws may delay or prevent a
transaction that shareowners would view as favorable. Our restated certificate of incorporation, as amended, and amended and
restated bylaws, as well as New Jersey law, contain provisions that could delay, defer or prevent an unsolicited change in
control of NJR, which may negatively affect the market price of our common stock or the ability of stockholders to participate
in a transaction in which they might otherwise receive a premium for their shares over the then-current market price. These
provisions may also prevent changes in management. In addition, our Board is authorized to issue preferred stock without
stockholder approval on such terms as our Board may determine. Our common shareowners will be subject to, and may be
negatively affected by, the rights of any preferred stock that may be issued in the future. In addition, we are subject to the New
Jersey Shareholders’ Protection Act, which could delay or prevent a change of control of NJR.
We may also be subject to actions or proposals from activist investors or others that may not be aligned with our long-
term strategy or the interests of our other stockholders. This may interfere with our ability to execute our strategic plans, cause
uncertainty with our regulators and make it more difficult to attract and retain qualified personnel. Moreover, our stock price
could be subject to significant fluctuation or otherwise be adversely affected by the events, risks and uncertainties of any
investor activism.
ITEM 1B. UNRESOLVED STAFF COMMENTS
None
ITEM 2. PROPERTIES
Natural Gas Distribution
As of September 30, 2023, NJNG owns approximately 7,334 miles of distribution main, 7,768 miles of service main, 251
miles of transmission main and 595,225 meters. Mains are primarily located under public roads. Where mains are located under
private property, NJNG has obtained easements from the owners of record.
Additionally, NJNG owns and operates two LNG storage plants in Stafford Township, Ocean County and Howell
Township, Monmouth County. The two LNG plants have an aggregate estimated maximum capacity of approximately 170,000
Dths per day and 1 Bcf of total capacity. These facilities are used for peaking natural gas supply and for emergencies. NJNG’s
Liquefaction facility is also located on the Howell Township property and allows NJNG to convert natural gas into LNG to fill
NJNG’s existing LNG storage tanks. A Power-to-Gas System is also located at the LNG plant in Howell Township that uses
solar power to produce hydrogen and then injects it into the natural gas system. It consists primarily of an electrolyzer unit, an
electrical and instrumentation building and small hydrogen storage tank, along with other supporting systems.
Page 25
New Jersey Resources Corporation
Part I
ITEM 2. PROPERTIES (Continued)
NJNG owns five service centers located in Rockaway Township, Morris County; Atlantic Highlands and Wall Township,
Monmouth County; and Lakewood and Stafford Township, Ocean County. These service centers house storerooms, garages,
natural gas distribution and administrative offices. NJNG leases a customer service office in Asbury Park, Monmouth County.
These customer service offices support customer contact, marketing, economic development and other functions. NJNG also
owns its headquarters and customer service facilities in Wall Township and a training facility in Howell Township, Monmouth
County, to support the technical training of its employees.
Substantially all of NJNG’s properties not expressly excepted or duly released are subject to the lien of the Mortgage
Indenture as security for NJNG’s mortgage bonds, which totaled $1.5B as of September 30, 2023. In addition, under the terms
of the Mortgage Indenture, NJNG had capacity to issue up to $1.4B of additional FMBs as of September 30, 2023.
Clean Energy Ventures
As of September 30, 2023, CEV has various solar contracts, including lease agreements and easements, allowing the
installation, operation and maintenance of solar equipment and access to the various properties, including commercial and
residential rooftops throughout the State of New Jersey. In addition to the lease agreements and easements, CEV owns solar
projects with a total of 468.8 MW of capacity in New Jersey, Rhode Island, New York, Connecticut, Michigan and Indiana,
79.5 acres of land in Vineland, Cumberland County, New Jersey, 14.4 acres of land in Upper Deerfield Township, Cumberland
County, New Jersey and 101.8 acres of land in Fairfield Township, Cumberland County, New Jersey.
CEV leases office space in Wall Township, New Jersey.
Energy Services
As of September 30, 2023, ES leases office space in Wall Township, New Jersey.
Storage and Transportation
As of September 30, 2023, Adelphia owns approximately 11.1 acres of land in Delaware County, Pennsylvania, 32.71
acres in Bucks County, Pennsylvania, 121.1 acres in Northampton County, Pennsylvania and 44.9 acres in Montgomery
County, Pennsylvania and leases office space in Wall Township, New Jersey. Leaf River owns 43.9 acres of land and a 5,000
square foot building in Smith County, Mississippi, 158.5 acres in Jasper County, Mississippi and 3.5 acres in Clarke County,
Mississippi and leases office space in Houston, Texas.
All Other Business Operations
As of September 30, 2023, CR&R’s real estate portfolio consists of 23.1 acres of undeveloped land in Atlantic County,
New Jersey. NJRHS leases service centers in Dover, New Jersey and Wall Township, New Jersey. NJR Service Corporation
leases office space in Red Bank, New Jersey.
ITEM 3. 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.
Page 26
New Jersey Resources Corporation
Part I
ITEM 3. LEGAL PROCEEDINGS (Continued)
NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic
Highlands, Berkeley, Long Branch, Manchester, Toms River, Freehold and Aberdeen, New Jersey, including a review of
potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future
expenditures at the former MGP sites for which it is responsible, including potential liabilities for natural resource damages that
might be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites, will range
from approximately $137.3M to $201.5M. NJNG’s estimate of these liabilities is based upon known facts, existing technology
and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and
the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no
point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of
September 30, 2023, NJNG recorded a MGP remediation liability and a corresponding regulatory asset of approximately
$169.4M on the Consolidated Balance Sheets based on the most likely amount. The actual costs to be incurred by NJNG are
dependent upon several factors, including final determination of remedial action, changing technologies and governmental
regulations, the ultimate ability of other responsible parties to pay and insurance recoveries, if any.
NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC
approved by the BPU. In March 2022, the BPU approved an increase in the RAC, which increased the pre-tax annual recovery
from $11.1M to $11.7M, effective April 1, 2022. On April 12, 2023, the BPU approved on a final basis NJNG’s annual SBC
filing of RAC expenditures through June 30, 2022, as well as an increase to the RAC annual recoveries of $3.7M, which
increased the pre-tax annual recovery to $15.4M, effective May 1, 2023.
As of September 30, 2023, $66.3M 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 foregoing statements about NJR’s litigation are based upon the Company’s judgments, assumptions and estimates and
are necessarily subjective and uncertain. 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 at various stages 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 are currently pending, taken together, will not have a materially adverse effect on
the Company’s financial condition, results of operations or cash flows. The actual results of resolving the pending litigation
matters may be substantially higher than the amounts accrued.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable
Page 27
New Jersey Resources Corporation
Part II
ITEM 5. MARKET FOR THE REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND
ISSUER PURCHASES OF EQUITY SECURITIES
NJR’s Common Stock is traded on the New York Stock Exchange under the ticker symbol NJR. As of November 7, 2023,
NJR had 79,007 holders of record of its common stock. Dividends are subject to declaration by the Board of Directors. In
September 2023, the Board of Directors declared dividends payable October 2, 2023 of $0.42 per share of common stock to
shareowners of record on September 20, 2023. We review our dividend policy on a regular basis. Although subject to any
contractual or regulatory restrictions or other limitations on the payment of dividends, future dividends will be at the discretion
of the Board of Directors and will depend upon, among other factors, earnings, financial condition and other requirements.
Performance Graph
The performance graph and table below illustrates a five-year comparison of cumulative total returns based on an initial
investment of $100 in our common stock, as compared with the S&P 500 Stock Index, the S&P 500 Utilities Industry Index and
the customized peer company group listed below, referred to herein as the Peer Group. The Peer Group companies were
selected based on similarities to the Company’s business model, size and other growth and business factors.
Cumulative Total Return
NJR
S&P 500 Utilities
S&P 500
Peer Group
2018
$100.00
$100.00
$100.00
$100.00
2019
$100.52
$127.10
$104.25
$117.06
2020
2021
2022
$62.55
$120.79
$120.05
$89.97
$83.47
$134.09
$156.07
$98.14
$96.11
$141.56
$131.92
$109.62
2023
$104.30
$131.63
$160.44
$106.24
The 9 companies in the Peer Group are: Atmos Energy Corporation; Avista Corporation; Black Hills Corporation; National
Fuel Gas Company; NiSource Inc.; Northwest Natural Holding Company; ONE Gas, Inc.; Southwest Gas Corporation; and
Spire Inc. South Jersey Industries was removed from the Peer Group since the company is no longer a publicly held entity.
This performance graph and accompanying information shall not be deemed “filed” for purposes of Section 18 of the
Exchange Act, or incorporated by reference into any of the Company’s filings under the Securities Act, or the Exchange Act,
except as shall be expressly set forth by specific reference in such filing.
In 1996, the Board of Directors authorized the Company to implement a share repurchase program, which has been
expanded seven times since the inception of the program, authorizing a total of 19.5M shares of common stock for repurchase.
The share repurchase plan allows us to purchase our outstanding shares on the open market or in negotiated transactions, based
on market and other conditions. We are not required to purchase any specific number of shares and may discontinue or suspend
the program at any time. The share repurchase plan will expire when we have repurchased all shares authorized for repurchase
thereunder, unless it is terminated earlier by action of our Board of Directors or additional shares are authorized for repurchase.
The following table sets forth NJR’s repurchase activity for the quarter ended September 30, 2023:
Period
07/01/23 - 07/31/23
08/01/23 - 08/31/23
09/01/23 - 09/30/23
Total
Total Number
of Shares
(or Units)
Purchased
—
—
—
—
$
$
$
$
Average
Price Paid
per Share
(or Unit)
Total Number of Shares (or
Units) Purchased as Part of
Publicly Announced Plans
or Programs
—
—
—
—
Maximum Number (or Approximate
Dollar Value) of Shares (or Units) That
May Yet Be Purchased Under the
Plans or Programs
1,685,053
1,685,053
1,685,053
1,685,053
—
—
—
—
ITEM 6. [RESERVED]
Page 28
Comparison of 5 year Cumulative ReturnNJRS&P 500 UtilitiesS&P 500Peer Group201820192020202120222023$0.00$100.00$200.00 New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
Critical Accounting Estimates
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, acquisitions, 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 and Adelphia are subject to accounting requirements resulting from the effects of rate regulation. Specifically,
NJNG and Adelphia record regulatory assets when it is considered probable that certain operating costs will be recoverable
from customers in future periods and record regulatory liabilities when it is probable future obligations to customers exist.
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. For NJNG, 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 probable through the regulatory process, we
record a regulatory asset corresponding to the related accrued liability. Accordingly, NJNG records 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 14. Commitments and Contingent Liabilities for more details.
Page 29
New Jersey Resources Corporation
Part II
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.
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%, 17%, 33% and 16%, 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 as of and for the fiscal year ended
September 30, 2023:
Pension Plans
Actuarial Assumptions
Discount rate
Discount rate
Rate of return on plan assets
Rate of return on plan assets
Other Postemployment Benefits
Actuarial Assumptions
Discount rate
Discount rate
Rate of return on plan assets
Rate of return on plan assets
Actuarial Assumptions
Health care cost trend rate
Health care cost trend rate
Increase/
(Decrease)
1.00 %
(1.00) %
1.00 %
(1.00) %
Increase/
(Decrease)
1.00 %
(1.00) %
1.00 %
(1.00) %
Increase/
(Decrease)
1.00 %
(1.00) %
Estimated
Increase/(Decrease) on PBO
(Thousands)
$ (28,573)
$ 34,313
n/a
n/a
Estimated
Increase/(Decrease) to Expense
(Thousands)
(88)
4,131
(2,854)
2,854
$
$
$
$
Estimated
Increase/(Decrease) on PBO
(Thousands)
$ (25,370)
$ 31,353
n/a
n/a
Estimated
Increase/(Decrease) to Expense
(Thousands)
(154)
2,515
(961)
960
$
$
$
$
Estimated
Increase/(Decrease) on PBO
(Thousands)
$ 30,818
$ (25,283)
Estimated
Increase/(Decrease) to Expense
(Thousands)
4,522
(1,700)
$
$
Page 30
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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.
Investments in Equity Investees
The Company accounts for its investment in Steckman Ridge 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% 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.
When impairment indicators are present, the fair value of the Company’s investment in Steckman Ridge is determined
using a discounted cash flow method and utilizes 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, discount
rates and the nature and timing of major maintenance and capital investment. 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.
Page 31
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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 to 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 ES’s 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. ES’s 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, ES may utilize additional published pipeline tariff information and/or other services to
determine an equivalent market price. As of September 30, 2023, 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, ES 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 2023, 2022 and
2021. 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.
CEV hedges certain of its expected production of SRECs through forward and futures contracts. CEV 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, 2023 and 2022.
Page 32
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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 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 changes in 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 effects of changes in tax laws or tax rates 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 laws 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 and/or assets be considered a
temporary difference for which a related deferred tax asset and/or 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. In general, for our unregulated subsidiaries, we record ITCs on
the balance sheet as a contra-asset as a reduction to property, plant and equipment when the property is placed in service. The
contra-asset is amortized on the Consolidated Statements of Operations as a reduction to depreciation expense over the useful
lives of the related assets.
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.
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 and
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.
Page 33
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The following sections include a discussion of results for fiscal 2023 compared to fiscal 2022. The comparative results
for fiscal 2022 with fiscal 2021 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, 2022, filed with the SEC on November 17, 2022.
Reporting Segments
We have four primary reporting segments as presented in the chart below:
In addition to our four reporting segments above, we have nonutility 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 HSO,
include appliance repair services, sales and installations at NJRHS and commercial real estate holdings at CR&R.
Operating Results
Net income (loss) and assets by reporting segment and other business operations for the fiscal years ended September 30,
are as follows:
(Thousands)
NJNG
CEV
ES
S&T
HSO
Intercompany (1)
Total
2023
Net Income
$
$
131,414 $
44,458
78,848
13,154
4,758
(7,908)
264,724 $
Assets
4,414,829 $
1,128,577
123,775
1,011,959
171,275
(312,919)
6,537,496 $
2022
Net Income
140,124 $
39,403
69,650
26,598
(781)
(72)
274,922 $
Assets
4,030,686 $
1,015,065
333,064
999,520
159,068
(275,987)
6,261,416 $
2021
Net Income
107,375 $
16,789
58,957
(67,787)
(826)
3,382
117,890 $
Assets
3,707,461
914,788
365,423
862,407
162,134
(289,935)
5,722,278
(1)
Consists of transactions between subsidiaries that are eliminated in consolidation.
Page 34
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The decrease in net income of $10.2M during fiscal 2023, compared with fiscal 2022, is due primarily to decreased
earnings at NJNG due to higher O&M and higher interest expense related to new debt at higher interest rates, and decreased
earnings at S&T resulting from increased interest and depreciation expenses. These decreases are partially offset by increased
earnings at ES due primarily to higher natural gas price volatility in December 2022 and February 2023 and by increased
earnings at CEV related to the reversal of a valuation allowance for certain deferred tax assets. The primary drivers of the
changes noted above are described in more detail in the individual reporting segment and other business operations discussions.
The increase in assets during fiscal 2023, compared with fiscal 2022, was due primarily to additional investment in utility
plant at NJNG and solar asset investments at CEV, partially offset by a decrease in accounts receivable, gas in storage and
restricted broker margin at ES and NJNG resulting from a decline in natural gas prices.
Non-GAAP Financial Measures
Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. ES economically
hedges its natural gas inventory with financial derivative instruments. NFE is a measure of the earnings based on eliminating
timing differences surrounding the recognition of certain gains or losses, to effectively match the earnings effects of the
economic hedges with the physical sale of natural gas and, therefore, eliminates the impact of volatility to GAAP earnings
associated with the derivative instruments. To the extent we utilize forwards, futures or other derivatives to hedge forecasted
SREC production, unrealized gains and losses are also eliminated from NFE. NFE also excludes certain transactions associated
with equity method investments, including impairment charges, which are non-cash charges, and return of capital in excess of
the carrying value of our investment. These are considered unusual in nature and occur infrequently such that they are not
indicative of our performance for ongoing operations. Included in the tax effects are current and deferred income tax expense
corresponding with the components of NFE.
Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in
addition to, and not as a substitute for or a replacement of, the comparable GAAP measure and should be read in conjunction
with those GAAP results.
Below is a reconciliation of consolidated net income, the most directly comparable GAAP measure, to NFE for the fiscal
years ended September 30:
(Thousands, except per share data)
Net income
Add:
Unrealized (gain) loss on derivative instruments and related transactions
Tax effect
Effects of economic hedging related to natural gas inventory (1)
Tax effect
(Gain on) impairment of equity method investment
Tax effect
Net financial earnings
Basic earnings per share
Add:
Unrealized (gain) loss on derivative instruments and related transactions
Tax effect
Effects of economic hedging related to natural gas inventory (1)
Tax effect
(Gain on) impairment of equity method investment
Tax effect
Basic NFE per share
2023
2022
$ 264,724 $ 274,922 $ 117,890
2021
(38,081)
9,050
34,699
(8,246)
(300)
(19)
54,203
(12,887)
(42,405)
10,078
92,000
(11,167)
$ 261,827 $ 240,321 $ 207,712
(59,906)
14,248
19,939
(4,738)
(5,521)
1,377
$
2.73 $
2.86 $
1.23
(0.39)
0.09
0.36
(0.09)
—
—
2.70 $
(0.62)
0.15
0.21
(0.05)
(0.06)
0.01
2.50 $
0.56
(0.13)
(0.44)
0.10
0.96
(0.12)
2.16
$
(1)
Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period.
Page 35
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
NFE by reporting segment and other business operations for the fiscal years ended September 30, discussed in more detail
within the operating results sections of each reporting segment and other business operations, is summarized as follows:
(Thousands)
NJNG
CEV
ES
S&T
HSO
Eliminations (1)
Total
2023
$ 131,414
44,458
68,517
12,835
4,758
(155)
$ 261,827
2021
2022
50 % $ 140,124
58 % $ 107,375
17
16,789
17
39,403
26
71,117
16
39,121
5
13,046
9
22,454
2
(826)
—
(781)
—
211
—
—
100 % $ 240,321 100 % $ 207,712 100 %
52 %
8
34
6
—
—
(1) Consists of transactions between subsidiaries that are eliminated in consolidation.
The increase in NFE of $21.5M during fiscal 2023, compared with fiscal 2022, was due primarily to higher Financial
Margin at ES along with an increase in the benefit from income taxes at CEV, partially offset by decreases at NJNG and S&T,
as previously discussed.
Natural Gas Distribution
Overview
Natural Gas Distribution is comprised of NJNG, a natural gas utility that provides regulated natural gas service
throughout Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex counties in New Jersey to approximately 576,000
residential and commercial customers in its service territory and also participates in the off-system sales and capacity release
markets. The business is subject to various risks, which 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 such as inflation and rising natural gas costs, certain regulatory actions, environmental
remediation and severe weather conditions. It is often difficult to predict the impact of events or trends associated with these
risks.
NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered to
customers on an annual basis. Specifically, customer demand substantially increases during the winter months when natural gas
is used for heating purposes. As a result, NJNG generates most of its natural gas distribution revenues during the first and
second fiscal quarters and is subject to variations in earnings and working capital during the fiscal year.
As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements.
See Note 4. Regulation in the accompanying Consolidated Financial Statements for a more detailed discussion of 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
In November 2021, the BPU issued an order adopting a stipulation of settlement approving a $79.0M increase to base
rates, effective December 1, 2021. In addition, the order also included approval for the final increase for the NJ RISE/SAFE II
programs, which totaled $0.3M. These increases include an overall rate of return on rate base of 6.84%, return on common
equity of 9.6%, a common equity ratio of 54.0% and a composite depreciation rate of 2.78%.
Page 36
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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 2023 and estimates of 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.
NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability and
integrity of NJNG’s natural gas distribution system.
Infrastructure Investment Program
In February 2019, NJNG filed a petition with the BPU seeking authority to implement a five-year IIP. The IIP consisted
of two components: transmission and distribution investments and information technology replacement and enhancements. The
total investment for the IIP was approximately $507.0M. All approved investments will be recovered through annual filings to
adjust base rates. In October 2020, the BPU approved the Company’s transmission and distribution component of the IIP for
$150.0M 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. In March 2022, NJNG filed its first rate
recovery request for its BPU-approved IIP with capital expenditures estimated through June 30, 2022, including AFUDC. In
July 2022, NJNG filed its update with actual capital expenditures of $28.9M through June 30, 2022. In September 2022, the
BPU approved the rate increase resulting in a $3.2M revenue increase, effective October 1, 2022.
On March 30, 2023, NJNG submitted its annual IIP filing to the BPU requesting a rate increase for estimated capital
expenditures of $31.4M through June 30, 2023. This filing was updated on July 28, 2023, with actual expenses of
approximately $28.2M through June 30, 2023. The BPU approved this filing on September 27, 2023, which resulted in a $3.2M
revenue increase, effective October 1, 2023.
Page 37
$ (Millions)$0.5$76.7$126.3$43.1$60.7$44.9$42.4$45.0$77.5$160.0$28.0$62.5$2.5$38.02023A2024EClean FuelsCustomerGrowth SystemIntegrityInfrastructure Investment ProgramTechnology UpgradesFacilities and Other Cost of Removal$0$20$40$60$80$100$120$140$160$180 New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
SAFE II and NJ RISE
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 $200.0M,
excluding AFUDC. With the approval of SAFE II, $157.5M was approved for accelerated cost recovery methodology. The
remaining $42.5M in capital expenditures was requested for recovery in base rate cases, of which $23.4M was approved in
NJNG’s 2019 base rate case and $19.1M was approved in the 2021 base rate case.
The BPU approved NJNG’s NJ RISE capital infrastructure program, which consists of six capital investment projects
estimated to cost $102.5M, excluding AFUDC, for natural gas distribution storm hardening and mitigation projects, along with
associated depreciation expense. These system enhancements are intended to minimize service impacts during extreme weather
events to customers in the most storm-prone areas of NJNG’s service territory. Recovery of NJ RISE investments is included in
NJNG’s base rates.
In March 2021, NJNG filed a petition with the BPU requesting the final base rate increase for the recovery associated
with NJ RISE and SAFE II capital investments costs of approximately $3.4M made through June 30, 2021. In June 2021, this
filing was consolidated with the 2021 base rate case. In November 2021, the BPU issued an order for the consolidated matter
which included approval for the final increase for the NJ RISE and SAFE II programs of $0.3M.With this approval, the filings
with respect to NJ RISE and SAFE II are complete.
Customer Growth
In conducting NJNG’s business, management focuses on factors it believes may have significant influence on its future
financial results. NJNG’s policy is to work with all stakeholders, including customers, regulators and policymakers, to achieve
favorable results. These factors include the rate of NJNG’s customer growth in its service territory, which can be influenced by
political and regulatory policies, the delivered cost of natural gas compared with competing fuels, interest rates and general
economic and business conditions.
NJNG’s total customers as of September 30, include the following:
Firm customers
Residential
Commercial, industrial & other
Residential transport
Commercial transport
Total firm customers
Other
Total customers
2023
2022
2021
520,682
31,725
15,457
8,033
575,897
103
576,000
512,264
31,227
17,316
8,397
569,204
96
569,300
502,546
30,615
21,882
8,815
563,858
47
563,905
During fiscal 2023, 2022 and 2021, NJNG added 8,800, 7,808 and 7,854 new customers, respectively. NJNG expects
new customer additions, and those customers who added additional natural gas services to their premises, to contribute
approximately $7.4M of incremental Utility Gross Margin on an annualized basis.
NJNG expects its new customer annual growth rate to be approximately 1.9%. Based on information from municipalities
and developers, as well as external industry analysts and management’s experience, NJNG estimates that approximately 67% of
the growth will come from new construction markets and 33% from customer conversions to natural gas from other fuel
sources. This new customer and conversion growth would increase Utility Gross Margin under NJNG’s base rates by
approximately $8.5M annually, as calculated under NJNG’s CIP tariff.
Page 38
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Energy Efficiency Programs
SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives designed
to encourage the installation of high-efficiency heating and cooling equipment and other energy efficiency upgrades. Depending
on the specific incentive or approval, NJNG recovers costs associated with the programs over a two- to 10-year period through
a tariff rider mechanism. In March 2021, the BPU approved a three-year SAVEGREEN program consisting of approximately
$126.1M of direct investment, $109.4M in financing options and approximately $23.4M in operation and maintenance
expenses, which resulted in a $15.6M annual recovery increase, effective July 1, 2021.
In May 2020, NJNG filed a petition with the BPU to decrease its EE recovery rate. In October 2020, the BPU approved
NJNG to maintain its existing rate, which resulted in an annual recovery of approximately $11.4M, effective November 1,
2020.
In June 2021, NJNG submitted its annual cost recovery filing for the SAVEGREEN programs established from 2010
through 2021. In January 2022, the BPU approved the stipulation, which increased annual recoveries by $2.2M, effective
February 1, 2022.
In June 2022, NJNG submitted its annual cost recovery filing for the SAVEGREEN programs established from 2010
through the present. In September 2022, the BPU approved the rate decrease, which resulted in an annual decrease of
approximately $3.5M, effective October 1, 2022.
On June 1, 2023, NJNG submitted its annual cost recovery filing for the SAVEGREEN programs established from 2010
through the present, which would increase annual recoveries by approximately $10.7M. On September 27, 2023, the BPU
approved an increase to the EE rate, increasing annual recoveries by $9.0M based on updated information since the initial
filing, effective October 1, 2023.
The following table summarizes loans, grants, rebates and related investments as of September 30:
(Thousands)
Loans
Grants, rebates and related investments
Total
2023
198,600 $
205,200
403,800 $
2022
175,300
168,700
344,000
$
$
Program recoveries from customers during the fiscal years ended September 30, 2023 and 2022, were $26.3M and
$25.8M, respectively. The recovery includes a weighted average cost of capital that ranges from 6.69% to 7.76%, with a return
on equity of 9.6% to 10.3%.
Conservation Incentive Program/BGSS
The CIP facilitates normalizing NJNG’s Utility Gross Margin for variances not only due to weather but also 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.
NJNG’s total utility firm gross margin includes the following adjustments related to the CIP mechanism:
(Thousands)
Weather (1)
Usage
Total
2023
2022
2021
$
$
44,675 $
3,276
47,951 $
22,263 $
2,032
24,295 $
13,273
(1,852)
11,421
(1)
Compared with the 20-year average, weather was 13.4%, 8.3% and 6.5% warmer-than-normal during fiscal 2023, 2022 and 2021, respectively.
Page 39
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Recovery of Natural Gas Costs
NJNG’s cost of natural gas is passed through to our customers, without markup, by applying NJNG’s authorized BGSS
rate to actual therms delivered. There is no Utility Gross Margin associated with BGSS costs; therefore, changes in such costs
do not impact NJNG’s earnings. NJNG monitors its actual natural gas costs in comparison to its BGSS rates to manage its cash
flows associated with its allowed recovery of natural gas costs, which is facilitated through BPU-approved deferred accounting
and the BGSS pricing mechanism. Accordingly, NJNG occasionally adjusts its periodic BGSS rates or can issue credits or
refunds, as appropriate, for its residential and small commercial customers when the commodity cost varies from the existing
BGSS rate. BGSS rates for its large commercial customers are adjusted monthly based on NYMEX prices.
NJNG’s residential and commercial markets are currently open to competition, and its rates are segregated between
BGSS (i.e., natural gas commodity) and delivery (i.e., transportation) components. NJNG earns Utility Gross Margin through
the delivery of natural gas to its customers and, therefore, is not negatively affected by customers who use its transportation
service and purchase natural gas from another supplier. Under an existing order from the BPU, BGSS can be provided by
suppliers other than the state’s natural gas utilities; however, customers who purchase natural gas from another supplier
continue to use NJNG for transportation service.
During fiscal 2021, NJNG notified the BPU of its intent to provide BGSS bill credits to residential and small commercial
sales customers. The actual bill credits given to customers totaled $20.6M, $19.3M net of tax.
In November 2021, the BPU approved on a preliminary basis a $2.9M increase to the annual revenues credited to BGSS,
a $13.0M annual increase related to its balancing charge, as well as changes to CIP rates, which resulted in a $6.3M annual
recovery decrease, effective December 1, 2021, and approved on a final basis in May 2022.
In November 2021, NJNG submitted notification of its intent to self-implement an increase to its BGSS rate, which
resulted in an approximately $24.2M increase to annual revenues credited to BGSS, effective December 1, 2021.
In June 2022, NJNG submitted its annual petition to modify its BGSS, balancing charge and CIP rates for residential and
small business customers, which was approved by the BPU on a preliminary basis in September 2022. This includes an $81.9M
increase to the annual revenues credited to BGSS, a $9.0M annual increase related to its balancing charge and a $10.2M
increase to CIP rates, effective October 1, 2022, which was approved on a final basis on April 12, 2023.
On April 12, 2023, the BPU approved on a final basis, NJNG’s February 22, 2023 filing that advised the BPU of a bill
credit and a reduction to the BGSS rate for residential and small commercial customers, which will reduce recoveries by
approximately $29.9M, effective March 1, 2023. Bill credits provided to customers from March 2023 through May 2023 totaled
approximately $32.4M.
On June 1, 2023, NJNG filed its annual petition to modify its BGSS, balancing charge and CIP rates for residential and
small business customers. This included a $38.6M decrease to the annual revenues credited to BGSS, a $7.4M annual decrease
related to its balancing charge and a $27.5M increase to CIP rates, effective October 1, 2023. On September 18, 2023, the BPU
approved, on a provisional basis, the filed BGSS and balancing charge changes and a $27.0M increase to CIP rates, based on
updated information since the initial filing. The balancing charge rate includes the cost of balancing natural gas deliveries with
customer usage for sales and transportation customers, and balancing charge revenues are credited to BGSS.
BGSS Incentive Programs
NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of Utility Gross Margin-sharing
programs that include off-system sales, capacity release and storage incentive programs. These programs are designed to
encourage better utilization and hedging of NJNG’s natural gas supply, transportation and storage assets. Depending on the
program, NJNG shares 80 or 85% of Utility Gross Margin generated by these programs with firm customers. Utility Gross
Margin from incentive programs was $20.0M, $19.6M and $13.4M during the fiscal years ended September 30, 2023, 2022 and
2021, respectively.
Page 40
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Hedging
In order to provide relative price stability to its natural gas supply portfolio, NJNG employs a hedging strategy with the
goal of having at least 75% of the Company’s projected winter periodic BGSS natural gas sales volumes hedged by each
November 1 and at least 25% of the projected periodic BGSS natural gas sales hedged for the following April-through-March
period. The hedging goal is typically achieved with gas in storage and the use of financial instruments to hedge storage
injections. NJNG may also use various financial instruments including futures, swaps, options and weather-related products to
hedge its future delivery obligations.
Commodity Prices
NJNG is affected by the price of natural gas, which can have a significant impact on our cash flows, short-term financing
costs, the price of natural gas charged to our customers through the BGSS clause, our ability to collect accounts receivable,
which impacts our bad debt expense, and our ability to maintain a competitive advantage over other energy sources. Natural gas
commodity prices are shown in the graph below, which illustrates the daily natural gas prices(1) in the Northeast market region,
also known as TETCO M-3.
(1) Data sourced from Standard & Poor’s Financial Services, LLC Global Platts.
The maximum price per MMBtu was $32.46, $17.69 and $14.57 and the minimum price was $0.67, $2.42 and $0.28 for
the fiscal years ended September 30, 2023, 2022 and 2021, respectively. A more detailed discussion of the impacts of the price
of natural gas on operating revenues, natural gas purchases and cash flows can be found in the Operating Results and Cash
Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Page 41
($ per MMBtu)Tetco M-3 Daily Prices202320222021OctNovDecJanFebMarAprMayJuneJulyAugSept$0$5$10$15$20$25$30$35 New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Societal Benefits Charge
NJNG’s qualifying customers are eligible for the USF program, which is administered by the New Jersey Department of
Community Affairs, to help make energy bills more affordable.
In March 2022, the BPU approved on a final basis NJNG’s annual SBC application to recover remediation expenses,
including an increase in the RAC, of approximately $0.6M annually and a decrease to the NJCEP factor of approximately
$2.9M, effective April 1, 2022.
In June 2022, NJNG filed its annual USF compliance filing proposing a decrease to the statewide USF rate. In August
2022, an additional update was submitted on behalf of all NJ utilities with actual information through July 31, 2022. In
September 2022, the BPU approved a decrease based on the August update, which resulted in an annual decrease of
approximately $1.6M, effective October 1, 2022.
In September 2022, NJNG submitted its annual SBC filing to the BPU requesting approval of RAC expenditures through
June 30, 2022, as well as an increase to the RAC annual recoveries of $3.8M and an increase to the NJCEP annual recoveries of
$2.2M, with a proposed effective date of April 1, 2023. On April 12, 2023, the BPU approved on a final basis, an increase to
the RAC annual recoveries of $3.7M and a decrease to the NJCEP annual recoveries of $0.9M, effective May 1, 2023.
On June 28, 2023, NJNG submitted its annual USF filing to the BPU requesting an increase to the statewide USF rate,
which will result in a $0.7M increase to annual recoveries. The BPU approved this matter on September 27, 2023, effective
October 1, 2023.
On September 11, 2023, NJNG submitted its annual SBC filing to the BPU requesting approval of RAC expenditures
through June 2023, as well as an increase to the RAC annual recoveries of $2.4M and an increase to the NJCEP annual
recoveries of $5.0M, which would be effective April 1, 2024.
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 $169.4M as of September 30,
2023, an increase of $42.3M compared with the prior fiscal period.
In June 2019, NJNG initiated a preliminary assessment of a site in Aberdeen, New Jersey to determine prior ownership
and if former MGP operations were active at the location. The preliminary assessment and site investigation activities are
ongoing at the Aberdeen site and, based on initial findings, will be moving to the remedial investigation phase. The costs
associated with preliminary assessment, site investigation and remedial investigation activities are considered immaterial and
are included as a component of NJNG’s annual SBC application to recover remediation expenses. We will continue to gather
information to further refine and enhance the estimate of potential costs for this site as it becomes available. See Note 14.
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.
Page 42
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Results
NJNG’s operating results for the fiscal years ended September 30, are as follows:
(Thousands)
Operating revenues (1)
Operating expenses
Natural gas purchases (2) (3)
Operation and maintenance
Regulatory rider expense (4)
Depreciation and amortization
Total operating expenses
Operating income
Other income, net
Interest expense, net of capitalized interest
Income tax provision
Net income
2023
2022
$ 1,012,633 $ 1,128,767 $ 731,796
2021
425,457
226,780
50,542
102,326
805,105
207,528
13,546
56,595
33,065
260,714
203,740
38,304
80,045
582,803
148,993
13,841
36,405
19,054
$ 131,414 $ 140,124 $ 107,375
557,232
198,546
59,437
94,579
909,794
218,973
7,686
46,394
40,141
(1)
(2)
(3)
(4)
Includes nonutility revenue of approximately $1.3M, $1.4M and $0.3M for fiscal 2023, 2022 and 2021, respectively, for lease agreements with various
NJR subsidiaries leasing office space from NJNG at the Company’s headquarters that commenced in July 2021, which are eliminated in consolidation.
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.
Includes related party transactions of approximately $9.3M for both fiscal 2023 and 2022, and $13.0M for fiscal 2021, a portion of which is eliminated
in consolidation.
Consists of expenses associated with state-mandated programs, the RAC and energy efficiency programs, calculated on a per-therm basis. These
expenses are passed through to customers and are offset by corresponding revenues.
Operating Revenues and Natural Gas Purchases
Operating revenues decreased 10.3% during fiscal 2023 compared with fiscal 2022. Natural gas purchases decreased
23.6% during fiscal 2023 compared with fiscal 2022.
The factors contributing to the increases and decreases in operating revenues and natural gas purchases during fiscal
2023, are as follows:
(Thousands)
BGSS incentives
Bill credits
Firm sales
Average BGSS rates
CIP adjustments
Base rate impact
Riders and other (1)
Total decrease
2023 v. 2022
Operating
revenues
Natural gas
purchases
$
$
(156,951) $
(31,581)
(24,005)
75,105
23,656
6,927
(9,285)
(116,134) $
(157,384)
(31,581)
(19,536)
75,105
—
—
1,621
(131,775)
(1)
Riders and other includes changes in rider rates, including those related to Energy Efficiency, NJCEP and other programs, which is offset in regulatory
rider expense.
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 operating revenues less natural gas purchases, sales tax and regulatory rider
expenses. This measure differs from gross margin as presented on a GAAP basis, as it excludes certain operations and
maintenance expense and depreciation and amortization. Utility Gross Margin may also 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
Page 43
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Gross Margin provides a meaningful basis for evaluating utility operations since natural gas costs, sales tax and regulatory rider
expenses are included in operating revenues and passed through to customers and, therefore, have no effect on Utility Gross
Margin. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in
addition to, and not as a substitute for, the comparable GAAP measure.
Utility Gross Margin
A reconciliation of gross margin, the closest GAAP financial measure to NJNG’s Utility Gross Margin for the fiscal years
ended September 30, is as follows:
(Thousands)
Operating revenues
Less:
Natural gas purchases
Operation and maintenance (1)
Regulatory rider expense
Depreciation and amortization
Gross margin
Add:
Operation and maintenance (1)
Depreciation and amortization
Utility Gross Margin
2023
2022
$ 1,012,633 $ 1,128,767 $
2021
731,796
425,457
115,292
50,542
102,326
319,016
557,232
93,164
59,437
94,579
324,355
260,714
110,364
38,304
80,045
242,369
115,292
102,326
536,634 $
93,164
94,579
512,098 $
110,364
80,045
432,778
$
(1)
Excludes selling, general and administrative expenses of approximately $111.5M, $102.8M and $97.0M for the fiscal years 2023, 2022 and 2021,
respectively.
Utility Gross Margin consists of three components:
• Utility firm gross margin generated from only the delivery component of either a sales tariff or a transportation tariff
from residential and commercial customers who receive natural gas service from NJNG;
• BGSS incentive programs, where revenues generated or savings achieved from BPU-approved off-system sales,
capacity release or storage incentive programs are shared between customers and NJNG; and
• Utility Gross Margin generated from off-tariff customers, as well as interruptible customers.
The following provides more information on the components of Utility Gross Margin and associated throughput (Bcf) of
natural gas delivered to customers:
($ in thousands)
Utility Gross Margin/Throughput
Residential
Commercial, industrial and other
Firm transportation
Total utility firm gross margin/throughput
BGSS incentive programs
Interruptible/off-tariff agreements
Total Utility Gross Margin/Throughput
Utility Firm Gross Margin
2023
2022
2021
Margin
Bcf
Margin
Bcf
Margin
Bcf
$ 360,138 43.4
8.4
76,550
76,114 12.1
512,802 63.9
20,020 72.6
3,812 29.5
$ 536,634 166.0
45.5
$ 341,167
8.7
77,629
13.0
69,933
67.2
488,729
95.2
19,587
32.4
3,782
$ 512,098 194.8
45.5
288,723
8.7
64,950
13.0
61,870
67.2
415,543
95.2
13,415
3,820
32.4
$ 432,778 194.8
Utility firm gross margin increased $24.1M during fiscal 2023 compared with fiscal 2022, due primarily to an increase in
customers along with increased base rates.
Page 44
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
BGSS Incentive Programs
The factors contributing to the change in Utility Gross Margin generated by BGSS incentive programs are as follows:
(Thousands)
Storage
Capacity release
Off-system sales
Total increase
2023 v. 2022
417
$
208
(192)
433
$
$
The increase in BGSS incentive programs was due primarily to increased margins from storage incentive market
opportunities and higher capacity release values, partially offset by lower off-system sales volumes.
Other Results
O&M expense increased $28.2M during fiscal 2023 compared with fiscal 2022, due primarily to the deferral of bad debt
costs in accordance with the July 2020 BPU deferral order in fiscal 2022 that did not reoccur, as well as an increase in
compensation and consulting expenditures.
Depreciation expense increased $7.7M in fiscal 2023, compared with fiscal 2022, as a result of additional utility plant
being placed into service.
Interest expense increased $10.2M in fiscal 2023, compared with fiscal 2022, due primarily to increased outstanding
long-term debt at higher interest rates.
Other income increased $5.9M during fiscal 2023, compared with fiscal 2022, due primarily to increased AFUDC equity,
along with decreased pension and postemployment costs.
Income taxes decreased $7.1M during fiscal 2023, compared with fiscal 2022, due to lower income before income taxes.
Net income decreased $8.7M during fiscal 2023, compared with fiscal 2022, due primarily to increased O&M,
depreciation and interest expenses, partially offset by higher Utility Gross Margin, as previously discussed.
Clean Energy Ventures
Overview
CEV actively pursues opportunities in the renewable energy markets. CEV 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, CEV 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. CEV is also subject to various risks, which may include impacts to
residential solar customer growth and customer collections, our ability to identify and develop commercial solar asset
investments, impacts to our supply chain and our ability to source materials for construction.
The primary contributors toward the value of qualifying clean energy projects are tax incentives and RECs. Changes in
the federal statutes related to the ITC and/or relevant state legislation and regulatory policies affecting the market for solar
renewable energy credits could significantly affect future results.
Page 45
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Solar
Solar projects placed in service and related expenditures for the fiscal years ended September 30, are as follows:
($ in Thousands)
Placed in service
Grid-connected (1) (2)
Net-metered:
Commercial (1) (3)
Residential
Total placed in service
2023
Projects MW Costs
2022
Projects MW Costs
2021
Projects MW Costs
5 42.0 $ 106,558
3 14.0 $ 31,411
1 2.9 $ 3,433
50,610
5 36.1
339 4.1
12,677
349 82.2 $ 169,845
2,440
2 1.0
360 3.9
11,544
365 18.9 $ 45,395
1 2.7
5,576
421 4.8 13,885
423 10.4 $ 22,894
(1)
(2)
(3)
Includes projects subject to sale leaseback arrangements.
Includes an operational 2.9 MW commercial solar project acquired in December 2020.
Includes two operational commercial solar projects acquired in July 2023, totaling 20.7 MW.
CEV has approximately 468.8 MW of solar capacity in service. Projects that were placed in service through December
31, 2019, qualified for a 30% federal ITC. The credit declined to 26% for property under construction during 2020. In
December 2020, the 26% federal ITC was extended through the end of 2022. Following the signing of the Inflation Reduction
Act into law in August 2022, the federal ITC was restored to 30% through the end of 2032. There are additional opportunities to
increase the credit amount up to 20% for certain facilities that are placed in service after December 31, 2022, based upon the
type of project and location. ITC-eligible projects placed in service prior to the enactment of the Inflation Reduction Act are not
impacted by the change.
CEV 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 is responsible for
related expenses and entitled to retain the revenue generated from RECs and energy sales. The ITCs and other tax benefits
associated with these solar projects transfer to the buyer if applicable; however, the lease payments are structured so that CEV
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, CEV 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 2023, 2022 and 2021, CEV received proceeds of $167.8M, $24.1M and $17.7M,
respectively, in connection with the sale leaseback of commercial solar assets.
As part of its solar investment portfolio, CEV operates a residential and small commercial solar program, The Sunlight
Advantage®, that provides qualifying homeowners and small business owners the opportunity to have a solar system installed
at their home or place of business with no installation or maintenance expenses. CEV owns, operates and maintains the system
over the life of the contract in exchange for monthly payments.
For solar installations placed in-service in New Jersey prior to April 30, 2020, each MWh of electricity produced creates
an SREC that represents the renewable energy attribute of the solar-electricity generated that can be sold to third parties,
predominantly load-serving entities that are required to comply with the solar requirements under New Jersey’s renewable
portfolio standard.
Following the close of the SREC market in New Jersey, the BPU established the TREC as 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.
In July 2021, the BPU established a new successor solar incentive program. This Administratively Determined Incentive
Program, which we refer to as SREC IIs, provides administratively set incentives for net metered residential projects and net
metered non-residential projects of 5 MW or less.
In December 2022, the BPU established the Competitive Solar Incentive Program, which will serve as the permanent
program within the successor solar incentive program and provide incentives to larger solar facilities. It is open to qualifying
grid supply solar facilities, non-residential net metered solar installations with a capacity greater than 5MW, and eligible grid
supply solar facilities installed in combination with energy storage.
Page 46
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
REC activity consisted of the following:
Inventory balance
as of October 1,
RECs
Generated
Delivered
Inventory balance
as of September 30,
Average
Sale Price
2023
SRECs
TRECs (1)
SREC IIs (1)
2022
SRECs (2)
TRECs
2021
SRECs
TRECs (1)
116,005
10,759
247
108,104
6,944
422,039
80,520
10,260
(393,906)
(81,159)
(4,494)
425,453
38,914
(417,305)
(35,099)
35,011
9,270
406,118
31,767
(333,025)
(34,093)
144,138
10,120
6,013
116,252
10,759
108,104
6,944
$202
$144
$90
$202
$139
$196
$144
(1) The TRECs’ and SREC IIs’ inventory balance is due to the timing of the generation of the RECs and the delivery of the RECs by the state administrator,
which is typically on a one month lag.
(2) Fiscal 2022 included 247 SREC IIs within SRECs, which are shown separately in fiscal 2023. There were no SREC IIs generated during fiscal 2021.
CEV hedges its expected SREC production through the use of forward sales contracts. The following table reflects the
hedged percentage of our projected inventory of SRECs related to CEV’s in-service commercial and residential assets at
September 30, 2023:
Energy Year (1)
2024
2025
2026
2027
Percent of SRECs Hedged
100%
89%
80%
24%
(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 RECs 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 broker fees.
Operating Results
CEV’s financial results for the fiscal years ended September 30, are summarized as follows:
(Thousands)
Operating revenues
Operating expenses
Operation and maintenance
Depreciation and amortization
Total operating expenses
Operating income
Other income, net
Interest expense, net
Income tax (benefit) provision
Net income
2023
124,131 $
2022
128,280 $
$
2021
95,275
40,089
25,320
65,409
58,722
6,622
28,569
(7,683)
44,458 $
40,706
21,396
62,102
66,178
6,554
21,968
11,361
39,403 $
36,715
20,567
57,282
37,993
6,392
22,548
5,048
16,789
$
Operating revenues decreased $4.1M in fiscal 2023, compared with fiscal 2022, due primarily to decreased SREC and
electricity sales, partially offset by increased TREC sales.
Depreciation expense increased $3.9M in fiscal 2023, compared with fiscal 2022, due primarily to additional solar assets
placed in service.
Page 47
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Income tax benefit increased $19.0M during fiscal 2023, compared with fiscal 2022, due primarily to the reversal of a
valuation allowance for certain deferred tax assets.
Net income in fiscal 2023 increased $5.1M, compared with fiscal 2022, due primarily to the increased income tax benefit,
partially offset by decreased operating revenues and higher depreciation expense, as previously discussed.
Energy Services
Overview
ES 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. ES 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 ES to generate market opportunities by capturing price
differentials over specific time horizons and between geographic market locations.
ES 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 either purchase and/or deliver physical natural gas. In addition to the contractual purchase
and/or sale of physical natural gas, ES generates or pays fee-based margin in exchange for its active management and may
provide the producer and/or utility with additional margin based on actual results.
In conjunction with the active management of these contracts, ES 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, ES is able to implement strategies that allow it to capture margin by improving the
respective time or geographic spreads on a forward basis.
ES 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 revenues or natural gas purchases on the Consolidated Statements of Operations.
Volatility in reported net income at ES 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 ES
realizes the entire margin on the transaction.
During December 2020, ES entered into a series of AMAs with an investment grade public utility to release pipeline
capacity associated with certain natural gas transportation contracts. The utility provides certain asset management services, and
ES may deliver natural gas to the utility in exchange for aggregate net proceeds of approximately $500M, payable through
November 1, 2030. The AMAs include a series of initial and permanent releases, which commenced in November 2021. NJR
will receive a total of approximately $260M in cash from fiscal 2022 through fiscal 2024 and $34M per year from fiscal 2025
through fiscal 2031 under the agreements. During fiscal 2023 and 2022, ES recognized $48.5M and $53.0M, respectively, of
operating revenue on the Consolidated Statements of Operations. Amounts received in excess of revenue, totaling $58.7M and
$33.8M as of September 30, 2023 and 2022, respectively, are included in deferred revenue on the Consolidated Balance Sheets.
Page 48
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Results
ES’s financial results for the fiscal years ended September 30, are summarized as follows:
(Thousands)
Operating revenues (1)
Operating expenses
Natural gas purchases (including demand charges (2)(3))
Operation and maintenance
Depreciation and amortization
Total operating expenses
Operating income
Other income, net
Interest expense, net
Income tax provision
Net income
$
$
2023
691,616 $ 1,529,272 $ 1,228,420
2021
2022
558,932
19,351
221
578,504
113,112
1,479
11,400
24,343
78,848 $
1,394,405
39,080
148
1,433,633
95,639
512
4,725
21,776
69,650 $
1,098,261
50,885
111
1,149,257
79,163
369
2,204
18,371
58,957
(1)
(2)
(3)
Includes related party transactions of approximately $10.2M, $0.1M and $(0.4)M for fiscal 2023, 2022 and 2021, respectively, which are eliminated in
consolidation.
Costs associated with pipeline and storage capacity are expensed over the term of the related contracts, which generally varies from less than one year to
10 years.
Includes related party transactions of approximately $0.9M, $1.0M and $0.8M for fiscal 2023, 2022 and 2021, respectively, a portion of which is
eliminated in consolidation.
ES’s portfolio of financial derivative instruments is composed of:
(in Bcf)
Net short futures and swaps contracts
2023
2022
2021
6.9
0.7
13.7
During fiscal 2023, 2022 and 2021 the net short position resulted in unrealized gains (losses) of $16.2M, $(8.5)M and
$(53.5)M, respectively.
Operating revenues decreased $837.7M and natural gas purchases decreased $835.5M during fiscal 2023, compared with
fiscal 2022, due primarily to a 45.2% decrease in natural gas prices, partially offset by periods of volatility in natural gas prices
during the first two quarters of fiscal 2023.
Future results at ES are contingent upon natural gas market price volatility driven by variations in both the supply and
demand balances caused by weather and other factors. As a result, variations in weather patterns in the key market areas served
may affect earnings during the fiscal year. Changes in market fundamentals, such as an increase in supply and decrease in
demand due to warmer temperatures and reduced volatility, can negatively impact ES’s earnings. See Item 7. Management’s
Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution for TETCO M-3 Daily
Prices, which illustrates the daily natural gas prices in the Northeast market region.
O&M expense decreased $19.7M during fiscal 2023, compared with fiscal 2022, due primarily to a reduction in the
reserve for bad debt, and decreases in charitable contributions and compensation costs.
Interest expense increased $6.7M during fiscal 2023, compared with fiscal 2022, due primarily to increased borrowings at
higher interest rates.
Net income increased $9.2M during fiscal 2023, compared with fiscal 2022, due primarily to increased operating income,
partially offset by higher interest expense, as previously discussed.
Page 49
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Non-GAAP Financial Measures
Management uses Financial Margin and NFE, non-GAAP financial measures, when evaluating the operating results of
ES. Financial Margin and NFE are based on removing timing differences associated with certain derivative instruments. GAAP
also requires us, during the interim periods, to estimate our annual effective tax rate and use this rate to calculate the year-to-
date tax provision. We also determine an annual estimated effective tax rate for NFE purposes and calculate a quarterly tax
adjustment based on the differences between our forecasted net income and our forecasted NFE for the fiscal year. This
adjustment is applied to ES, as the adjustment primarily relates to timing differences associated with certain derivative
instruments that impact the estimate of the annual effective tax rate for NFE. No adjustment is needed during the fourth quarter,
since the actual effective tax rate is calculated at year end.
Management views these measures as representative of the overall expected economic result and uses these measures to
compare ES’s 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, ES’s 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 ES 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. Financial Margin differs from gross margin as defined on a GAAP basis, as it
excludes certain operations and maintenance expense and depreciation and amortization as well as the effects of derivatives as
discussed above.
Financial Margin
A reconciliation of gross margin, the closest GAAP financial measure, to ES’s Financial Margin is as follows:
(Thousands)
Operating revenues
Less:
Natural gas purchases
Operation and maintenance (1)
Depreciation and amortization
Gross margin
Add:
Operation and maintenance (1)
Depreciation and amortization
Unrealized (gain) loss on derivative instruments and related transactions (2)
Effects of economic hedging related to natural gas inventory (3)
Financial margin
2023
2022
$ 691,616 $ 1,529,272 $ 1,228,420
2021
558,932 1,394,405 1,098,261
20,199
33,263
221
111
112,264
96,785
23,709
148
111,010
20,199
221
(48,251)
34,699
$ 119,132 $
33,263
23,709
111
148
58,362
(60,000)
(42,405)
19,939
94,806 $ 146,116
(1)
(2)
(3)
Excludes general and administrative expenses of $(0.8)M, $15.4M and $17.6M for fiscal 2023, 2022 and 2021, respectively.
Includes unrealized losses (gains) related to an intercompany transaction between NJNG and ES that have been eliminated in consolidation of
approximately $7.8M, $0.1M and $(3.2)M, net of taxes for fiscal 2023, 2022 and 2021, respectively.
Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period.
Financial Margin increased $24.3M during fiscal 2023, compared with fiscal 2022, due primarily to higher natural gas
price volatility in December 2022 and February 2023, as a result of cold weather in regions where ES had contracted rights to
transportation and storage assets.
Page 50
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Net Financial Earnings
A reconciliation of ES’s net income, the most directly comparable GAAP financial measure to NFE, is as follows for the
fiscal years ended September 30:
(Thousands)
Net income
Add:
2023
2022
$ 78,848 $ 69,650 $ 58,957
2021
Unrealized (gain) loss on derivative instruments and related transactions
Tax effect (1)
Effects of economic hedging related to natural gas inventory
Tax effect
Net financial earnings
(48,251) (60,000) 58,362
11,467 14,270 (13,875)
34,699 19,939 (42,405)
(4,738) 10,078
$ 68,517 $ 39,121 $ 71,117
(8,246)
(1)
Includes taxes related to an intercompany transaction between NJNG and ES that have been eliminated in consolidation of approximately $(2.4)M and
$1.0M for fiscal 2023 and 2021, respectively. Taxes that were eliminated in consolidation during fiscal 2022 were immaterial.
NFE increased $29.4M during fiscal 2023, compared with fiscal 2022, due primarily to higher Financial Margin, as
previously discussed.
Future results are subject to ES’s ability to expand its wholesale sales and service activities and are contingent upon many
other factors, including an adequate number of appropriate and credit-qualified counterparties in an active and liquid natural
marketplace; volatility in the natural gas market due to weather or other fundamental market factors impacting supply and/or
demand; transportation, storage and/or other market arbitrage opportunities; sufficient liquidity in the overall energy trading
market; and continued access to liquidity in the capital markets.
Storage and Transportation
Overview
S&T invests in natural gas assets, such as natural gas transportation and storage facilities. We believe that acquiring,
owning and developing these storage and transportation assets, which operate under a tariff structure that has either cost- or
market-based rates, can provide us a growth opportunity. S&T is subject to various risks, including the construction,
development and operation of our transportation and storage assets, obtaining necessary governmental, environmental and
regulatory approvals, our ability to obtain necessary property rights and our ability to obtain financing at reasonable costs for
the construction, operation and maintenance of our assets.
S&T is comprised of Leaf River, a 32.2M Dth salt dome natural gas storage facility that operates under market-based
rates, and Adelphia, an existing 84-mile pipeline in southeastern Pennsylvania. Adelphia 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. In October 2020, we began the conversion of the southern zone of
the pipeline to natural gas, which became fully operational in September 2022.
S&T also has a 50% ownership interest in Steckman Ridge, a storage facility located in western Pennsylvania that
operates under market-based rates. As of September 30, 2023, our investment in Steckman Ridge was $104.1M.
S&T also has a 20% interest in PennEast, a partnership whose purpose was to construct and operate a 120-mile natural
gas pipeline that would have extended from northeast Pennsylvania to western New Jersey. PennEast received a Certificate of
Public Convenience and Necessity for the project from FERC in January 2018. However, because of numerous regulatory and
legal challenges, we evaluated our equity investment in PennEast for impairment during fiscal 2021, and determined that it was
other-than-temporarily impaired. We estimated the fair value of our investment in PennEast using probability weighted
scenarios assigned to discounted future cash flows. The impairment was the result of management’s estimates and assumptions
regarding the likelihood of certain outcomes related to required regulatory approvals and pending legal matters, the timing and
magnitude of construction costs and in-service dates, the evaluation of the current environmental and political climate as it
relates to interstate pipeline development, and transportation capacity revenues and discount rates.
Page 51
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
In December 2021, the FERC dismissed PennEast’s pending applications. The order vacated the certificate authorization
for the PennEast pipeline project in light of PennEast’s response to FERC staff’s November 2021 request for a status update, in
which PennEast informed the Commission it is no longer developing the project.
During fiscal 2022, the PennEast board of managers approved cash distributions to members of the partnership following
the sale of certain project-related assets and refunds of interconnection fees received from interstate pipelines. The return of
capital received by the Company, which totaled $11.0M, reduced the remaining carrying value of its equity method investment
in PennEast to zero, with the excess recorded in equity in earnings (loss) of affiliates in the Consolidated Statements of
Operations. The Company received additional return of capital of $0.3M during fiscal 2023, which is recognized in equity in
earnings of affiliates in the Consolidated Statements of Operations.
Operating Results
The financial results of S&T for the fiscal years ended September 30, are summarized as follows:
(Thousands)
Operating revenues (1)
Operating expenses
Natural gas purchases
Operation and maintenance
Depreciation and amortization
Total operating expenses
Operating income
Other income, net
Interest expense, net
Income tax provision (benefit)
Equity in earnings (loss) of affiliates
Net income (loss)
2023
2022
2021
$
92,859 $
67,735 $
51,020
1,601
34,648
24,185
60,434
32,425
6,850
25,803
3,444
3,126
13,154 $
2,702
30,568
12,302
45,572
22,163
8,546
12,097
1,879
9,865
26,598 $
1,266
29,135
9,960
40,361
10,659
5,931
13,348
(10,043)
(81,072)
(67,787)
$
(1)
Includes related party transactions of approximately $4.2M, $2.4M and $1.8M for the fiscal years ended September 30, 2023, 2022 and 2021,
respectively, which are eliminated in consolidation.
Operating revenue increased $25.1M during fiscal 2023, compared with fiscal 2022, due primarily to increased fixed
price contract revenue for Adelphia and increased hub services revenue for Leaf River.
O&M expense increased $4.1M during fiscal 2023, compared with fiscal 2022, due primarily to increased property taxes
and contractor expenses.
Depreciation expense increased $11.9M during fiscal 2023, compared with fiscal 2022, due primarily to the southern
portion of Adelphia, which was placed in service in September 2022.
Interest expense increased $13.7M during fiscal 2023, compared with fiscal 2022, due primarily to increased borrowings
and higher interest rates.
Equity in earnings of affiliates decreased $6.7M during fiscal 2023, compared with fiscal 2022, due primarily to a
decreased return of capital related to our equity method investment in PennEast, as previously discussed.
Net income decreased $13.4M during fiscal 2023, compared with fiscal 2022, due primarily to increased O&M,
depreciation and interest expense, along with decreased equity in earnings of affiliates, partially offset by higher operating
revenue, as previously discussed.
Page 52
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Non-GAAP Financial Measures
Management uses NFE, a non-GAAP financial measure, when evaluating the operating results of S&T. Certain
transactions associated with equity method investments and their impact, including impairment charges, which are non-cash
charges, and the return of capital in excess of the carrying value of our investment, are excluded for NFE purposes. The details
of such adjustments can be found in the table below. Non-GAAP financial measures are not in accordance with, or an
alternative to, GAAP, and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.
A reconciliation of S&T’s net income, the most directly comparable GAAP financial measure to NFE, is as follows:
(Thousands)
Net income (loss)
Add:
(Gain on) impairment of equity method investment
Tax effect
Net financial earnings
2023
2022
2021
$
13,154 $
26,598 $
(67,787)
(300)
(19)
12,835 $
(5,521)
1,377
22,454 $
92,000
(11,167)
13,046
$
NFE decreased $9.6M during fiscal 2023, compared with fiscal 2022, due primarily to increased O&M, depreciation and
interest expense, partially offset by higher operating revenue, as previously discussed.
Home Services and Other
Overview
The financial results of HSO consist primarily of the operating results of NJRHS. NJRHS provides service, sales and
installation of appliances to service contract customers and has been focused on growing its installation business and expanding
its service contract customer base. HSO also includes organizational expenses incurred at NJR.
Operating Results
The condensed financial results of HSO for the fiscal years ended September 30, are summarized as follows:
(Thousands)
Operating revenues
Income (loss) before income taxes
Income tax (benefit) provision
Net income (loss)
2023
2022
2021
57,638 $
56,182 $
52,229
3,281 $
(1,477)
4,758 $
278 $
1,059
(781) $
(1,022)
(196)
(826)
$
$
$
Operating revenues increased $1.5M during fiscal 2023, compared with fiscal 2022, due primarily to increased service
contract and installation revenue at NJRHS.
Net income increased $5.5M during fiscal 2023, compared with fiscal 2022, due primarily to increased revenue, as
previously discussed, along with decreased pension costs and increased income tax benefit.
Liquidity and Capital Resources
Our objective is to maintain an efficient consolidated capital structure that reflects the different characteristics of each
reporting segment and other business operations and provides adequate financial flexibility for accessing capital markets as
required. Our consolidated capital structure as of September 30, was as follows:
Common stock equity
Long-term debt
Short-term debt
Total
Page 53
2023
2022
39 %
54
7
100 %
38 %
52
10
100 %
New Jersey Resources Corporation
Part II
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 $15.0M and $14.7M of equity through the DRP during fiscal 2023 and 2022,
respectively. We also raised approximately $42.8M of equity by issuing approximately 948,000 shares through the waiver
discount feature of the DRP during fiscal 2023. There were no shares issued through the waiver discount feature during fiscal
2022.
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 19.5M shares of common stock for repurchase. As of September
30, 2023, we had repurchased a total of approximately 17.8M of those shares and may repurchase an additional 1.7M shares
under the approved program. There were no shares repurchased during fiscal 2023 and 2022.
Debt
NJR and its unregulated subsidiaries generally rely on cash flows generated from operating activities and the utilization
of committed credit facilities to provide liquidity to meet working capital and short-term debt financing requirements. NJNG
also relies on the issuance of commercial paper for short-term funding. NJR and NJNG, as borrowers, periodically access the
capital markets to fund long-life assets through the issuance of long-term debt securities.
We believe that our existing borrowing availability, equity proceeds and cash flows from operations will be sufficient to
satisfy our working capital, capital expenditures and dividend requirements for at least the next 12 months. NJR, NJNG, CEV,
S&T and ES currently anticipate that each of their financing requirements for the next 12 months will be met primarily through
the issuance of short- and long-term debt, and meter or solar asset sale leasebacks.
We believe that as of September 30, 2023, 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, recent geopolitical tensions and inflationary pressures, there has been uncertainty
and volatility in the credit and capital markets. We have been able to obtain sufficient financing to meet our funding
requirements for operations and capital expenditures; however, our ability to access funds from financial institutions at a
reasonable cost in the future may impact the nature and timing of future capital market transactions.
Short-Term Debt
We use our short-term borrowings primarily to finance ES’s short-term liquidity needs, S&T investments, share
repurchases and, on an initial basis, CEV’s investments. ES’s use of high-volume storage facilities and anticipated pipeline park
and loan arrangements, combined with related economic hedging activities in the volatile wholesale natural gas market, create
significant short-term cash requirements.
As of September 30, 2023, NJR had a revolving credit facility totaling $650M, with $427.0M available under the facility.
NJNG satisfies its debt needs by issuing short-term and long-term debt based on its financial profile. The seasonal nature
of NJNG’s operations creates large short-term cash requirements, primarily to finance natural gas purchases and customer
accounts receivable. NJNG obtains working capital for these requirements, and for the temporary financing of construction and
MGP remediation expenditures and energy tax payments, based on its financial profile, through the issuance of commercial
paper supported by the NJNG Credit Facility or through short-term bank loans under the NJNG Credit Facility.
NJNG’s commercial paper is sold through several commercial banks under an issuing and paying agency agreement and
is supported by the $250M NJNG Credit Facility. As of September 30, 2023, 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 $214.5M.
Page 54
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Short-term borrowings were as follows:
(Thousands)
NJR
Notes Payable to banks:
Balance at end of period
Weighted average interest rate at end of period
Average balance for the period
Weighted average interest rate for average balance
Month end maximum for the period
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
Weighted average interest rate for average balance
Month end maximum for the period
Twelve Months Ended
September 30, 2023
$
$
$
$
$
$
217,300
6.53 %
254,932
5.78 %
465,000
34,800
5.48 %
40,685
4.82 %
111,800
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
On August 30, 2022, NJR entered into a First Amendment to NJR’s Second Amended and Restated Credit Agreement
governing a $650M NJR Credit Facility with a maturity date of September 2, 2027. The NJR Credit Facility is subject to a one-
year extension beyond that date and includes an accordion feature, which allows NJR, in the absence of a default or event of
default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit
Facility in increments of $50M with the total revolving credit commitments not exceeding $750M. The NJR Credit Facility also
permits the borrowing of revolving loans and swingline loans, as well as a $75M sublimit for the issuance of letters of credit.
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 ES’s short-term liquidity needs and to finance, on an initial
basis, unregulated investments.
As of September 30, 2023, NJR had seven letters of credit outstanding totaling $5.7M, 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.
In February 2022, NJR entered into a 364-day $150M term loan credit agreement with an interest rate based on SOFR
plus 0.85%, that expired on February 7, 2023. The Company borrowed $50M on February 9, 2022 and $100M on February 14,
2022 under the term loan, which was paid in full at expiration of the term loan agreement.
Based on its average borrowings during fiscal 2023, NJR’s average interest rate was 5.78%, resulting in interest expense
of approximately $14.3M. Based on average borrowings of $254.9M during the period, a 100 basis point change in the
underlying average interest rate would have caused a change in interest expense of approximately $2.6M during fiscal 2023.
Neither NJNG nor its assets are obligated or pledged to support the NJR Credit Facility.
NJNG
On August 30, 2022, NJNG amended the Second Amended and Restated Credit Agreement governing a $250M NJNG
Credit Facility with a maturity date of September 2, 2027. The NJNG Credit Facility is subject to a one-year extension beyond
that date and 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 $50M up to a maximum of $100M. The NJNG Credit Facility also permits the borrowing of
revolving loans and swingline loans, as well as a $30M sublimit for the issuance of letters of credit.
Page 55
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
As of September 30, 2023, NJNG had two letters of credit outstanding for $0.7M, which reduced the amount available
under the NJNG Credit Facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by
the counterparties.
Based on its average borrowings during fiscal 2023, NJNG’s average interest rate was 4.82%, resulting in interest
expense of $1.5M. Based on average borrowings of $40.7M during the period, a 100 basis point change in the underlying
average interest rate would have caused a change in interest expense of approximately $0.3M during fiscal 2023.
Short-Term Debt Covenants
Borrowings under the NJR Credit Facility, term loan credit agreement 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 .70 to 1.00 for NJR and .65 to 1.00 for NJNG. These revolving credit facilities and
term loan credit agreement 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;
•
• merge, consolidate, transfer, sell or lease all or substantially all of the borrowers’ or guarantors’ assets.
enter into transactions with affiliates; and
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, 2023, NJR had the following outstanding:
•
•
•
•
•
•
•
•
•
•
•
$100M of 3.48% senior notes due November 7, 2024;
$100M of 3.54% senior notes due August 18, 2026;
$110M of 4.38% senior notes due June 23, 2027;
$100M of 3.96% senior notes due June 8, 2028;
$150M of 3.29% senior notes due July 17, 2029;
$130M of 3.50% senior notes due July 23, 2030;
$130M of 3.60% senior notes due July 23, 2032;
$80M of 3.25% senior notes due September 1, 2033;
$120M of 3.13% senior notes due September 1, 2031;
$50M of 3.64% senior notes due September 19, 2034; and
$50M of 6.14% senior notes due December 15, 2032.
Page 56
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On October 24, 2022, NJR entered into a Note Purchase Agreement, which closed on December 15, 2022, under which
NJR issued $50M senior notes at a fixed rate of 6.14%, maturing in 2032. The senior notes are unsecured and guaranteed by
certain unregulated subsidiaries of NJR.
Neither NJNG nor its assets are obligated or pledged to support NJR’s long-term debt.
NJNG
As of September 30, 2023, NJNG’s long-term debt consisted of $1.5B in fixed-rate debt issuances secured by the
Mortgage Indenture, with maturities ranging from 2024 to 2061, and $22.9M in finance leases with various maturities ranging
from 2024 to 2028.
On October 24, 2022, NJNG entered into a Note Purchase Agreement under which it sold $125M of its senior notes at an
interest rate of 5.47%, maturing in 2052.
On September 28, 2023, NJNG entered into a Note Purchase Agreement for $100M aggregate principal amount of its
senior notes consisting of $50M of 5.56% senior notes due September 28, 2033, which closed on September 28, 2023, and
$50M of 5.85% senior notes due October 30, 2053, which closed on October 30, 2023.
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 NJNG’s fixed-rate debt issuances.
Long-Term Debt Covenants and Default Provisions
The NJR and NJNG long-term debt instruments contain customary representations and warranties for transactions of their
type. They also contain customary events of default and certain covenants that will limit NJR or NJNG’s ability beyond agreed
upon thresholds to, among other things:
incur liens and encumbrances;
•
incur additional debt (including a covenant that limits the amount of consolidated total debt of the borrower at the end
of a fiscal quarter to 70% for NJR and 65% for NJNG of the consolidated total capitalization of the borrower, as those
terms are defined in the applicable agreements, and a covenant limiting priority debt to 20% of the borrower’s
consolidated total capitalization, as those terms are defined in the applicable agreements);
•
• make loans and investments;
• make dispositions of assets;
• make dividends or restricted payments;
•
• merge, consolidate, transfer, sell or lease substantially all of the borrower’s assets.
enter into transactions with affiliates; and
The aforementioned covenants are subject to a number of exceptions and qualifications set forth in the applicable note
purchase agreements.
In addition, the FMBs issued by NJNG under the Mortgage Indenture are subject to certain default provisions. Events of
Default, as defined in the Mortgage Indenture, consist mainly of:
•
•
•
•
•
•
failure for 30 days to pay interest when due;
failure to pay principal or premium when due and payable;
failure to make sinking fund payments when due;
failure to comply with any other covenants of the Mortgage Indenture after 30 days’ written notice from the Trustee;
failure to pay or provide for judgments in excess of $30M in aggregate amount within 60 days of the entry thereof; or
certain events that are or could be the basis of a bankruptcy, reorganization, insolvency or receivership proceeding.
Upon the occurrence and continuance of such an Event of Default, the Mortgage Indenture, subject to any provisions of
law applicable thereto, provides that the Trustee may take possession and conduct the business of NJNG, may sell the trust
estate or proceed to foreclose the lien of the Mortgage Indenture. The interest rate on defaulted principal and interest, to the
extent permitted by law, on the FMBs issued under the Mortgage Indenture is the rate stated in the applicable supplement or, if
no such rate is stated, 6% per annum.
Page 57
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Sale Leaseback
NJNG
NJNG received $8.4M and $17.3M in fiscal 2023 and 2022, respectively, in connection with the sale leaseback of its
natural gas meters. These transactions are treated as financing obligations that are paid over the term of the arrangement, and
NJNG has the option to purchase the meters back at fair value upon expiration. NJNG continues to evaluate this sale leaseback
program based on current market conditions. Natural gas meters are excepted and excluded from the lien on NJNG property
under the Mortgage Indenture. There were no natural gas meter sale leasebacks recorded during fiscal 2021.
CEV
CEV enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over
a period of five to 15 years. These transactions are considered failed sale leasebacks for accounting purposes and are therefore
treated as financing obligations, which are typically secured by the renewable energy facility asset and its future cash flows
from RECs and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if
applicable; however, the lease payments are structured so that CEV is compensated for the transfer of the related tax incentives.
CEV continues to operate the solar assets, including related expenses, and retain the revenue generated from RECs and energy
sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. During fiscal 2023, 2022
and 2021, CEV received proceeds of $167.8M, $24.1M and $17.7M, respectively, in connection with the sale leaseback of
commercial solar projects. The proceeds received were recognized as a financing obligation on the Consolidated Balance
Sheets.
Contractual Obligations and Capital Expenditures
As of September 30, 2023, there were NJR guarantees covering approximately $192.3M of natural gas purchases and ES
demand fee commitments and nine outstanding letters of credit totaling $6.4M, as previously mentioned, not yet reflected in
accounts payable on the Consolidated Balance Sheets.
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.
NJNG’s total capital expenditures spent or accrued during fiscal 2023 were $394.6M. During fiscal 2024 capital
expenditures are projected to be between $387M and $440M. NJNG expects to fund its obligations with a combination of cash
flows from operations, cash on hand, issuance of commercial paper, available capacity under its revolving credit facility and the
issuance of long-term debt. As of September 30, 2023, NJNG’s future MGP expenditures are estimated to be $169.4M. For a
more detailed description of MGP expenditures, see Note 14. Commitments and Contingent Liabilities in the accompanying
Consolidated Financial Statements.
During fiscal 2023, S&T had capital expenditures spent or accrued for the Adelphia project totaling $18.8M, and capital
expenditures spent or accrued for Leaf River totaling $12.2M. During fiscal 2024, we expect expenditures related to the
Adelphia project to be between $8M and $12M and expenditures related to Leaf River to be between $25M and $35M.
During fiscal 2023, total capital expenditures spent or accrued related to the purchase and installation of solar equipment
were $110.4M. CEV’s expenditures include clean energy projects that support our goal to promote renewable energy.
Accordingly, CEV enters into agreements to install solar equipment involving both residential and commercial projects. We
estimate solar-related capital expenditures for projects placed in service during fiscal 2024 to be between $140M and $204M.
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.
ES does not currently anticipate any significant capital expenditures during fiscal 2024 and 2025.
Page 58
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
During December 2020, ES entered into a series of AMAs with an investment grade public utility to release pipeline
capacity associated with certain natural gas transportation contracts. The utility provides certain asset management services, and
ES may deliver natural gas to the utility in exchange for aggregate net proceeds of approximately $500M, payable through
November 1, 2030. The AMAs include a series of initial and permanent releases which commenced in November 2021. NJR
will receive a total of approximately $260M in cash from fiscal 2022 through fiscal 2024 and $34M per year from fiscal 2025
through fiscal 2031 under the agreements. During fiscal 2023 and 2022, ES recognized $48.5M and $53.0M, respectively, of
operating revenue on the Consolidated Statements of Operations. Amounts received in excess of revenue, totaling $58.7M and
$33.8M as of September 30, 2023 and 2022, respectively, are included in deferred revenue on the Consolidated Balance Sheets.
Cash Flows
Operating Activities
Cash flows from operating activities during fiscal 2023 totaled $479.0M compared with $323.5M during fiscal 2022.
Operating cash flows are primarily affected by variations in working capital, which can be impacted by several factors,
including:
•
•
•
•
•
•
•
•
•
•
seasonality of our business;
fluctuations in wholesale natural gas prices and other energy prices, including changes in derivative asset and liability
values;
timing of storage injections and withdrawals;
the deferral and recovery of natural gas costs;
changes in contractual assets utilized to optimize margins related to natural gas transactions;
broker margin requirements;
impact of unusual weather patterns on our wholesale business;
timing of the collections of receivables and payments of current liabilities;
volumes of natural gas purchased and sold; and
timing of SREC deliveries.
The increase of $155.5M in cash flows from operating activities during fiscal 2023, compared with fiscal 2022, was due
primarily to decreased working capital requirements related to the decline in natural gas prices.
Investing Activities
Cash flows used in investing activities totaled $538.6M during fiscal 2023, compared with $590.6M during fiscal 2022.
The decrease of $52.0M was due primarily to lower capital expenditures for S&T related to the conversion of the southern
portion of Adelphia’s pipeline to natural gas, which was placed into service during September 2022, along with decreased solar
asset expenditures, partially offset by increased utility plant expenditures.
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 ES and clean energy
investments at CEV.
Cash flows from financing activities totaled $59.7M during fiscal 2023, compared with $262.5M during fiscal 2022. The
decrease of $202.8M is due primarily to the repayment of the term loan of $150.0M that was borrowed during fiscal 2022,
decreased long-term debt proceeds of $135.0M, partially offset by an increase in proceeds of $143.7M from solar sale
leasebacks, a decrease in payments of short-term debt of $81.5M and an increase of $42.8M from the waiver discount issuance
of common stock.
Page 59
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Credit Ratings
The table below summarizes NJNG’s credit ratings as of September 30, 2023, issued by two rating entities, Moody’s and
Fitch:
Corporate Rating
Commercial Paper
Senior Secured
Ratings Outlook
Moody’s
N/A
P-2
A1
Stable
Fitch
A-
F-2
A+
Stable
The Fitch ratings and outlook were reaffirmed on April 24, 2023. The Moody’s ratings and outlook were reaffirmed on
September 29, 2023. NJNG’s Moody’s and Fitch ratings are investment-grade ratings. NJR is not rated by Moody’s or Fitch.
Although NJNG is not party to any lending agreements that would accelerate the maturity date of any obligation caused
by a failure to maintain any specific credit rating, if such ratings are downgraded below investment grade, borrowing costs
could increase, as would the costs of maintaining certain contractual relationships, and future financing and our access to capital
markets would be reduced. Even if ratings are downgraded without falling below investment grade, NJR and NJNG could face
increased borrowing costs under their credit facilities. A rating set forth above is not a recommendation to buy, sell or hold
NJR’s or NJNG’s securities and may be subject to revision or withdrawal at any time. Each rating set forth above should be
evaluated independently of any other rating.
The timing and mix of any external financings will target a common equity ratio that is consistent with maintaining
NJNG’s current short-term and long-term credit ratings.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Financial Risk Management
Commodity Market Risks
Natural gas is a nationally traded commodity. Its prices are determined effectively by the NYMEX, ICE and over-the-
counter markets. The prices on the NYMEX, CME, ICE and over-the-counter markets generally reflect the national balance of
natural gas supply and demand, but are also significantly influenced from time to time by other events.
Our regulated and unregulated businesses are subject to market risk due to fluctuations in the price of natural gas. To
economically hedge against such fluctuations, we have entered into forwards, futures, options and swap agreements. To manage
these derivative instruments, we have well-defined risk management policies and procedures that include daily monitoring of
volumetric limits and monetary guidelines. Our natural gas businesses are conducted through two of our operating subsidiaries.
NJNG is a regulated utility that uses futures, options and swaps to provide relative price stability, and its recovery of natural gas
costs is governed by the BPU. ES uses futures, options, swaps and physical contracts to economically hedge purchases and
sales of natural gas.
The following table reflects the changes in the fair market value of financial derivatives related to natural gas purchases
and sales:
(Thousands)
NJNG
ES
Total
Balance
September 30,
2022
$ (6,196)
Increase
(Decrease) in Fair
Market Value
$
(27,752)
Less
Amounts
Settled
$ (40,038)
Balance
September 30,
2023
$ 6,090
(6,686)
83,704
60,840
$ (12,882)
$
55,952
$ 20,802
16,178
$ 22,268
There were no changes in methods of valuations during the fiscal year ended September 30, 2023.
Page 60
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
The following is a summary of fair market value of financial derivatives as of September 30, 2023, excluding foreign
exchange contracts discussed below, by method of valuation and by maturity for each fiscal year period:
(Thousands)
Price based on ICE
2024
2025
2026 - 2028 After 2028
Total
Fair Value
$ 21,604 $
593
$
71
$ —
$ 22,268
The following is a summary of financial derivatives by type as of September 30, 2023:
NJNG
ES
Total
Volume
Bcf
Futures
Futures
32.1
(6.9)
Price per
MMBtu
$0.97 - $5.89
$0.00 - $6.87
Amounts included
in Derivatives
(Thousands)
$ 6,090
16,178
$ 22,268
The following table reflects the changes in the fair market value of physical commodity contracts:
(Thousands)
NJNG - Prices based on other external data
ES - Prices based on other external data
Total
Balance
September 30,
2022
241
$
(20,379)
$ (20,138)
Increase
(Decrease) in Fair
Market Value
(26,852)
14,249
(12,603)
Less
Amounts
Settled
(26,166)
7,486
(18,680)
Balance
September 30,
2023
(445)
$
(13,616)
$ (14,061)
Our market price risk is predominately linked with changes in the price of natural gas at the Henry Hub, the delivery
point for the NYMEX natural gas futures contracts. Based on price sensitivity analysis, an illustrative 10% movement in the
natural gas futures contract price, for example, increases (decreases) the reported derivative fair value of all open, unadjusted
Henry Hub natural gas futures and fixed price swap positions by approximately $3.6M. This analysis does not include potential
changes to reported credit adjustments embedded in the $14.4M reported fair value.
Derivative Fair Value Sensitivity Analysis
(Thousands)
Percent increase in NYMEX natural gas futures prices
Estimated change in derivative fair value
Ending derivative fair value
Percent decrease in NYMEX natural gas futures prices
Estimated change in derivative fair value
Ending derivative fair value
Wholesale Credit Risk
0%
Henry Hub Futures and Fixed Price Swaps
10%
$
(3,611) $
$ 14,392 $ 12,587 $ 10,781 $
15%
(5,417) $
8,975 $
5%
(1,805) $
— $
20%
(7,222)
7,170
0%
(5)%
(10)%
(15)%
(20)%
— $
$
7,222
$ 14,392 $ 16,197 $ 18,003 $ 19,809 $ 21,614
3,611 $
1,805 $
5,417 $
The following is a summary of gross and net credit exposures, grouped by investment and non-investment grade
counterparties, as of September 30, 2023. Gross credit exposure for ES is defined as the unrealized fair value of derivative and
energy trading contracts, plus any outstanding wholesale receivable for the value of natural gas or power delivered and/or
financial derivative commodity contract that has settled for which payment has not yet been received. Gross credit exposure for
S&T is defined as demand and estimated usage fees for contracted services and/or market value of loan balances for which
payment has not yet been received. Net credit exposure is defined as gross credit exposure reduced by collateral received from
counterparties and/or payables, where netting agreements exist. The amounts presented in the next tables exclude accounts
receivable for NJNG retail natural gas sales and services.
Page 61
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
ES’s, CEV’s and S&T’s counterparty credit exposure as of September 30, 2023, is as follows:
(Thousands)
Investment grade
Noninvestment grade
Internally-rated investment grade
Internally-rated noninvestment grade
Total
NJNG’s counterparty credit exposure as of September 30, 2023, is as follows:
(Thousands)
Investment grade
Noninvestment grade
Internally-rated investment grade
Internally-rated noninvestment grade
Total
Gross Credit
Exposure
Net Credit
Exposure
$ 105,765
4,548
19,549
19,897
$ 149,759
$ 102,746
372
18,802
16,850
$ 138,770
Gross Credit
Exposure
Net Credit
Exposure
$ 13,464
227
794
256
$ 14,741
$ 13,112
—
679
192
$ 13,983
Due to the inherent volatility in the market price for natural gas, electricity and SRECs, the market value of contractual
positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a
counterparty failed to perform the obligations under its contract (for example, failed to make payment for natural gas received),
we could sustain a loss. This loss would comprise the loss on natural gas delivered but not paid for and/or the cost of replacing
natural gas not delivered or received at a price that exceeds the original contract price. Any such loss could have a material
impact on our financial condition, results of operations or cash flows.
Effects of Interest Rate and Foreign Currency Rate Fluctuations
We are also exposed to changes in interest rates on our debt hedges, variable rate debt and changes in foreign currency
rates for our business conducted in Canada using Canadian dollars. We do not believe an immediate 10% increase or decrease
in interest rates or foreign currency rates would have a material effect on our operating results or cash flows.
Information regarding NJR’s interest rate risk can be found in the Liquidity and Capital Resources - Debt section of Item
7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Effects of Inflation
Any change in price levels has an effect on operating results due to the capital-intensive and regulated nature of our
utility subsidiary. The Company’s operations are sensitive to increases in the rate of inflation because of its operational and
capital spending requirements in both its regulated and non-regulated businesses. We attempt to minimize the effects of
inflation through cost control, productivity improvements and regulatory actions, when appropriate. See Item 1A. Risk Factors
for additional information related to the impact of recent increases in inflation rates.
Page 62
New Jersey Resources Corporation
Part II
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 Exchange Act. 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 GAAP 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, 2023. 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, 2023, 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 GAAP.
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, 2023, which appears herein.
November 21, 2023
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New Jersey Resources Corporation
Part II
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, 2023 and 2022, 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, 2023, 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, 2023 and 2022, and the results of its operations and its cash flows for each of the three years in the period ended September
30, 2023, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United
States) (PCAOB), the Company's internal control over financial reporting as of September 30, 2023, based on criteria
established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the
Treadway Commission and our report dated November 21, 2023, expressed an unqualified opinion on the Company's internal
control over financial reporting.
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 Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements
that was communicated or required to be communicated to the audit committee and that (1) relates 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 matter below, providing a separate opinion on the critical audit matter or on the
accounts or disclosures to which it relates.
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.
Page 64
New Jersey Resources Corporation
Part II
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 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 both recovery in rates of incurred costs, and refunds 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 due to refunds to customers.
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 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 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.
/s/ Deloitte & Touche LLP
Morristown, New Jersey
November 21, 2023
We have served as the Company’s auditor since 1951.
Page 65
New Jersey Resources Corporation
Part II
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 Internal Control over Financial Reporting
We have audited the internal control over financial reporting of New Jersey Resources Corporation and subsidiaries (the
“Company”) as of September 30, 2023, based on criteria established in Internal Control — Integrated Framework (2013) issued
by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company
maintained, in all material respects, effective internal control over financial reporting as of September 30, 2023, based on
criteria established in Internal Control — Integrated Framework (2013) issued by COSO.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United
States) (PCAOB), the consolidated financial statements as of and for the year ended September 30, 2023, of the Company and
our report dated November 21, 2023, expressed an unqualified opinion on those financial statements.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its
assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report
on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control
over financial reporting based on our audit. 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 audit in accordance with the standards of the PCAOB. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was
maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting,
assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal
control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We
believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally
accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures
that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and
dispositions of the assets of the company; (2) 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 (3) 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.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements.
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.
/s/ Deloitte & Touche LLP
Morristown, New Jersey
November 21, 2023
Page 66
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,
OPERATING REVENUES
Utility
Nonutility
Total operating revenues
OPERATING EXPENSES
Natural gas purchases:
Utility
Nonutility
Related parties
Operation and maintenance
Regulatory rider expenses
Depreciation and amortization
Total operating expenses
OPERATING INCOME
Other income, net
Interest expense, net of capitalized interest
INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF
AFFILIATES
Income tax provision
Equity in earnings (loss) of affiliates
NET INCOME
EARNINGS PER COMMON SHARE
Basic
Diluted
WEIGHTED AVERAGE SHARES OUTSTANDING
Basic
Diluted
2023
2022
2021
$ 1,011,284 $ 1,127,417 $ 731,459
951,710 1,778,562 1,425,154
1,962,994 2,905,979 2,156,613
7,395
361,866
59,437
129,249
7,206
373,568
50,542
152,941
416,158
247,734
547,901
555,579 1,393,656 1,096,920
7,013
366,905
38,304
111,387
1,555,994 2,499,504 1,868,263
288,350
24,597
78,559
234,388
407,000
26,083
123,014
310,069
406,475
22,295
85,830
342,940
49,275
3,930
33,286
(83,212)
$ 264,724 $ 274,922 $ 117,890
76,195
8,177
$2.73
$2.71
$2.86
$2.85
$1.23
$1.22
97,028
97,627
96,100
96,488
96,227
96,560
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Thousands)
Fiscal years ended September 30,
Net income
Other comprehensive (loss) income, net of tax
Reclassifications of losses to net income on derivatives designated as hedging
instruments, net of tax of $(317), $(317) and $(350), respectively
Adjustment to postemployment benefit obligation, net of tax of $1,873, $(8,657) and
$(2,575), respectively
Other comprehensive (loss) income, net of tax
Comprehensive income
See Notes to Consolidated Financial Statements
Page 67
2023
2022
$ 264,724 $ 274,922 $ 117,890
2021
1,053
1,054
1,021
(6,186)
28,648
8,766
(5,133)
9,787
$ 259,591 $ 304,624 $ 127,677
29,702
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,
CASH FLOWS FROM OPERATING ACTIVITIES
2021
2023
2022
Net income
Adjustments to reconcile net income to cash flows from operating activities
Unrealized (gain) loss on derivative instruments
Impairment of equity method investment
Depreciation and amortization
Amortization of acquired wholesale energy contracts
Allowance for equity used during construction
Allowance for doubtful accounts
Non-cash lease expense
Deferred income taxes
Equivalent value of ITCs recognized on equipment financing
Manufactured gas plant remediation costs
Equity in earnings, net of distributions received from equity investees
Cost of removal - asset retirement obligations
Contributions to postemployment benefit plans
Taxes related to stock-based compensation
Changes in:
Components of working capital
Other noncurrent assets
Other noncurrent liabilities
Cash flows from operating activities
CASH FLOWS USED IN INVESTING ACTIVITIES
Expenditures for:
Utility plant
Solar equipment
Storage and transportation and other
Cost of removal
Distribution from equity investees in excess of equity in earnings
Investments in equity investees, net of return of capital
Cash flows used in investing activities
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt
Payments of long-term debt
Proceeds from term loan
Payments of term loan
(Payments of) proceeds from short-term debt, net
Proceeds from sale leaseback transactions - solar
Proceeds from sale leaseback transactions - natural gas meters
Payments of common stock dividends
Cash settlement of equity forward agreement
Proceeds from waiver discount issuance of common stock
Proceeds from issuance of common stock - DRP
Purchases of treasury stock
Tax withholding payments related to net settled stock compensation
Cash flows from financing activities
Change in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash at beginning of period
Cash, cash equivalents and restricted cash at end of period
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables
Inventories
Recovery of natural gas costs
Natural gas purchases payable
Natural gas purchases payable - related parties
Deferred revenue
Accounts payable and other
Prepaid expenses
Prepaid and accrued taxes
Restricted broker margin accounts
Customers’ credit balances and deposits
Other current assets (liabilities)
Total
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for:
Interest (net of amounts capitalized)
Income taxes
Accrued capital expenditures
See Notes to Consolidated Financial Statements
Page 68
$ 264,724
$ 274,922
$ 117,890
(38,081)
—
152,941
2,271
(7,137)
1,570
3,708
30,462
(6,986)
(9,571)
—
(1,526)
(4,706)
(588)
61,525
(97,753)
128,140
478,993
(350,304)
(107,303)
(42,757)
(40,555)
2,294
—
(538,625)
225,000
(71,934)
—
(150,000)
(21,850)
167,790
8,441
(150,973)
—
42,807
14,993
—
(4,577)
59,697
65
1,452
1,517
$
$ 112,628
67,445
(14,427)
(183,772)
8
934
7,537
(1,169)
16,415
46,364
11,664
(2,102)
61,525
$
$ 108,194
4,282
$
25,867
$
(59,906)
—
129,249
2,561
(11,243)
2,401
4,850
81,659
(7,542)
(17,538)
—
(1,289)
(6,785)
(144)
(77,687)
(38,424)
48,396
323,480
(259,081)
(146,676)
(153,378)
(39,293)
2,336
5,479
(590,613)
360,000
(68,343)
150,000
—
(103,350)
24,071
17,300
(127,704)
—
—
14,745
—
(4,177)
262,542
(4,591)
6,043
1,452
(16,658)
(80,801)
1,037
66,352
(10)
33,802
(34,259)
(406)
(1,516)
(51,165)
660
5,277
(77,687)
84,375
4,252
34,674
$
$
$
$
$
$
54,203
92,000
111,387
4,604
(20,303)
18,986
3,920
23,796
(6,482)
(17,532)
(3,046)
(1,129)
(7,669)
(159)
10,254
13,715
(3,481)
390,954
(376,312)
(87,852)
(110,130)
(50,316)
3,183
(690)
(622,117)
—
(18,007)
—
—
251,950
17,673
—
(116,960)
(2,823)
—
15,105
(27,217)
(1,938)
117,783
(113,380)
119,423
6,043
(81,366)
(25,257)
(13,124)
72,752
70
(1,763)
31,826
(1,527)
(3,449)
28,013
6,652
(2,573)
10,254
78,650
6,381
64,626
$
$
$
$
$
$
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CONSOLIDATED BALANCE SHEETS
ASSETS
(Thousands)
September 30,
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost
Construction work in progress
Nonutility plant and equipment, at cost
Construction work in progress
Total property, plant and equipment
Accumulated depreciation and amortization, utility plant
Accumulated depreciation and amortization, nonutility plant and equipment
Property, plant and equipment, net
CURRENT ASSETS
Cash and cash equivalents
Customer accounts receivable:
Billed
Unbilled revenues
Allowance for doubtful accounts
Regulatory assets
Natural gas in storage, at average cost
Materials and supplies, at average cost
Prepaid expenses
Prepaid taxes
Derivatives, at fair value
Restricted broker margin accounts
Other current assets
Total current assets
NONCURRENT ASSETS
Investments in equity method investees
Regulatory assets
Operating lease assets
Derivatives, at fair value
Intangible assets, net
Software costs
Deferred income taxes
Postemployment employee benefit assets
Other noncurrent assets
Total noncurrent assets
Total assets
See Notes to Consolidated Financial Statements
Page 69
2023
2022
$ 3,843,037 $ 3,576,691
162,087
237,428
1,767,306
142,768
5,990,539
(714,087)
(254,397)
5,022,055
1,577,259
199,679
5,515,716
(659,737)
(206,053)
4,649,926
954
1,107
97,540
19,100
(11,036)
73,587
199,501
27,022
9,741
43,046
30,755
20,796
21,071
532,077
104,134
584,830
175,740
1,564
77
8,375
28,383
18,684
61,577
983,364
222,297
13,769
(19,379)
40,086
273,644
20,324
8,572
54,501
24,635
94,261
22,270
756,087
106,571
500,666
168,520
6,385
2,348
6,120
2,928
4,388
57,477
855,403
$ 6,537,496 $ 6,261,416
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CAPITALIZATION AND LIABILITIES
(Thousands, except share data)
September 30,
CAPITALIZATION
Common stock, $2.50 par value; authorized 150,000,000 shares;
outstanding shares September 30, 2023 — 97,584,455; September 30, 2022 — 96,249,859
Premium on common stock
Accumulated other comprehensive loss, net of tax
Treasury stock at cost and other;
shares September 30, 2023 — 13,041; September 30, 2022 — 611,045
Retained earnings
Common stock equity
Long-term debt
Total capitalization
CURRENT LIABILITIES
Current maturities of long-term debt
Short-term debt
Natural gas purchases payable
Natural gas purchases payable to related parties
Deferred revenue
Accounts payable and other
Dividends payable
Accrued taxes
Regulatory liabilities
New Jersey Clean Energy Program
Derivatives, at fair value
Restricted broker margin accounts
Operating lease liabilities
Customers’ credit balances and deposits
Total current liabilities
NONCURRENT LIABILITIES
Deferred income taxes
Deferred investment tax credits
Deferred revenue
Derivatives, at fair value
Manufactured gas plant remediation
Postemployment employee benefit liabilities
Regulatory liabilities
Operating lease liabilities
Asset retirement obligation
Other noncurrent liabilities
Total noncurrent liabilities
Commitments and contingent liabilities (Note 14)
Total capitalization and liabilities
See Notes to Consolidated Financial Statements
Page 70
2023
2022
$
243,458 $
558,654
(9,959)
241,616
519,697
(4,826)
20,748
1,177,834
1,990,735
2,768,017
4,758,752
(6,805)
1,067,528
1,817,210
2,485,402
4,302,612
116,155
252,100
51,277
859
61,404
151,790
40,981
10,090
32,287
15,804
16,145
8,029
4,772
44,910
806,603
285,427
2,434
659
7,967
169,390
102,528
180,458
148,023
61,993
13,262
972,141
75,069
423,950
235,049
851
35,547
156,580
37,534
5,130
31,090
15,697
49,848
—
4,562
33,246
1,104,153
238,928
2,710
753
14,191
127,060
82,867
185,634
138,382
55,035
9,091
854,651
$ 6,537,496 $ 6,261,416
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY
(Thousands)
Balance as of September 30, 2020
Net income
Other comprehensive income
Common stock issued:
Common stock offering
Incentive compensation plan
Dividend reinvestment plan (1)
Cash dividend declared ($1.36 per share)
Treasury stock and other
Premium
on
Common
Stock
Common
Number
Stock
of Shares
95,949 $ 240,243 $ 491,982
Accumulated
Other
Comprehensive
(Loss) Income
$ (44,315)
Treasury
Stock And
Other
Retained
Earnings
Total
$
8,485 $ 947,501 $ 1,643,896
—
—
—
—
—
—
—
9,787
—
84
431
—
(754)
—
(2,823)
210
191
—
—
4,053
9,372
—
—
—
—
—
—
—
—
—
—
—
5,593
117,890
117,890
—
9,787
—
—
—
(2,823)
4,263
15,156
—
(130,781)
(130,781)
(26,526)
—
(26,526)
Balance as of September 30, 2021
95,710 240,644 502,584
(34,528)
(12,448)
934,610 1,630,862
Net income
Other comprehensive income
Common stock issued:
Incentive compensation plan
Dividend reinvestment plan (1)
Cash dividend declared ($1.4775 per share)
Treasury stock and other
—
—
193
355
—
(8)
—
—
481
491
—
—
—
—
—
29,702
—
—
274,922
274,922
—
29,702
8,665
8,450
—
(2)
—
—
—
—
—
5,800
—
—
9,146
14,741
—
(142,004)
(142,004)
(157)
—
(159)
Balance as of September 30, 2022
96,250 241,616 519,697
(4,826)
(6,805) 1,067,528 1,817,210
Net income
Other comprehensive loss
Common stock issued:
Incentive compensation plan
Dividend reinvestment plan (1)
Waiver discount
Cash dividend declared ($1.59 per share)
Treasury stock and other
—
—
136
258
948
—
(8)
—
—
—
—
—
(5,133)
—
—
264,724
264,724
—
(5,133)
339
205
4,829
6,069
1,298
28,059
—
—
—
—
—
—
—
—
—
—
8,760
13,450
—
—
—
5,168
15,034
42,807
—
(154,418)
(154,418)
5,343
—
5,343
Balance as of September 30, 2023
97,584 $ 243,458 $ 558,654
$
(9,959)
$ 20,748 $ 1,177,834 $ 1,990,735
(1) Certain shares sold through the DRP issued from treasury stock are at average cost, which may differ from the actual market price paid.
See Notes to Consolidated Financial Statements
Page 71
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
1. NATURE OF THE BUSINESS
The Company provides regulated natural gas distribution services, transmission and storage services and operates certain
unregulated businesses primarily through the following:
NJNG provides natural gas utility service to approximately 576,000 customers throughout Burlington, Middlesex,
Monmouth, Morris, Ocean and Sussex counties in New Jersey and is subject to rate regulation by the BPU. NJNG comprises
the Natural Gas Distribution segment.
NJRCEV, the Company’s clean energy subsidiary, comprises the CEV segment and invests in, owns and operates clean
energy projects, including commercial and residential solar installations located in New Jersey, Rhode Island, New York,
Connecticut, Michigan and Indiana.
NJRES comprises the ES segment. ES maintains and transacts around a portfolio of natural gas transportation and storage
capacity contracts and provides physical wholesale energy, retail energy and energy management services in the U.S. and
Canada.
NJR Midstream Holdings Corporation, which comprises the Storage and Transportation segment, invests in energy-
related ventures through its subsidiaries. The Company operates natural gas storage and transmission assets through the wholly-
owned subsidiaries of Leaf River and Adelphia and is subject to rate regulation by FERC. The Company holds a 50% combined
ownership interest in Steckman Ridge, located in Pennsylvania, which is accounted for under the equity method of accounting,
and 20% ownership interest in PennEast, which ceased operations in fiscal 2022.
NJR Retail Holdings Corporation has one principal subsidiary: NJRHS, which provides heating, central air conditioning,
standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey. NJRHS is
included in HSO operations.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The Consolidated Financial Statements include the accounts of the Company and its 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, 2023, 2022 and 2021.
Investments in entities over which the Company does not have a controlling financial interest are accounted for under the
equity method.
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, lease liabilities, 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 periodically as required. 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.
Page 72
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in
loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can
be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the
information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any
other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are
subsequently adjusted to actual results that may differ from estimates.
Revenues
Revenues from the sale of natural gas to NJNG customers are recognized in the period that natural gas is delivered and
consumed by customers, including an estimate for unbilled revenue. NJNG records unbilled revenue for natural gas services.
Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout
the month. At the end of each month, the amount of natural gas delivered to each customer after the last meter reading through
the end of the respective accounting period is estimated, and recognizes unbilled revenues related to these amounts. The
unbilled revenue estimates are based on estimated customer usage by customer type, weather effects, unaccounted-for natural
gas and the most current tariff rates.
CEV recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the
transfer of certificates as per contractual settlement schedules. The Clean Energy Act of 2018 established guidelines for the
closure of the SREC registration program to new applicants in New Jersey. The SREC program officially closed to new
qualified solar projects on April 30, 2020.
In December 2019, the BPU established the TREC as the successor to the SREC program. TRECs provide a fixed
compensation base multiplied by an assigned project factor in order to determine their value. The project factor is determined
by the type and location of the project, as defined.
In July 2021, the BPU established a new successor solar incentive program. The Administratively Determined Incentive
Program provides administratively set incentives for net metered residential projects and net metered non-residential projects of
5 MW or less. RECs generated through the production of electricity under this program are known as SREC IIs.
TRECs and SREC IIs generated are required to be purchased monthly by a REC program administrator as appointed by
the BPU. Revenue is recognized when RECs are generated and are transferred monthly based upon metered solar electricity
activity.
Revenues for ES 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. ES also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues.
During December 2020, ES entered into a series of AMAs with an investment grade public utility to release pipeline
capacity associated with certain natural gas transportation contracts, which commenced in November 2021. The AMAs include
a series of temporary and permanent releases, and revenue under these agreements is recognized as the performance obligations
are satisfied. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed-upon
term. For permanent releases of pipeline capacity, which represent a transfer of contractual rights for such capacity, revenue is
recognized upon the transfer of the underlying contractual rights. ES recognized $48.5M and $53.0M of operating revenue on
the Consolidated Statements of Operations during fiscal 2023 and 2022, respectively. Amounts received in excess of revenue
recognized totaling $58.7M and $33.8M are included in deferred revenue on the Consolidated Balance Sheets as of
September 30, 2023 and 2022, respectively.
S&T 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.
Page 73
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 ES 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, ES and NJNG 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 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)
ES
NJNG
Total
2023
2022
2021
$
74.6 $
183.4
95.4 $ 120.5
123.2
170.3
$ 258.0 $ 265.7 $ 243.7
ES expenses demand charges over the term of the service being provided.
NJNG’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 the 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.
Page 74
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 12. 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.
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.
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. ITCs at the unregulated subsidiaries of NJR are recorded on the
balance sheet as a reduction to property, plant and equipment when the property is placed in service, and recognized in earnings
as a reduction of depreciation expense over the useful lives of the related assets.
Investments in Equity Investees
The Company accounts for its investment in Steckman Ridge 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% 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. See Note 7. Investments in Equity Investees for more information regarding impairments.
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 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 the Company’s nonutility entities,
and is computed 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 2.68% of average depreciable property in fiscal 2023, 2.66% in fiscal 2022
and 2.42% in fiscal 2021. The Company recorded $152.9M, $129.2M and $111.4M in depreciation expense during fiscal 2023,
2022 and 2021, respectively.
Page 75
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Property, plant and equipment was comprised of the following as of September 30:
(Thousands)
Property Classifications
Distribution facilities
Transmission facilities
Storage facilities
Solar property
Storage and transportation property
All other property
Construction work in progress
Total property, plant and equipment
Accumulated depreciation and amortization
Property, plant and equipment, net
Estimated
Useful Lives
11 to 54 years
28 to 42 years
27 to 86 years
20 to 35 years
5 to 50 years
5 to 40 years
2023
3,063,111 $
650,817
85,603
864,838
884,647
61,327
380,196
5,990,539
(968,484)
5,022,055 $
2022
2,797,936
649,241
85,449
710,224
850,186
60,914
361,766
5,515,716
(865,790)
4,649,926
$
$
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, 2023 and 2022, the base gas had a cost basis of $20.9M and $15.1M,
respectively.
Capitalized and Deferred Interest
NJNG’s base rates include the ability to recover AFUDC on its construction work in progress. For all NJNG construction
projects, an incremental cost of equity is recoverable during periods when NJNG’s short-term debt balances are lower than its
construction work in progress. For more information on AFUDC treatment with respect to certain accelerated infrastructure
projects, see Note 4. Regulation - Infrastructure Programs. Capitalized amounts associated with the debt and equity
components of NJNG’s AFUDC are recorded in utility plant on the Consolidated Balance Sheets. Corresponding amounts for
the debt component are recognized in interest expense and in other income for the equity component on the Consolidated
Statements of Operations.
Adelphia’s base rates include the ability to recover AFUDC on its construction work in progress. Capitalized amounts
associated with Adelphia’s AFUDC are recorded in nonutility plant on the Consolidated Balance Sheets. Corresponding
amounts for the debt component are recognized in interest expense and in other income for the equity component on the
Consolidated Statements of Operations.
Capitalized and deferred interest include the following for the fiscal years ended September 30:
($ in thousands)
AFUDC:
Debt
Equity
Total
Weighted average interest rate
2023
2022
2021
NJNG
$
3,546
6,979
$ 10,525
6.41 %
$
$
Adelphia
90
158
248
8.28 %
$
$
NJNG
1,648
4,169
5,817
4.91 %
$
Adelphia
4,019
7,074
$ 11,093
NJNG
Adelphia
$
5,648
16,605
$ 22,253
$
$
2,101
3,698
5,799
8.28 %
5.97 %
8.28 %
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 4.79%, 3.85% and 1.68% for the fiscal years
ended September 30, 2023, 2022 and 2021, respectively. Accordingly, other income included $1.8M, $0.9M and $0.3M in the
fiscal years ended September 30, 2023, 2022 and 2021, respectively.
CEV 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. Corresponding amounts are
recognized in interest expense on the Consolidated Statements of Operations.
Page 76
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Cash and Cash Equivalents
Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less,
and excludes restricted cash related to escrow balances for utility plant projects at NJNG, which are recorded in other
noncurrent assets on the Consolidated Balance Sheets.
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 Consolidated Statements of Cash Flows, as of September 30:
(Thousands)
Balance Sheet
Cash and cash equivalents
Restricted cash in other noncurrent assets
Statements of Cash Flow
Cash, cash equivalents and restricted cash
Allowance for Doubtful Accounts
2023
2022
2021
$
$
$
954 $
563 $
1,107 $
345 $
4,749
1,294
1,517 $
1,452 $
6,043
The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into
portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for
evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio
segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on
uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include
changing weather, commodity prices, regulations and macroeconomic factors, such as unemployment rates among others.
Loans Receivable
NJNG currently provides loans, with terms ranging from two to 10 years, to customers that elect to purchase and install
certain energy-efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at
fair value on the Consolidated Balance Sheets. The Company has $15.1M and $14.5M recorded in other current assets and
$39.0M and $34.7M in other noncurrent assets as of September 30, 2023 and 2022, respectively, on the Consolidated Balance
Sheets, related to the loans. The Company regularly evaluates the credit quality and collection profile of its customers. If NJNG
determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of September 30,
2023 and 2022, the Company has not recorded any impairments for SAVEGREEN loans.
Regulatory Assets & Liabilities
Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and
earn a reasonable rate of return on their utility investment.
NJNG is subject to accounting requirements resulting from the effects of rate regulation by the BPU. Accordingly, NJNG
capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes
certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See
Note 4. Regulation for a more detailed description of NJNG’s regulatory assets and liabilities.
Adelphia capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and
recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance
Sheets. See Note 4. Regulation for a more detailed description of Adelphia’s regulatory assets and liabilities.
Page 77
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Natural Gas in Storage
Natural gas in storage is reflected at average cost on the Consolidated Balance Sheets and represents natural gas and LNG
that will be utilized in the ordinary course of business. The following table summarizes natural gas in storage, at average cost by
company, as of September 30:
($ in thousands)
NJNG
ES
Total
Derivative Instruments
2023
2022
Natural Gas in Storage Bcf Natural Gas in Storage Bcf
$
$
175,025 29.1
24,476 14.6
199,501 43.7
$ 191,175 29.0
82,469 10.8
$ 273,644 39.8
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 ES, 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. Cash flows from derivative
financial instruments are included in cash flows from operating activities on the Consolidated Statements of Cash Flows.
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 CEV. 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 ES 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 is amortized into
earnings over the term of the associated debt as a component of interest expense on the Consolidated Statements of Operations.
As of both September 30, 2023 and 2022, amounts recognized in interest expense related to the amortization of the loss on
treasury lock transactions totaled $0.2M for NJNG and $1.1M for NJR.
Page 78
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Software Costs
The Company capitalizes certain costs, such as software design and configuration, coding, testing and installation, that
are incurred to purchase or create and implement computer software for internal use. Capitalized costs include external costs of
materials and services utilized in developing or obtaining internal-use software and payroll and payroll-related costs for
employees who are directly associated with and devote time to the internal-use software project. Maintenance costs are
expensed as incurred. Upgrades and enhancements are capitalized if it is probable that such expenditures will result in
additional functionality. Amortization is recorded on the straight-line basis over the estimated useful lives.
The following table presents the software costs included in the Consolidated Financial Statements, as of September 30:
(Thousands)
Balance Sheets
Utility plant, at cost
Construction work in progress
Nonutility plant and equipment, at cost
Accumulated depreciation and amortization, utility plant
Accumulated depreciation and amortization, nonutility plant and equipment
Software costs
Statements of Operations
Operation and maintenance (1)
Depreciation and amortization
(1) During both fiscal 2023 and 2022, $0.5M was amortized from software costs into O&M.
Intangible Assets
2023
2022
$
$
$
$
$
$
$
$
51,282 $
55,012 $
344 $
(7,480) $
(36) $
8,375 $
40,437
14,381
344
(3,361)
(25)
6,120
14,299 $
4,130 $
11,141
2,024
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, 2023, intangible assets
consist primarily of acquired wholesale natural gas energy contracts totaling $0.1M, which will be fully amortized during fiscal
2024.
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 2023 and 2022, there were no events or circumstances that indicated that the carrying value
of long-lived assets or finite-lived intangibles was 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.
Page 79
New Jersey Resources Corporation
Part II
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.
In addition, for certain of its commercial solar energy projects, the Company enters into lease agreements that provide for
the sale of commercial solar energy assets to third parties and the concurrent leaseback of the assets. For sale leaseback
transactions where the Company has concluded that the arrangement does not qualify as a sale as the Company retains control
of the underlying assets, 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.
The Company continues to operate the solar assets and is responsible for related expenses and entitled to retain the
revenue generated from SRECs, TRECs, SREC IIs 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 CEV is compensated for the transfer of the related
tax attributes. Accordingly, CEV 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.
See Note 9. Debt for more details regarding sale leaseback transactions recorded as financing arrangements.
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 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 14. 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 during fiscal 2023 and
2022.
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 $4.2M and $6.1M in aggregate to these plans during fiscal 2023 and 2022,
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.
Page 80
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 CEV’s 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 CEV’s 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.
The following is an analysis of the change in the Company’s ARO for the fiscal years ended September 30:
(Thousands)
2023
NJNG
NJRCEV
2022
NJNG
NJRCEV
Balance at
October 1
Accretion
Additions
Change in
assumptions Retirements
Balance at
period end
$
$
$
$
49,874
5,161
41,611
4,694
2,693
213
2,052
186
155
1,334
161
281
4,089
—
7,339
—
(1,526) $
— $
55,285
6,708
(1,289) $
— $
49,874
5,161
Accretion for the next five years, for the fiscal years ended September 30, is estimated to be as follows:
(Thousands)
Estimated Accretion
2024
2025
2026
2027
2028
Total
$
3,114
3,268
3,429
3,597
3,781 $
17,189
Page 81
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Accumulated Other Comprehensive Income
The following table presents the changes in the components of accumulated other comprehensive income, net of related
tax effects:
(Thousands)
Balance as of September 30, 2021
Other comprehensive income, net of tax
Other comprehensive income, before reclassifications, net of tax of $0,
$(7,727) and $(7,727), respectively
Amounts reclassified from accumulated other comprehensive income, net of
tax of $(317), $(930) and $(1,247), respectively
Net current-period other comprehensive income, net of tax of $(317),
$(8,657) and $(8,974), respectively
Balance as of September 30, 2022
Other comprehensive income, net of tax
Cash Flow
Hedges
(9,376)
$
Postemployment
Benefit
Obligation
(25,152)
$
Total
$ (34,528)
—
1,054
25,580
25,580
3,068 (1)
4,122
1,054
(8,322)
$
$
28,648
3,496
29,702
$ (4,826)
Other comprehensive income, before reclassifications, net of tax of $0,
$1,922 and $1,922, respectively
Amounts reclassified from accumulated other comprehensive income, net of
tax of $(317), $(49) and $(366), respectively
Net current-period other comprehensive income, net of tax of $(317), $1,873
and $1,556, respectively
Balance as of September 30, 2023
—
1,053
(6,350)
(6,350)
164 (1)
1,217
1,053
(7,269)
$
$
(6,186)
(2,690)
(5,133)
$ (9,959)
(1)
Included in the computation of net periodic pension cost, a component of operations and maintenance expense on the Consolidated Statements of
Operations. For more details, see Note 11. Employee Benefit Plans.
Foreign Currency Transactions
The market area of ES includes Canadian delivery points and, as a result, ES 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, 2023, 2022 and 2021, are considered immaterial.
Reclassification
Certain prior period amounts have been reclassified to conform to the current period presentation. Deferred income taxes
and postemployment employee benefit assets previously classified within other noncurrent assets on the Consolidated Balance
Sheets have been reclassified to their own category.
Recently Adopted Updates to the Accounting Standards Codification
Debt and Other
In August 2020, the FASB issued ASU No. 2020-06, an amendment to ASC 470, Debt, and ASC 815, Derivatives and
Hedging, which changes the accounting for convertible instruments by reducing the number of acceptable accounting models to
three models, including the embedded derivative, substantial premium and traditional no proceeds allocated models. The
Company adopted this guidance on October 1, 2022. The Company does not currently have convertible debt instruments, and as
a result there was no impact on its financial position, results of operations, cash flows and disclosures upon adoption.
In May 2021, the FASB issued ASU No. 2021-04, an amendment to ASC 470, Debt, ASC 260, Earnings per Share, ASC
718, Stock Compensation, and ASC 815, Derivatives and Hedging. The update impacts equity-classified written call options
that remain equity-classified after a modification or exchange. The Company adopted this guidance on October 1, 2022, on a
prospective basis. As the Company does not currently have equity-classified written call options, there was no impact on its
financial position, results of operations, cash flows and disclosures upon adoption.
Page 82
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Leases
In July 2021, the FASB issued ASU No. 2021-05, an amendment to ASC 842, Leases, which requires a lessor to classify a
lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another
classification, including sales-type or direct financing, would trigger a loss at the lease commencement date. The Company
adopted this guidance on October 1, 2022, on a prospective basis. The Company currently does not have any leases that meet
this criteria, and as such there was no impact on its financial position, results of operations, cash flows and disclosures upon
adoption.
Other Recent Updates to the Accounting Standards Codification
Business Combinations
In October 2021, the FASB issued ASU No. 2021-08, an amendment to ASC 805, Business Combinations, which requires
that an acquirer recognize and measure contract assets and contract liabilities acquired in a business combination in accordance
with Topic 606, Revenue from Contracts with Customers. The guidance is effective for the Company beginning October 1,
2023, and the Company will apply the updated guidance on a prospective basis to new acquisitions following the date of
adoption.
In August 2023, the FASB issued ASU No. 2023-05, an amendment to ASC 805, Business Combinations, which
addresses how a joint venture should recognize contributions received upon its formation. Joint ventures must account for initial
assets and liabilities received at fair value on the date the joint venture is formed. The guidance is effective for the Company for
joint ventures formed beginning January 1, 2025, and the Company can elect to apply it either prospectively or retrospectively
back to a joint venture’s formation date provided adequate information is available. Early adoption is permitted. This
amendment would only impact the Company upon adoption if, in the future, it entered into an applicable transaction.
Derivatives and Hedging
In March 2022, the FASB issued ASU No. 2022-01, an amendment to ASC 815, Derivatives and Hedging, which
addresses fair value hedge accounting of interest rate risk for portfolios of financial assets. This update further clarifies
guidance previously released in ASU 2017-12, which established the “last-of-layer” method, and this update renames that
method as the “portfolio layer” method. The guidance is effective for the Company beginning October 1, 2023, and the
transition method can be on a prospective basis for a multiple-layer hedging strategy or a modified retrospective basis for a
portfolio layer method. As the Company does not currently apply hedge accounting to any of its risk management activities, the
amendment will have no impact on its financial position, results of operations, cash flows and disclosures upon adoption.
Financial Instruments
In March 2022, the FASB issued ASU No. 2022-02, an amendment to ASC 326, Financial Instruments-Credit Losses,
which eliminates the accounting guidance for creditors in troubled debt restructuring. It also aligns conflicting disclosure
requirement guidance in ASC 326 by requiring disclosure of current-period gross write-offs by year of origination. The
amendment also adds new disclosures for creditors with loan refinancing and restructuring for borrowers experiencing financial
difficulty. The guidance is effective for the Company beginning October 1, 2023, and the Company can elect to apply it on
either a modified retrospective or prospective basis. At this time, the Company has not experienced a troubled debt
restructuring, and therefore the amendments will have no impact on its financial position, results of operations, cash flows and
disclosures upon adoption.
Fair Value Measurement
In June 2022, the FASB issued ASU No. 2022-03, an amendment to ASC 820, Fair Value Measurement. The amendment
clarifies the fair value principles when measuring the fair value of an equity security subject to a contractual sale restriction.
The guidance is effective for the Company on October 1, 2024, and will be applied on a prospective basis. At this time, the
Company does not have equity securities subject to contractual sale restrictions, and therefore this amendment would only
impact the Company upon adoption if, in the future, it entered into such transactions.
Page 83
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Leases
In March 2023, the FASB issued ASU No. 2023-01, an amendment to ASC 842, Leases, which applies to arrangements
between related parties under common control. This update requires that all entities with common control arrangements classify
and account for these leases on the same basis as an arrangement with an unrelated party. If the lessee in these types of
arrangements continues to control the use of the underlying asset through a lease, the leasehold improvements are to be
amortized over the improvements’ useful life to the common control group, regardless of the lease term. The guidance is
effective for the Company on October 1, 2024, and the Company can elect to apply it either on a prospective basis or
retrospectively beginning October 1, 2019, representing the date which the Company adopted ASC 842. The Company is
currently evaluating the amendment to understand the impact on its financial position, results of operations, cash flows and
disclosures upon adoption.
3. REVENUE
Revenue is recognized when a performance obligation is satisfied by transferring control of a product or service to a
customer. Revenue is measured based on consideration specified in a contract with a customer using the output method of
progress. The Company elected to apply the invoice practical expedient for recognizing revenue, whereby the amounts invoiced
to customers represent the value to the customer and the Company’s performance completion as of the invoice date. Therefore
the Company does not disclose related unsatisfied performance obligations. The Company also elected the practical expedient
to exclude from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales
tax net in operating revenues on the 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/
Operations
NJNG
Performance
Obligation
Natural gas
utility sales
CEV
Commercial
solar electricity
CEV
Residential
solar electricity
Description
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.
CEV operates wholly-owned solar projects that recognize revenue as electricity is generated
and transferred to the customer. The performance obligation is to provide electricity to the
customer in accordance with contract terms or the interconnection agreement and is satisfied
upon transfer of electricity generated.
Revenue is recognized as invoiced and the payment is due each month for the previous
month's services.
CEV 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.
Page 84
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Segment/
Operations
CEV
Revenue Recognized Over Time (continued):
Performance
Obligation
Renewable
energy
certificates
Description
Certain CEV projects generate TRECs and SREC IIs under the established Administratively
Determined Incentive Program. A TREC or SREC II is created for every MWh of electricity
produced by a solar generator. The performance obligation of CEV is to generate electricity.
TRECs and SREC IIs under the Administratively Determined Incentive Program are
purchased monthly by a REC Administrator.
ES
Natural gas
services
S&T
Natural gas
services
HSO
Service
contracts
Revenue is recognized upon generation.
The performance obligation of ES is to provide the customer transportation, storage and
asset management services on an as-needed basis. ES 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. ES invoices customers in line with the terms of the
contract and based on the services provided. Payment is due upon receipt of the invoice. For
temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over
the agreed upon term.
The performance obligation of S&T is to provide the customer with storage and
transportation services. S&T generates revenues from firm storage contracts and
transportation contracts, injection and withdrawal at the storage facility and the delivery of
natural gas to customers. Revenue is recognized over time as customers receive the benefits
of its service as it is performed on their behalf using an output method based on actual
deliveries.
Demand fees are recognized as revenue over the term of the related agreement.
Home Services enters into service contracts with homeowners to provide maintenance and
replacement of applicable heating, cooling or ventilation equipment. NJR Retail enters into
warranty contracts with homeowners for various appliances. 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:
ES
Natural gas
services
For a permanent release of pipeline capacity, the performance obligation of ES is the release
of the pipeline capacity associated with certain natural gas transportation contracts and the
transfer of the underlying contractual rights to the counterparty.
S&T
Natural gas
services
Revenue is recognized upon the transfer of the underlying contractual rights.
The performance obligation of S&T is to provide the customer with storage and
transportation services. S&T generates revenues from usage fees and hub services for the
use of storage space, injection and withdrawal from the storage facility. Hub services
include park and loan transactions and wheeling.
HSO
Usage fees and hub services revenues are recognized as services are performed.
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.
Page 85
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Disaggregated revenues from contracts with customers by product line and by reporting segment and other business
operations during fiscal 2023, 2022 and 2021 are as follows:
NJNG
CEV
ES
S&T
HSO
Total
(Thousands)
2023
Natural gas utility sales (1)
Natural gas services
Service contracts
Installations and maintenance
Renewable energy certificates
Electricity sales
Eliminations (2)
Revenues from contracts with customers
Alternative revenue programs (3)
Derivative instruments
Eliminations (2)
Revenues out of scope
Total operating revenues
2022
Natural gas utility sales (1)
Natural gas services
Service contracts
Installations and maintenance
Renewable energy certificates
Electricity sales
Eliminations (2)
Revenues from contracts with customers
Alternative revenue programs (3)
Derivative instruments
Eliminations (2)
Revenues out of scope
Total operating revenues
2021
Natural gas utility sales
Natural gas services
Service contracts
Installations and maintenance
Renewable energy certificates
Electricity sales
Eliminations (2)
Revenues from contracts with customers
Alternative revenue programs (3)
Derivative instruments
Eliminations (2)
Revenues out of scope
Total operating revenues
$
$
845,392
—
—
—
—
—
(1,349)
844,043
27,257
139,984
—
167,241
$ 1,011,284
$
951,626
—
—
—
—
—
(1,350)
950,276
11,259
165,882
—
177,141
$ 1,127,417
$
694,635
—
—
—
—
—
—
694,635
(7,282)
44,443
—
37,161
731,796
—
—
—
—
12,636
31,733
—
44,369
—
79,762
—
79,762
124,131
—
—
—
—
5,487
38,317
—
43,804
—
84,476
—
84,476
128,280
—
—
—
—
4,571
25,270
—
29,841
—
65,434
—
65,434
95,275
—
76,975
—
—
—
—
—
76,975
—
614,641
(10,170)
604,471
681,446
—
83,801
—
—
—
—
—
83,801
—
1,445,471
(94)
1,445,377
1,529,178
—
26,933
—
—
—
—
—
26,933
—
1,201,487
426
1,201,913
1,228,846
(4)
(4)
(4)
—
92,859
—
—
—
—
(4,159)
88,700
—
—
—
—
88,700
—
67,735
—
—
—
—
(2,449)
65,286
—
—
—
—
65,286
—
51,020
—
—
—
—
(1,768)
49,252
—
—
—
—
49,252
— $ 845,392
169,834
—
35,210
35,210
22,428
22,428
12,636
—
31,733
—
(5,713)
(205)
57,433 1,111,520
27,257
834,387
(10,170)
851,474
57,433 $ 1,962,994
—
—
—
—
— $ 951,626
151,536
—
33,932
33,932
22,250
22,250
5,487
—
38,317
—
(4,163)
(364)
55,818 1,198,985
—
11,259
— 1,695,829
(94)
—
— 1,706,994
55,818 $ 2,905,979
694,635
—
77,953
—
33,250
33,250
18,979
18,979
4,571
—
25,270
—
(2,553)
(785)
852,105
51,444
—
(7,282)
— 1,311,364
426
—
— 1,304,508
51,444 2,156,613
(1)
(2)
(3)
(4)
Includes building rent related to the Wall headquarters, which is eliminated in consolidation.
Consists of transactions between subsidiaries that are eliminated in consolidation.
Includes CIP revenue.
Includes SREC revenue.
Page 86
New Jersey Resources Corporation
Part II
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)
2023
Residential
Commercial and industrial
Firm transportation
Interruptible, off-tariff and other
Revenues out of scope
Total operating revenues
2022
Residential
Commercial and industrial
Firm transportation
Interruptible, off-tariff and other
Revenues out of scope
Total operating revenues
2021
Residential
Commercial and industrial
Firm transportation
Interruptible, off-tariff and other
Revenues out of scope
Total operating revenues
NJNG
CEV
ES
S&T
HSO
Total
$
621,663
136,011
77,722
8,647
167,241
$ 1,011,284
$
586,678
265,970
92,531
5,097
177,141
$ 1,127,417
$
$
487,018
124,519
79,256
3,842
37,161
731,796
13,668
30,701
—
—
79,762
124,131
—
76,975
—
—
604,471
681,446
12,579
31,225
—
—
—
83,801
—
—
84,476 1,445,377
128,280 1,529,178
11,319
18,522
—
—
—
26,933
—
—
65,434 1,201,913
95,275 1,228,846
—
88,700
—
—
—
88,700
—
65,286
—
—
—
65,286
—
49,252
—
—
—
49,252
57,091 $
342
—
—
—
692,422
332,729
77,722
8,647
851,474
57,433 $ 1,962,994
55,629 $
189
—
—
—
654,886
446,471
92,531
5,097
1,706,994
55,818 $ 2,905,979
50,689 $
755
—
—
—
549,026
219,981
79,256
3,842
1,304,508
51,444 $ 2,156,613
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 are as follows:
(Thousands)
Balance as of September 30, 2021
Increase
Balance as of September 30, 2022
(Decrease) increase
Balance as of September 30, 2023
Customer Accounts Receivable Customers’Credit
Billed
Unbilled
Balances and
Deposits
$
$
212,838 $
9,459
222,297
(124,757)
97,540 $
10,351 $
3,418
13,769
5,331
19,100 $
32,586
660
33,246
11,664
44,910
The following table provides information about receivables, which are included within accounts receivable, billed and
unbilled, and customers’ credit balances and deposits, respectively, on the Consolidated Balance Sheets as of September 30:
(Thousands)
2023
Customer accounts receivable
Billed
Unbilled
Customers’ credit balances and deposits
Total
2022
Customer accounts receivable
Billed
Unbilled
Customers’ credit balances and deposits
Total
NJNG
CEV
ES
S&T
HSO
Total
$
$
$
$
55,234
10,784
(44,898)
21,120
9,962
8,316
—
18,278
23,716
—
—
23,716
78,508
10,814
(33,246)
56,076
5,566
2,955
—
8,521
129,199
—
—
129,199
6,577
—
(12)
6,565
7,012
—
—
7,012
2,051 $
—
—
2,051 $
97,540
19,100
(44,910)
71,730
2,012 $ 222,297
13,769
(33,246)
2,012 $ 202,820
—
—
Page 87
New Jersey Resources Corporation
Part II
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
on 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 filings to the BPU for review of its BGSS, CIP and other programs and related rates. Annual rate changes are typically
requested to be effective at the beginning of the following fiscal year. The current base rates include a weighted average cost of
capital of 6.84% and a return on common equity of 9.6%. All rate and program changes are subject to proper notification and
BPU review and approval. In addition, NJNG is permitted to implement certain BGSS rate changes on a provisional basis with
proper notification to the BPU.
Page 88
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Regulatory assets and liabilities included on the Consolidated Balance Sheets for NJNG are comprised of the following,
as of September 30:
(Thousands)
Regulatory assets-current
New Jersey Clean Energy Program
Conservation Incentive Program
Derivatives at fair value, net
Other current regulatory assets
Total current regulatory assets
Regulatory assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries
Liability for future expenditures
Deferred income taxes
SAVEGREEN
Postemployment and other benefit costs
Deferred storm damage costs
Cost of removal
Other noncurrent regulatory assets
Total noncurrent regulatory assets
Regulatory liability-current
Overrecovered natural gas costs
Derivatives at fair value, net
Total current regulatory liabilities
Regulatory liabilities-noncurrent
Tax Act impact (1)
Derivatives at fair value, net
Other noncurrent regulatory liabilities
Total noncurrent regulatory liabilities
2023
2022
15,804 $
50,356
6,017
1,410
73,587 $
15,697
23,099
—
1,290
40,086
66,298 $
169,390
41,667
83,589
55,274
—
112,362
51,019
579,599 $
66,149
127,070
40,520
52,690
56,021
2,172
104,850
45,828
495,300
30,637 $
—
30,637 $
17,807
7,972
25,779
180,347 $
—
111
180,458 $
185,367
116
151
185,634
$
$
$
$
$
$
$
$
(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. The Tax Act is an Act to Provide for Reconciliation Pursuant to Titles II and V of the Concurrent Resolution on the Budget for Fiscal Year
2018, previously known as The Tax Cuts and Jobs Act of 2017.
Other noncurrent regulatory assets include deferred pandemic costs of approximately $3.9M and $6.9M as of
September 30, 2023 and 2022, respectively, primarily related to a portion of bad debt associated with customer accounts
receivable resulting from the impacts of the COVID-19 pandemic. These costs are eligible for future regulatory recovery. On
January 5, 2023, NJNG advised the BPU that it will cease deferring COVID-19 costs as of December 31, 2022, and will seek
recovery of its regulatory asset balance in its next base rate proceeding.
Regulatory assets and liabilities included on the Consolidated Balance Sheets for Adelphia are comprised of the
following, as of September 30:
(Thousands)
Total noncurrent regulatory assets
Total current regulatory liabilities
2023
2022
$
$
5,231 $
1,650 $
5,366
5,311
The assets are comprised primarily of the tax benefit associated with the equity component of AFUDC and the liability
consists primarily of scheduling penalties. Recovery of regulatory assets is subject to FERC approval.
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 2024. NJNG recovers the costs
associated with its portion of the NJCEP obligation through its NJCEP rider, with interest.
Page 89
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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.
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.
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 14. 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.
Page 90
New Jersey Resources Corporation
Part II
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.
Overrecovered 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 returns 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.
The following is a description of certain regulatory proceedings during fiscal 2022 and 2023:
On November 2021, the BPU issued an order adopting a stipulation of settlement approving a $79.0M increase to base
rates, effective December 1, 2021. The increase includes an overall rate of return on rate base of 6.84%, return on common
equity of 9.6%, a common equity ratio of 54.0% and a depreciation rate of 2.78%.
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:
•
•
•
•
•
In November 2020, NJNG notified the BPU of its intent to provide BGSS bill credits to residential and small
commercial sales customers effective December 1, 2020 to December 31, 2020. In December 2020, NJNG notified
the BPU of the extension of the BGSS bill credits through January 2021. The actual bill credits given to customers
totaled $20.6M, $19.3M net of tax.
2021 BGSS/CIP filing — In May 2021, NJNG submitted to the BPU the annual petition to modify its BGSS,
balancing charge and CIP rates. In November 2021, the BPU approved a $2.9M increase to the annual revenues
credited to BGSS and a $13.0M annual increase related to its balancing charge, as well as changes to CIP rates, which
will result in a $6.3M decrease to the annual recovery, effective December 1, 2021.
In November 2021, the BPU approved, on a preliminary basis, NJNG’s annual petition to modify its BGSS, balancing
charge and CIP rates for residential and small commercial customers. The rate changes resulted in a $2.9M increase to
the annual revenues credited to BGSS and a $13.0M annual increase related to its balancing charge, as well as changes
to CIP rates, which resulted in a $6.3M annual recovery decrease, effective December 1, 2021, and was approved on a
final basis in May 2022.
In November 2021, NJNG submitted notification of its intent to self-implement an increase to its BGSS rate which
results in an approximate $24.2M increase to annual revenues credited to BGSS, effective December 1, 2021.
2022 BGSS/CIP filing — In June 2022, NJNG submitted its annual petition to modify its BGSS, balancing charge and
CIP rates for residential and small commercial customers. In September 2022, the BPU approved, on a preliminary
basis, an $81.9M increase to the annual revenues credited to BGSS and a $9.0M annual increase related to its
balancing charge, as well as a $10.2M increase to CIP rates, effective October 1, 2022, which was approved on a final
basis on April 12, 2023.
Page 91
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
• On February 22, 2023, NJNG advised the BPU of a bill credit and a reduction to the BGSS rate for residential and
small commercial customers, which reduced recoveries by approximately $29.9M, effective March 1, 2023, and was
approved on a final basis by the BPU on April 12, 2023. Bill credits provided to customers from March 2023 through
May 2023, totaled approximately $32.4M.
•
2023 BGSS/CIP filing — On June 1, 2023, NJNG filed its annual petition to modify its BGSS, balancing charge and
CIP rates for residential and small business customers. This includes a $38.6M decrease to the annual revenues
credited to BGSS, a $7.4M annual decrease related to its balancing charge and a $27.5M increase to CIP rates,
effective October 1, 2023. On September 18, 2023, the BPU approved, on a provisional basis, the filed BGSS and
balancing charge changes and a $27.0M increase to CIP rates, based on updated information since the initial filing.
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. In March 2021, the BPU approved a three-year SAVEGREEN program that
included $126.1M of direct investment, $109.4M in financing options and $23.4M in operation and maintenance expenses.
SAVEGREEN investments and costs are filed with the BPU on an annual basis. NJNG’s annual EE filings are
summarized as follows:
•
•
•
•
2020 EE filing — In May 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 results in an annual
recovery of approximately $11.4M, effective November 1, 2020.
2021 EE filing — In June 2021, NJNG submitted its annual cost recovery filing for the SAVEGREEN programs
established from 2010 through 2018. In January 2022, the BPU approved the stipulation to resolve the current EE
annual cost recovery filing, which increases annual recoveries by $2.2M, effective February 1, 2022.
2022 EE filing — In June 2022, NJNG submitted its annual cost recovery filing for the SAVEGREEN programs
established from 2010 through the present. In September 2022, the BPU approved the filing, which decreases annual
recoveries by $3.5M, effective October 1, 2022.
2023 EE filing — On June 1, 2023, NJNG submitted its annual EE filing with the BPU for the recovery of
SAVEGREEN costs, proposing an increase in annual recoveries of approximately $10.7M. On September 27, 2023,
the BPU approved an increase to the EE rate increasing annual recoveries by $9.0M based on updated information
since the initial filing, effective October 1, 2023
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:
•
2020 SBC filing — In April 2021, the BPU approved a stipulation resolving NJNG’s annual SBC application
requesting to recover remediation expenses, including an increase in the RAC of approximately $1.3M annually and
an increase to the NJCEP factor, which resulted in an annual increase of approximately $6.0M, effective May 1, 2021.
Page 92
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
•
•
•
•
•
•
2021 USF filing — In June 2021, NJNG filed its annual USF compliance filing proposing an annual increase to the
statewide USF rate of approximately $4.9M. In September 2021, the BPU approved the increase, effective October 1,
2021.
2021 SBC filing — In March 2022, the BPU approved NJNG’s annual filing to increase the RAC by $0.6M and
decrease the NJCEP by $2.9M, effective April 1, 2022.
2022 USF filing — In June 2022, NJNG filed its annual USF compliance filing proposing a decrease to the statewide
USF rate. In August 2022, an additional update was submitted on behalf of all NJ utilities with actual information
through July 31, 2022. In September 2022, the BPU approved a decrease based on the August update, which resulted
in an annual decrease of approximately $1.6M, effective October 1, 2022.
2022 SBC filing — In September 2022, NJNG submitted its annual SBC filing to the BPU requesting approval of
RAC expenditures through June 30, 2022, as well as an increase to the RAC annual recoveries of $3.8M and an
increase to the NJCEP annual recoveries of $2.2M, with a proposed effective date of April 1, 2023. On April 12, 2023,
the BPU approved on a final basis an increase to the RAC annual recoveries of $3.7M and a decrease to the NJCEP
annual recoveries of $0.9M, effective May 1, 2023.
2023 USF filing — On June 28, 2023, NJNG submitted its annual USF filing to the BPU requesting an increase to the
statewide USF rate, which will result in a $0.7M increase to annual recoveries. The BPU approved this matter on
September 27, 2023, effective October 1, 2023.
2023 SBC filing — On September 11, 2023, NJNG submitted its annual SBC filing to the BPU requesting approval of
RAC expenditures through June 2023, as well as an increase to the RAC annual recoveries of $2.4M and an increase to
the NJCEP annual recoveries of $5.0M, which would be effective April 1, 2024.
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 replaced 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 $130.0M, exclusive of AFUDC, over a four-year period. SAFE II was approved to invest up to $200.0M, excluding
AFUDC, over a five-year period. NJNG recovered approximately $157.5M 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 consisted of six capital investment projects estimated to cost $102.5M 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% to 6.9% and a return on equity of 9.75%. Requests for
recovery of future NJ RISE capital costs occurred in conjunction with SAFE II.
In March 2021, NJNG filed a petition with the BPU requesting the final base rate increase for the recovery associated
with NJ RISE and SAFE II capital investments cost of approximately $3.4M made through June 30, 2021. In June 2021, this
filing was consolidated with the 2021 base rate case. In November 2021, the BPU issued an order for the consolidated matter
which included approval for the final increase for the NJ RISE and SAFE II programs of $0.3M. With this approval, the BPU
filings with respect to NJ RISE and SAFE II are complete.
Page 93
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Infrastructure Investment Program
In February 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 $507.0M. Upon approval from the BPU, investments will be recovered through
annual filings to adjust base rates. In October 2020, the BPU approved the Company’s transmission and distribution component
of the IIP for $150.0M 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. In March 2022, NJNG filed its first rate recovery request for its BPU-approved IIP with capital expenditures estimated
through June 30, 2022, including AFUDC. In July 2022, NJNG filed its update with actual capital expenditures of $28.9M
through June 30, 2022. In September 2022, the BPU approved the rate increase resulting in a $3.2M revenue increase, effective
October 1, 2022.
On March 30, 2023, NJNG submitted its annual IIP filing to the BPU requesting a rate increase for estimated capital
expenditures of $31.4M through June 30, 2023. This filing was updated on July 28, 2023, with actual expenses of
approximately $28.2M through June 30, 2023. The BPU approved this filing on September 27, 2023, which resulted in a $3.2M
revenue increase, effective October 1, 2023.
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
ES 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 ES, on the Consolidated Statements of Operations as unrealized gains or losses. For ES 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.
ES 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. ES 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 ES 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.
Page 94
New Jersey Resources Corporation
Part II
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. ES recognizes
changes in the fair value of these derivatives as a component of operating revenues. Upon settlement of the contract, the related
revenue is recognized when the SREC is transferred to the counterparty.
Natural Gas Distribution
Changes in fair value of NJNG’s financial commodity derivatives are recorded as a component of regulatory assets or
liabilities on the Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity
contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis.
Accordingly, physical natural gas purchases are recognized in regulatory assets or liabilities on the Consolidated Balance Sheets
when the contract settles and the natural gas is delivered. The average cost of natural gas is charged to expense in the current
period earnings based on the BGSS factor times the therm sales. Effective for contracts executed on or after January 1, 2016,
NJNG no longer elects NPNS accounting treatment on a portfolio basis. However, since NPNS is a contract-by-contract
election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as normal. Because NJNG recovers
these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for natural gas
service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the
Consolidated Balance Sheets.
Clean Energy Ventures
The Company elects NPNS accounting treatment on PPA contracts executed by CEV that meet the definition of a
derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues
throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to
do so, the Company can and may elect to treat certain contracts as normal.
Fair Value of Derivatives
The following table presents the fair value of the Company’s derivative assets and liabilities recognized on the
Consolidated Balance Sheets as of September 30:
Balance Sheet Location
(Thousands)
Derivatives not designated as hedging instruments:
NJNG:
Physical commodity contracts
Financial commodity contracts
ES:
Physical commodity contracts
Derivatives - current
Derivatives - current
Financial commodity contracts
Foreign currency contracts
Total fair value of derivatives
Derivatives - current
Derivatives - noncurrent
Derivatives - current
Derivatives - noncurrent
Derivatives - current
Derivatives at Fair Value
2023
2022
Assets
Liabilities
Assets
Liabilities
$
43
6,110
$
488
20
$
252
85
$
11
6,281
6,209
802
18,393
762
—
$ 32,319
12,757
7,870
2,880
97
—
$ 24,112
9,857
376
14,423
6,009
18
$ 31,020
17,051
13,561
26,488
630
17
$ 64,039
Page 95
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Offsetting of Derivatives
The Company transacts under master netting arrangements or equivalent agreements that allow it to offset derivative
assets and liabilities with the same counterparty. However, the Company’s policy is to present its derivative assets and
liabilities on a gross basis at the contract level unit of account on the 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 and the net amounts the Company could present on the Consolidated Balance Sheets but elects
not to.
(Thousands)
As of September 30, 2023
ES Contracts
Physical commodity
Financial commodity
Total ES
NJNG Contracts
Physical commodity
Financial commodity
Total NJNG
As of September 30, 2022
ES Contracts
Physical commodity
Financial commodity
Foreign currency
Total ES
NJNG Contracts
Physical commodity
Financial commodity
Total NJNG
Asset Derivatives
Fair
Value (1)
Amounts
Offset (2)
Collateral
Received/
Pledged (3)
Net
Value (4)
Fair
Value (1)
Liability Derivatives
Collateral
Received/
Pledged (3)
Amounts
Offset (2)
Net
Value (4)
$ 7,011
19,155
$ 26,166
(1,236)
(2,977)
(4,213)
— $ 5,775
—
(16,178)
(16,178) $ 5,775
$ 20,627
2,977
$ 23,604
(1,236)
(2,977)
(4,213)
(9,728) $
—
(9,728) $
9,663
—
9,663
$
43
6,110
$ 6,153
(3)
(20)
(23)
40
— $
—
6,090
— $ 6,130
$
$
488
20
508
(3)
(20)
(23)
— $
—
— $
485
—
485
$ 10,233
(404)
20,432 (12,198)
(17)
$ 30,683 (12,619)
18
(200) $ 9,629
8,234
1
(200) $ 17,864
—
—
$ 30,612
27,118
17
$ 57,747
(404)
(12,198)
(17)
(12,619)
$
$
252
85
337
—
(85)
(85)
— $
—
— $
252
—
252
$
$
11
6,281
6,292
—
(85)
(85)
— $ 30,208
14,920
—
—
—
— $ 45,128
— $
—
— $
11
6,196
6,207
(1)
(2)
(3)
(4)
Derivative assets and liabilities are presented on a gross basis on the Consolidated Balance Sheets, as the Company does not elect balance sheet
offsetting under ASC 210-20.
Includes transactions with NAESB netting election, transactions held by FCMs with net margining and transactions with ISDA netting.
Financial collateral includes cash balances at FCMs, as well as cash received from or pledged to other counterparties.
Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.
ES utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical natural
gas to be used for storage injection and its subsequent sale at a later date. The gains or (losses) on the financial transactions that
are economic hedges of the cost of the purchased natural gas are recognized prior to the gains or (losses) on the physical
transaction, which are recognized in earnings when the natural gas is delivered. Therefore, mismatches between the timing of
the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the
actual sale of the natural gas that is being economically hedged, along with fair value changes in derivative instruments, creates
volatility in the results of ES, although the Company’s intended economic results relating to the entire transaction are
unaffected.
Page 96
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table presents the effect of derivative instruments recognized on the Consolidated Statements of Operations
as of September 30:
(Thousands)
Derivatives not designated as hedging instruments:
ES:
Location of gain (loss) recognized in
income on derivatives
Amount of gain (loss) recognized
in income on derivatives
2022
2023
2021
Physical commodity contracts
Physical commodity contracts
Financial commodity contracts
Foreign currency contracts
Operating revenues
Natural gas purchases
Natural gas purchases
Natural gas purchases
Total unrealized and realized gain (loss)
$
33,610
(6,846)
80,406
—
$ 107,170
$
$
(8,569)
3,580
14,403
(14)
9,400
$ 30,011
1,052
(43,997)
238
$ (12,696)
NJNG’s derivative contracts are part of the Company’s risk management activities that relate to its natural gas purchases
and BGSS incentive programs. At settlement, the resulting gains and/or losses are payable to or recoverable from utility
customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings.
The following table reflects the gains and/or (losses) associated with NJNG’s derivative instruments as of September 30:
(Thousands)
NJNG:
Physical commodity contracts
Financial commodity contracts
Total unrealized and realized (loss) gain
2023
2022
2021
$ (34,241)
(50,130)
$ (84,371)
$ 7,116
32,868
$ 39,984
$ 2,174
32,725
$ 34,899
During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with debt
issuances that were finalized in 2020. NJR designates its treasury lock contracts as cash flow hedges; therefore, changes in fair
value of the effective portion of the hedges are recorded in OCI and upon settlement of the contracts, realized gains and (losses)
are reclassified from OCI to interest expense on the Consolidated Statements of Operations ratable over the term of the
associated debt. Pre-tax losses of $1.4M were reclassified during both fiscal 2023 and 2022.
NJNG and ES had the following outstanding long (short) derivatives as of September 30:
Volumes (Bcf)
2023
2022
Natural Gas Distribution
Energy Services
Futures
32.1
30.5
Physical Commodity
12.1
6.8
Futures
(6.9)
(0.7)
Physical Commodity
0.2
2.7
Not included in the above table are 1.3M and 1.2M SRECs that were open as of September 30, 2023 and 2022,
respectively, and the notional amount of foreign currency transactions for the periods were immaterial.
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 NJNG and
ES.
The balances as of September 30, by reporting segment, are as follows:
(Thousands)
NJNG
ES
Balance Sheet Location
$
Restricted broker margin accounts - current assets
$
Restricted broker margin accounts - current assets
Restricted broker margin accounts - current liabilities $
2023
2022
5,915 $
14,881 $
8,029 $
26,138
68,123
—
Page 97
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Wholesale Credit Risk
NJNG, ES, CEV and S&T 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 and SRECs, the market value of contractual
positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a
counterparty fails to perform the obligations under its contract, then the Company could sustain a loss.
The Company monitors and manages the credit risk of its wholesale operations through credit policies and procedures that
management believes reduce overall credit risk. These policies include a review and evaluation of current and prospective
counterparties’ financial statements and/or credit ratings, daily monitoring of counterparties’ credit limits and exposure, daily
communication with traders regarding credit status and the use of credit mitigation measures, such as collateral requirements
and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin
deposit. Collateral may be requested due to the Company’s election not to extend credit or because exposure exceeds defined
thresholds. Most of the Company’s wholesale marketing contracts contain standard netting provisions. These contracts include
those governed by ISDA and the NAESB. The netting provisions refer to payment netting, whereby receivables and payables
with the same counterparty are offset and the resulting net amount is paid to the party to which it is due.
Internally-rated exposure applies to counterparties that are not rated by Fitch or Moody’s. In these cases, the
counterparty’s or guarantor’s financial statements are reviewed, and similar methodologies and ratios used by Fitch and/or
Moody’s are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and
financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/
or financial derivative commodity contract that has settled for which payment has not yet been received.
The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as
of September 30, 2023. 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 CEV residential solar installations.
(Thousands)
Investment grade
Noninvestment grade
Internally-rated investment grade
Internally-rated noninvestment grade
Total
Gross Credit
Exposure
$ 119,229
4,775
20,343
20,153
$ 164,500
Conversely, certain of NJNG’s and ES’s derivative instruments are linked to agreements containing provisions that would
require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in
individual counterparty agreements and can result in cash payments if NJNG’s credit rating were to fall below its current level.
Specifically, most, but not all, of these additional payments will be triggered if NJNG’s debt is downgraded by the major credit
agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would
result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in
relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings, but are
based on certain financial metrics.
Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent
upon the degree to which the Company’s credit rating and/or financial metrics deteriorate, and the extent to which liability
amounts exceed applicable threshold limits. There was approximately $0.1M and $0.2M of derivative instruments with credit-
risk-related contingent features that were in a liability position for which collateral is required as of September 30, 2023 and
2022, respectively. 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.
Page 98
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
6. FAIR VALUE
Fair Value of Assets and Liabilities
The fair value of cash and cash equivalents, accounts receivable, current loans receivable, 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 loans receivable are recorded based on what the Company expects to receive, which
approximates fair value, in other noncurrent assets on the Consolidated Balance Sheets. 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, including current maturities, excluding natural gas meter
sale leasebacks, debt issuance costs and solar asset sale leasebacks, is as follows (1):
(Thousands)
NJNG (2) (3)
Carrying value
Fair market value
NJR (4)
Carrying value
Fair market value
2023
2022
$ 1,467,845 $
$ 1,097,088 $
1,292,845
979,388
$ 1,120,000 $
$ 1,009,448 $
1,070,000
966,968
(1)
(2)
(3)
(4)
See Note 9. Debt for a reconciliation to long-term and short-term debt.
Excludes the sale leasebacks of natural gas meters of $31.4M and $30.3M as of September 30, 2023 and 2022, respectively. The fair value of certain sale
leasebacks of natural gas meters amounted to $20.9M and $15.7M as of September 30, 2023 and 2022, respectively.
Excludes NJNG’s debt issuance costs of $9.8M and $9.5M as of September 30, 2023 and September 30, 2022, respectively.
Excludes NJR’s debt issuance costs of $3.7M and $3.8M as of September 30, 2023 and September 30, 2022, respectively.
CEV 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, 2023 and
2022 was $268.1M and $124.1M, 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, 2023, the Company discloses its debt within Level 2 of the fair value hierarchy.
Fair Value Hierarchy
The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include
financial derivatives and physical commodity contracts qualifying as derivatives, investments in equity securities and other
financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that
prioritizes the inputs-to-valuation techniques used to measure fair value based on the source of the data used to develop the
price inputs.
Page 99
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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:
Fair Value
Hierarchy
Description of Fair Value Level
Level 1 Unadjusted quoted prices for identical
assets or liabilities in active markets
Level 2 Other significant observable inputs, such
as interest rates or price data, including
both commodity and basis pricing that is
observed either directly or indirectly
from publications or pricing services
Fair Value Technique
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 an FCM.
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:
Level 3
Inputs derived from a significant amount
of unobservable market data
•
•
•
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.
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 ES 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. ES uses Platts and Natural Gas Exchange for Canadian delivery points. However, ES 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, ES’s 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.
Page 100
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Assets and liabilities measured at fair value on a recurring basis are summarized as follows:
Quoted Prices in
Active Markets for
Identical Assets
(Level 1)
Significant Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
Total
$
—
25,265
145
2,641
$ 28,051
$
$
—
2,997
2,997
$
—
20,517
—
59
1,884
$ 22,460
$
—
33,231
—
$ 33,231
$ 7,054
—
—
—
$ 7,054
$ 21,115
—
$ 21,115
$ 10,485
—
18
—
—
$ 10,503
$ 30,623
168
17
$ 30,808
$ —
—
—
—
$ —
$ —
—
$ —
$ —
—
—
—
—
$ —
$ —
—
—
$ —
$
7,054
25,265
145
2,641
$ 35,105
$ 21,115
2,997
$ 24,112
$ 10,485
20,517
18
59
1,884
$ 32,963
$ 30,623
33,399
17
$ 64,039
(Thousands)
As of September 30, 2023
Assets
Physical commodity contracts
Financial commodity contracts
Money market funds
Other
Total assets at fair value
Liabilities
Physical commodity contracts
Financial commodity contracts
Total liabilities at fair value
As of September 30, 2022
Assets
Physical commodity contracts
Financial commodity contracts
Financial commodity contracts - foreign exchange
Money market funds
Other
Total assets at fair value
Liabilities
Physical commodity contracts
Financial commodity contracts
Financial commodity contracts - foreign exchange
Total liabilities at fair value
7. INVESTMENTS IN EQUITY INVESTEES
Steckman Ridge
The Company holds a 50% equity method investment in Steckman Ridge, a jointly owned and controlled natural gas
storage facility located in Bedford County, Pennsylvania. The Company’s investment in Steckman Ridge was $104.1M and
$106.6M as of September 30, 2023 and 2022, respectively, which includes loans with a total outstanding principal balance of
$70.4M for both September 30, 2023 and 2022. On October 1, 2023, we entered into an Amended and Restated Loan
Agreement with Steckman Ridge to extend the existing loan agreement for an additional five years and moved from London
Interbank Offered Rate to SOFR. These loans accrue interest at a variable rate that resets quarterly and are now due October 1,
2027.
NJNG and ES have entered into storage and park and loan agreements with Steckman Ridge. See Note 16. Related Party
Transactions for more information on these intercompany transactions.
PennEast
The Company, through its subsidiary NJR Midstream Company, is a 20% investor in PennEast, a partnership whose
purpose was to construct and operate a 120-mile natural gas pipeline that would have extended from northeast Pennsylvania to
western New Jersey.
Page 101
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
During the third quarter of fiscal 2021, the Company recognized an other-than-temporary impairment charge of $92.0M,
or approximately $74.5M, net of income taxes, which represented the best estimate of the salvage value of the remaining assets
of the project and was recorded in equity in earnings of affiliates in the Consolidated Statements of Operations. In September
2021, the PennEast partnership determined that this project was no longer supported, and all further development ceased.
In March 2022, the PennEast board of managers approved cash distributions to members of the partnership following the
sale of certain project-related assets and refunds of interconnection fees received from interstate pipelines. The return of capital
received by the Company from March 2022 through September 2022 totaled $11.0M and reduced the remaining carrying value
of its equity method investment in PennEast to zero in the Consolidated Balance Sheets, with the excess recorded in equity in
earnings of affiliates in the Consolidated Statements of Operations. The Company received additional return of capital of $0.3M
during fiscal 2023, which is recognized in equity in earnings of affiliates in the Consolidated Statements of Operations.
The following is the summarized financial information for Steckman Ridge and PennEast for fiscal years ended
September 30:
(Thousands)
Steckman Ridge
Operating revenues
Gross profit
Income from continuing operations
Net income
Net income attributable to NJR
Current assets
Noncurrent assets
Current liabilities
Noncurrent liabilities
PennEast
Operating revenues
Gross profit
Loss from continuing operations
Net loss
Net loss attributable to NJR
Current assets
Noncurrent assets
Current liabilities
Noncurrent liabilities
8. EARNINGS PER SHARE
2023
2022
2021
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
22,659 $
13,385 $
5,769 $
5,769 $
2,884 $
12,724 $
193,779 $
148,577 $
— $
— $
— $
(9,543) $
(9,543) $
(1,909) $
1,481 $
— $
127 $
— $
19,812 $
11,349 $
8,686 $
8,686 $
4,343 $
28,609
198,052
23,618
140,810
— $
— $
(3,778) $
(3,778) $
(756) $
1,801
—
82
500
21,847
13,350
11,483
11,483
5,741
—
—
(406,305)
(406,305)
(81,261)
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)
Net income, as reported
Basic earnings per share
Weighted average shares of common stock outstanding-basic
Basic earnings per common share
Diluted earnings per share
Weighted average shares of common stock outstanding-basic
Incremental shares (1)
Weighted average shares of common stock outstanding-diluted
Diluted earnings per common share
2023
2022
$ 264,724 $ 274,922 $ 117,890
2021
97,028
$2.73
96,100
$2.86
96,227
$1.23
97,028
599
97,627
$2.71
96,100
388
96,488
$2.85
96,227
333
96,560
$1.22
(1)
Incremental shares consist primarily of unvested stock awards and performance units, which are calculated using the treasury stock method.
Page 102
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
9. DEBT
NJNG and NJR finance working capital requirements and capital expenditures through various short-term debt and long-
term financing arrangements, including a commercial paper program and committed unsecured credit facilities.
Long-term Debt
The following table presents the long-term debt of the Company as of September 30:
(Thousands)
NJNG
First mortgage bonds:
Series OO
Series PP
Series QQ
Series RR
Series SS
Series TT
Series UU
Series VV
Series WW
Series XX
Series YY
Series ZZ
Series AAA
Series BBB
Series CCC
Series DDD
Series EEE
Series FFF
Series GGG
Series HHH
Series III
Series JJJ
Series LLL
Series MMM
Series NNN
Series OOO
Meter financing obligation
Less: Debt issuance costs
Less: Current maturities of long-term debt
3.00%
3.15%
3.58%
4.61%
2.82%
3.66%
3.63%
4.01%
3.50%
3.38%
2.45%
3.76%
3.86%
2.75%
3.00%
3.13%
3.13%
3.33%
2.87%
2.97%
2.97%
3.07%
4.37%
4.71%
5.47%
5.56%
Total NJNG long-term debt
NJR
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Unsecured senior notes
Less: Debt issuance costs
Less: Current maturities of long-term debt
3.20%
3.48%
3.54%
3.96%
3.29%
3.60%
3.50%
3.25%
3.13%
4.38%
3.64%
6.14%
Total NJR long-term debt
CEV
Solar asset financing obligation
Less: Current maturities of long-term debt
Total CEV long-term debt
Total long-term debt
Maturity date:
August 1, 2041
April 15, 2028
March 13, 2024
March 13, 2044
April 15, 2025
April 15, 2045
June 21, 2046
May 11, 2048
April 1, 2042
April 1, 2038
April 1, 2059
July 17, 2049
July 17, 2059
August 1, 2039
August 1, 2043
June 30, 2050
July 23, 2050
July 23, 2060
September 1, 2050
September 1, 2060
October 28, 2051
October 28, 2061
May 27, 2037
May 27, 2052
October 24, 2052
September 28, 2033
Various dates
August 18, 2023
November 7, 2024
August 18, 2026
June 8, 2028
July 17, 2029
July 23, 2032
July 23, 2030
September 1, 2033
September 1, 2031
June 23, 2027
September 19, 2034
December 15, 2032
Various dates
Page 103
2023
2022
46,500
50,000
70,000
55,000
50,000
100,000
125,000
125,000
10,300
10,500
15,000
100,000
85,000
9,545
41,000
50,000
50,000
25,000
25,000
50,000
50,000
50,000
50,000
50,000
125,000
50,000
31,352
(9,770)
(78,477)
1,410,950
—
100,000
100,000
100,000
150,000
130,000
130,000
80,000
120,000
110,000
50,000
50,000
(3,656)
—
1,116,344
46,500
50,000
70,000
55,000
50,000
100,000
125,000
125,000
10,300
10,500
15,000
100,000
85,000
9,545
41,000
50,000
50,000
25,000
25,000
50,000
50,000
50,000
50,000
50,000
—
—
30,290
(9,528)
(6,538)
1,307,069
50,000
100,000
100,000
100,000
150,000
130,000
130,000
80,000
120,000
110,000
50,000
—
(3,753)
(50,000)
1,066,247
278,401
(37,678)
240,723
130,618
(18,532)
112,086
$ 2,768,017 $ 2,485,402
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Annual long-term debt redemption requirements, excluding meter financing obligations, debt issuance costs and solar
asset financing obligations, as of September 30, are as follows:
(Thousands)
NJR
NJNG
NJR
2024
2025
2026
2027
2028
Thereafter
$
$
— $
100,000 $
100,000 $
110,000 $
100,000 $
710,000
70,000 $
50,000 $
— $
— $
50,000 $
1,297,845
On October 24, 2022, NJR entered into a Note Purchase Agreement, which closed on December 15, 2022, under which
NJR issued $50M, senior notes at a fixed rate of 6.14%, maturing in 2032. The senior notes are unsecured and guaranteed by
certain unregulated subsidiaries of NJR.
NJNG
First Mortgage Bonds
NJNG and Trustee entered into the Mortgage Indenture, dated September 1, 2014, which secures all the outstanding
FMBs issued by NJNG. The Mortgage Indenture provides a direct first mortgage lien upon substantially all 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%. As of September 30, 2023, NJNG’s equity-to-total-capitalization ratio is 54.4% and NJNG has the capacity to issue
up to $1.4B of FMB under the terms of the Mortgage Indenture.
On October 24, 2022, NJNG entered into a Note Purchase Agreement under which it sold $125M of its senior notes at an
interest rate of 5.47%, maturing in 2052.
On September 28, 2023, NJNG entered into a Note Purchase Agreement for $100M aggregate principal amount of its
senior notes consisting of $50M of 5.56% senior notes due September 28, 2033, which closed on September 28, 2023, and
$50M of 5.85% senior notes due October 30, 2053, which closed on October 30, 2023.
The senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture.
Sale Leasebacks
NJNG received $8.4M and $17.3M during fiscal 2023 and 2022, respectively, in connection with the sale leaseback of its
natural gas meters, with terms ranging from seven to 10 years. These transactions are treated as financing obligations that are
paid over the term of the arrangement and NJNG has the option to purchase the meters back upon lease expiration. During
fiscal 2022, NJNG exercised an early purchase option with respect to certain outstanding meter leases by making a final
principal payment of $1.1M for fiscal 2022. There were no early purchase options exercised during fiscal 2023.
Contractual commitments for meter financing obligation payments, which include the most likely outcome of cash
payments to the lessor, as of the fiscal years ended September 30, are as follows:
(Thousands)
Lease Payments
Less: Interest component
Total
2024
2025
2026
2027
2028
Thereafter Subtotal
$
9,362
7,479
6,407
4,083
4,715
1,676 $
33,722
(2,370)
$
31,352
Page 104
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Clean Energy Ventures
CEV enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over a
period of five to 15 years. These transactions are treated as financing obligations for accounting purposes and are typically
secured by the renewable energy facility asset and its future cash flows from RECs and energy sales. ITCs and other tax
benefits associated with these solar projects are transferred to the buyer, if applicable; however, the lease payments are
structured so that CEV is compensated for the transfer of the related tax incentives. CEV continues to operate the solar assets,
including related expenses, and retain the revenue generated from RECs and energy sales, and has the option to renew the lease
or repurchase the assets sold at the end of the lease term. CEV received proceeds of $167.8M and $24.1M during fiscal 2023
and 2022, respectively, in connection with the sale leaseback of commercial solar assets. The proceeds received were
recognized as a financing obligation on the Consolidated Balance Sheets.
Contractual commitments for the solar asset financing obligation payments, as of the fiscal years ended September 30, are
as follows:
(Thousands)
Lease Payments
Less: Interest component
Total
2024
54,033
$
2025
50,663
2026
13,875
2027
16,385
2028
26,392
Thereafter Subtotal
87,881 $ 249,229
(42,942)
$ 206,287
Credit Facilities and Short-term Debt
On February 7, 2023, NJR's 364-day $150M term loan credit agreement, that was entered into in February 2022, expired.
The Company had $50M that was borrowed on February 9, 2022 and $100M that was borrowed on February 14, 2022, which
was paid in full at expiration of the term loan agreement.
The following table summarizes NJR’s credit facility and NJNG’s commercial paper program and credit facility as of
September 30:
(Thousands)
2023
NJR
Bank revolving credit facilities (1)
NJNG
Bank revolving credit facilities (3)
2022
NJR
Bank revolving credit facilities (1)
Bank term loan credit agreement
NJNG
Bank revolving credit facilities (3)
(1)
(2)
Total borrowing
capacity
Loans
outstanding
Weighted average
interest rate
Remaining
borrowing capacity
Expiration
dates
At end of period
$
$
$
$
$
650,000
$ 217,300
6.53 %
250,000
$
34,800
5.48 %
650,000
150,000
$ 200,150
$ 150,000
3.97 %
3.81 %
250,000
$
73,800
3.34 %
$
$
$
$
$
426,967 (2)
Sep 2027
214,469 (4)
Sep 2027
440,177 (2)
—
Sep 2027
Feb 2023
175,469 (4)
Sep 2027
Committed credit facilities, which require commitment fees of 0.10% on the unused amounts.
Letters of credit outstanding total $5.7M and $9.7M as of September 30, 2023 and September 30, 2022, respectively, which reduces amount available by
the same amount.
Committed credit facilities, which require commitment fees of 0.075% on the unused amounts.
Letters of credit outstanding total $0.7M as of both September 30, 2023 and 2022, which reduces amount available by the same amount.
(3)
(4)
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.
Page 105
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
NJR
On August 30, 2022, NJR entered into a First Amendment to NJR’s Second Amended and Restated Credit Agreement
governing a $650M NJR Credit Facility with a maturity date of September 2, 2027. The NJR Credit Facility is subject to a one-
year extension beyond that date and includes an accordion feature, which allows NJR, in the absence of a default or event of
default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit
Facility in increments of $50M, with the total revolving credit commitments not exceeding $750M. The NJR Credit Facility
also permits the borrowing of revolving loans and swingline loans, as well as a $75M sublimit for the issuance of letters of
credit. 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 ES’s short-term liquidity needs and to finance, on an
initial basis, unregulated investments.
As of September 30, 2023, NJR had seven letters of credit outstanding totaling $5.7M on behalf of ES and CEV. 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.
ES’s letters of credit are used for margin requirements for natural gas transactions, collateral and security deposit for retail
natural gas sales, and they expire on dates ranging from September 2024 to December 2024.
Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.
NJNG
On August 30, 2022, NJNG amended the Second Amended and Restated Credit Agreement governing a $250M NJNG
Credit Facility with a maturity date of September 2, 2027. The NJNG Credit Facility is subject to a one-year extension beyond
that date and includes an accordion feature, which allows 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 $50M up to a maximum of $100M. The NJNG Credit Facility also permits the borrowing of revolving loans and
swingline loans, as well as a $30M sublimit for the issuance of letters of credit.
As of September 30, 2023, NJNG has two letters of credit outstanding for $0.7M, which reduced the amount available
under the NJNG Credit Facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by
the counterparties.
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, 2023, 2,774,527 shares remain available for future
issuance.
The following table summarizes all stock-based compensation expense recognized during the following fiscal years:
(Thousands)
Stock-based compensation expense:
Performance share awards
Restricted and non-restricted stock
Deferred retention stock
Compensation expense included in operation and maintenance expense
Income tax benefit (1)
Total, net of tax
2023
2022
2021
3,647
6,187
$ 4,882 $ 4,131 $ 3,856
3,193
100
7,149
(1,613)
$ 11,153 $ 11,203 $ 5,536
3,189
7,507
14,716 14,827
(3,624)
(3,563)
(1)
Excludes additional tax (expense) benefit related to delivered shares of $(0.6)M, $(0.1)M and $(0.2)M as of September 30, 2023, 2022 and 2021,
respectively.
Page 106
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Performance Share Units
In fiscal 2023, the Company granted to certain officers 39,614 performance shares, which are market condition awards
that vest on September 30, 2025, subject to the Company meeting certain conditions. In fiscal 2023, the Company also granted
to certain officers 73,047 performance shares, of which 42,449 vest on September 30, 2025 and 30,598 vest annually over a
three-year period beginning in September 2023, both of which are subject to the Company meeting certain performance
conditions.
In fiscal 2022, the Company granted to certain officers 44,965 performance shares, which are market condition awards
that vest on September 30, 2024, subject to the Company meeting certain conditions. In fiscal 2022, the Company also granted
to certain officers 73,561 performance shares, of which 44,596 vest on September 30, 2024 and 28,965 vest annually over a
three-year period beginning in September 2022, both of which are subject to the Company meeting certain performance
conditions.
In fiscal 2021, the Company granted to certain officers 46,813 performance shares, which are market condition awards
that vested on September 30, 2023, subject to the Company meeting certain conditions. In fiscal 2021, the Company also
granted to certain officers 70,138 performance shares, of which 44,156 vested in September 30, 2023 and 25,982 vest annually
over a three-year period beginning in September 2021, 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 $5.2M 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:
Non-vested and outstanding at September 30, 2020
Granted
Vested (2)
Cancelled/forfeited
Non-vested and outstanding at September 30, 2021
Granted
Vested (3)
Cancelled/forfeited
Non-vested and outstanding at September 30, 2022
Granted
Vested (4)
Cancelled/forfeited
Non-vested and outstanding at September 30, 2023
Weighted Average
Grant Date
Fair Value
$44.22
$33.34
$44.64
$45.32
$36.08
$38.84
$39.57
$37.33
$36.29
$46.00
$35.07
$38.64
$42.60
Shares (1)
155,731
116,951
(54,918)
(51,673)
166,091
118,526
(76,708)
(15,788)
192,121
112,661
(105,197)
(9,330)
190,255
Total Fair Value
of Vested Shares
(in Thousands)
—
—
$ 1,673
—
—
—
$ 2,765
—
—
—
$ 4,126
—
—
(1)
(2)
(3)
(4)
The number of common shares issued related to certain performance shares may range from zero to 150% of the number of shares shown in the table
above based on the Company’s achievement of performance goals.
As certified by the Company’s Leadership and Compensation Committee on November 10, 2021, there were no common shares earned related to TSR
performance, the number of common shares earned related to NFE performance was 93% or 31,116 shares, and the number of common shares earned
related to Performance Based Restricted Stock was 100% or 25,982 shares. Each award earned excludes accumulated dividends. The number
represented on this line is the target number of 100%.
As certified by the Company’s Leadership and Compensation Committee on November 9, 2022, the number of common shares earned related to TSR
performance was 112% or 30,472 shares, the number of common shares earned related to NFE performance was 105% or 26,282 shares, and the
number of common shares earned related to Performance Based Restricted Stock was 100% or 28,965 shares. Each award earned excludes
accumulated dividends. The number represented on this line is the target number of 100%.
As certified by the Company’s Leadership and Compensation Committee on November 15, 2023, the number of common shares earned related to TSR
performance was 150% or 59,192 shares, the number of common shares earned related to NFE performance was 150% or 55,832 shares, and the
number of common shares earned related to Performance Based Restricted Stock was 100% or 30,598 shares. Each award earned excludes
accumulated dividends. The number represented on this line is the target number of 100%.
Page 107
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 the grant date and are subsequently adjusted for actual achievement of
the performance goals.
Restricted Stock Units
The Company granted 64,080, 54,826 and 67,726 shares of restricted stock during fiscal 2023, 2022 and 2021,
respectively. The shares vest annually over a three-year period beginning in October of the fiscal year in which they were
granted. There is approximately $1.4M 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:
Non-vested and outstanding at September 30, 2020
Granted
Vested
Cancelled/forfeited
Non-vested and outstanding at September 30, 2021
Granted
Vested
Cancelled/forfeited
Non-vested and outstanding at September 30, 2022
Granted
Vested
Cancelled/forfeited
Non-vested and outstanding at September 30, 2023
Deferred Retention Stock Units
Weighted Average
Grant Date
Fair Value
$43.52
$33.34
$44.30
$36.34
$36.87
$38.84
$39.01
$37.06
$36.90
$46.00
$40.30
$38.77
$41.55
Shares
73,486
67,726
(34,000)
(5,591)
101,621
54,826
(47,867)
(10,756)
97,824
64,080
(48,312)
(4,716)
108,876
Total Fair Value
of Vested Shares
(in Thousands)
—
—
$ 996
—
—
—
$ 1,824
—
—
—
$ 1,910
—
—
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:
Outstanding at September 30, 2020
Granted/Vested
Delivered
Outstanding at September 30, 2021
Granted/Vested
Delivered
Forfeited
Outstanding at September 30, 2022
Granted/Vested
Delivered
Outstanding at September 30, 2023
Weighted Average
Grant Date
Fair Value
$46.32
$33.34
$45.00
$46.28
$38.95
$47.95
$40.33
$39.16
$45.85
$40.67
$41.74
Shares
228,246
2,999
(22,389)
208,856
192,728
(163,499)
(6,818)
231,267
134,941
(38,115)
328,093
Total Fair Value
of Vested Shares
(in Thousands)
$
—
—
641
—
—
$ 6,167
—
—
—
$ 1,517
—
Page 108
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Non-Employee Director Stock
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.
The following summarizes non-employee director share awards for the past three fiscal years:
Shares granted
Weighted average grant date fair value
2023
24,044 (1)
$49.58
2022
2021
30,908
$39.09
34,994
$35.72
(1)
Approximately $0.3M of expense remains as of September 30, 2023, to be recognized through December 31, 2023.
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 are no plan assets in the nonqualified plan due to the nature of the plan.
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 2023 and 2022, the Company had no minimum
funding requirements and did not make any discretionary contributions to the pension plans. The Company does not expect to
be required to make additional contributions to fund the pension plans during the next fiscal year 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 $4.2M and $6.1M in fiscal 2023 and 2022, respectively,
and estimates that it will contribute between $5M and $10M over each of the next five years. Additional contributions may be
required based on market conditions and changes to assumptions.
Page 109
New Jersey Resources Corporation
Part II
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:
(Thousands)
Change in Benefit Obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Plan participants’ contributions (2)
Actuarial (gain) loss
Benefits paid, net of retiree subsidies received
Benefit obligation at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual return (loss) on plan assets
Employer contributions
Benefits paid, net of plan participants’ contributions (2)
Fair value of plan assets at end of year
Funded status
Amounts recognized on Consolidated Balance Sheets
Postemployment employee benefit asset
Noncurrent
Postemployment employee benefit liability
Current
Noncurrent
Total
Pension (1)
OPEB
2023
2022
2023
2022
$ 290,823 $ 395,547 $ 173,217 $ 244,674
4,305
6,355
423
(77,775)
(4,765)
$ 290,321 $ 290,823 $ 203,406 $ 173,217
8,291
9,632
59
(109,320)
(13,386)
5,402
15,174
32
(7,057)
(14,053)
2,471
9,146
552
25,363
(7,343)
27,456
579
(14,021)
$ 284,347 $ 355,284 $
(58,239)
628
(13,326)
99,736 $ 114,183
9,826
(15,996)
4,192
6,082
(6,971)
(4,533)
$ 298,361 $ 284,347 $ 106,783 $
99,736
(96,623) $
$
(73,481)
(6,476) $
8,040 $
$
$
$
18,684 $
4,388 $
— $
—
(538) $
(10,106)
8,040 $
(578) $
(10,286)
(6,476) $
(4,201) $
(92,422)
(96,623) $
(900)
(72,581)
(73,481)
(1)
(2)
Includes the Company’s PEP.
Employees hired prior to July 1, 1998, that were eligible to elect an additional participant contribution to enhance their benefits, and contributions made
during the periods were immaterial.
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 OCI for the portion of the liability related to its unregulated operations.
The following table summarizes the amounts recognized in regulatory assets and accumulated OCI as of September 30:
(Thousands)
Balance at September 30, 2021
Amounts arising during the period:
Net actuarial (gain)
Amounts amortized to net periodic costs:
Net actuarial (loss)
Prior service (cost) credit
Balance at September 30, 2022
Amounts arising during the period:
Net actuarial (gain) loss
Amounts amortized to net periodic costs:
Net actuarial (loss)
Prior service (cost)
Balance at September 30, 2023
Regulatory Assets
OPEB
Pension
Accumulated Other
Comprehensive
Income (Loss)
Pension
OPEB
$ 56,187 $ 60,335
$ 22,790 $ 12,696
(14,922)
(35,781)
(14,885)
(18,422)
(5,843)
(101)
(4,577)
133
$ 35,321 $ 20,110
(2,902)
—
5,003 $
(1,107)
11
(6,822)
$
(10,493)
9,936
(4,048)
12,320
(87)
(103)
—
—
$ 24,638 $ 30,046
$
(213)
—
742 $
—
—
5,498
Page 110
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The amounts in regulatory assets and accumulated OCI not yet recognized as components of net periodic benefit cost as
of September 30 are:
(Thousands)
Net actuarial loss (gain)
Prior service cost
Total
Regulatory Assets
Accumulated Other Comprehensive
Income (Loss)
Pension
OPEB
Pension
OPEB
2023
2022
2023
2022
2023
2022
2023
2022
$ 24,577 $ 35,157 $ 30,046 $ 20,110 $
—
$ 24,638 $ 35,321 $ 30,046 $ 20,110 $
164
61
—
742 $
—
742 $
5,003 $
—
5,003 $
5,498 $
—
5,498 $
(6,822)
—
(6,822)
To the extent the unrecognized amounts in accumulated OCI or regulatory assets exceed 10% 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 OCI expected to be recognized as
components of net periodic benefit cost in fiscal 2024 are as follows:
(Thousands)
Net actuarial loss (gain)
Prior service cost
Total
Regulatory Assets
Accumulated Other
Comprehensive Income (Loss)
Pension
OPEB
Pension
OPEB
$
$
815 $
62
877 $
667
—
667
$
$
(12) $
—
(12) $
661
—
661
The projected benefit and accumulated benefit obligations and the fair value of plan assets as of September 30, are as
follows:
(Thousands)
Projected benefit obligation
Accumulated benefit obligation
Fair value of plan assets
Pension
2023
290,321 $
267,794 $
298,361 $
2022
290,823
265,933
284,347
$
$
$
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:
(Thousands)
Service cost
Interest cost
Expected return on plan assets
Recognized actuarial loss
Prior service cost (credit) amortization
Net periodic benefit cost recognized as expense
2023
Pension
2022
2021
2023
OPEB
2022
2021
$
$
5,402 $
15,174
(19,972)
300
103
1,007 $
8,291 $
9,632
(21,275)
8,745
101
5,494 $
8,730 $
9,112
(20,150)
11,446
102
9,240 $
2,471 $
9,146
(6,721)
—
—
4,896 $
4,844
4,305 $
6,071
6,355
(6,497)
(7,575)
7,909
5,684
(144)
(179)
8,625 $ 12,148
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:
2023
Pension
2022
2021
2023
OPEB
2022
2021
Benefit costs:
Discount rate
Expected asset return
Compensation increase
Obligations:
Discount rate
Compensation increase
5.50/5.50% (1)
7.00 %
3.00/3.50% (1)
3.10/3.07% (1)
6.75 %
3.00/3.50% (1)
2.95/2.92% (1)
6.75 %
3.00/3.50% (1)
5.51/5.51% (1)
7.00 %
3.00/3.50% (1)
3.24/3.17% (1)
6.75 %
3.00/3.50% (1)
3.08/3.03% (1)
6.75 %
3.00/3.50% (1)
5.89/5.87% (1)
3.00/3.50% (1)
5.50/5.50% (1)
3.00/3.50% (1)
3.10/3.07% (1)
3.00/3.50% (1)
5.97/5.94% (1)
3.00/3.50% (1)
5.51/5.51% (1)
3.00/3.50% (1)
3.24/3.17% (1)
3.00/3.50% (1)
(1)
Percentages for represented and non-represented plans, respectively.
Page 111
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
When measuring its PBO, 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% change in the rate, are as follows:
($ in thousands)
HCCTR
Ultimate HCCTR
Year ultimate HCCTR reached
Effect of a 1 percentage point increase in the HCCTR on:
Year-end benefit obligation
Total service and interest cost
Effect of a 1 percentage point decrease in the HCCTR on:
Year-end benefit obligation
Total service and interest costs
2023
7.4%
4.5%
2032
2022
6.6%
4.5%
2027
2021
6.9%
4.5%
2027
$
$
$
$
30,818 $
2,117 $
26,710 $
2,544 $
43,217
2,959
(25,283) $
(1,700) $
(21,853) $
(1,966) $
(34,669)
(2,253)
The Company’s investment objective is a long-term real rate of return on assets before permissible expenses that is
approximately 5% 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:
Asset Allocation
U.S. equity securities
International equity securities
Fixed income
Collective investment trusts at NAV
Total
2024
Target
Allocation
34 %
17
33
16
100 %
Assets at
September 30,
2022
2023
34 %
16
31
19
100 %
32 %
16
32
20
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-2021, 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
2024
2025
2026
2027
2028
$
$
15,227 $
6,925 $
16,233 $
7,602 $
17,255 $
8,481 $
18,246 $
9,337 $
19,219 $
10,211 $
2029 - 2033
110,341
63,780
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. Estimated subsidy payments for fiscal 2024 and 2025 are immaterial and zero thereafter.
Page 112
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Pension and OPEB assets held in the master trust, measured at fair value, are summarized as follows:
Pension
Quoted Prices in
Active Markets for
Identical Assets
(Level 1)
Total
OPEB
Quoted Prices in
Active Markets for
Identical Assets
(Level 1)
Total
(Thousands)
As of September 30, 2023
Assets
Registered Investment Companies:
Equity Funds:
Large Cap Index
Extended Market Index
International Stock
Fixed Income Funds:
Emerging Markets
Core Fixed Income
High Yield Bond Fund
Long Duration Fund
Total assets at fair value
As of September 30, 2022
Assets
Money market funds
Registered Investment Companies:
Equity Funds:
Large Cap Index
Extended Market Index
International Stock
Fixed Income Funds:
Emerging Markets
Core Fixed Income
Opportunistic Income
Ultra Short Duration
High Yield Bond Fund
Long Duration Fund
Total assets in the fair value hierarchy
Investments measured at net asset value
Collective investment trusts
$
$
$
$
—
81,171
17,256
48,557
11,471
—
20,685
58,484
237,624
75,394
15,783
44,846
11,074
—
—
—
19,816
59,084
225,997
30,884
6,444
17,966
4,306
22,241
7,651
—
89,492
81,171
17,256
48,557
11,471
—
20,685
58,484
237,624 $
60,737
298,361
— $
28
75,394
15,783
44,846
11,074
—
—
—
19,816
59,084
225,997 $
26,939
5,578
16,106
4,026
16,594
3,283
3,296
7,320
—
83,170
30,884
6,444
17,966
4,306
22,241
7,651
—
89,492
17,291
106,783
28
26,939
5,578
16,106
4,026
16,594
3,283
3,296
7,320
—
83,170
16,566
99,736
$
$
$
Total assets in the fair value hierarchy
Investments measured at net asset value
$
Collective investment trusts
Total assets at fair value
58,350
284,347
$
The Plan had no Level 2 or Level 3 fair value measurements during fiscal 2023 and 2022, and there have been no changes
in valuation methodologies as of September 30, 2023. The Plan held assets that are valued using NAV 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:
Asset Types
Money Market funds
Description of the Valuation Methodologies
Represents bank balances and money market funds that are valued based on the NAV of
shares held at year end.
Registered Investment Companies Equity and fixed income funds valued at the NAV of shares held by the plan at year end as
Collective investment trusts
reported on the active market on which the individual securities are traded.
The NAV for collective investment 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.
Page 113
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 85% of participants’ contributions up
to 6% 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% and 4.5% 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 $5.9M in fiscal 2023, $5.5M in fiscal
2022 and $5.1M in fiscal 2021. The amount contributed for the employer special contribution of the Savings Plan was $2.1M in
fiscal 2023, $2.4M in fiscal 2022 and $2.1M in fiscal 2021.
12. INCOME TAXES
The income tax provision from operations for the fiscal years ended September 30, consists of the following:
(Thousands)
Current:
Federal
State
Deferred:
Federal
State
Investment/production tax credits
Income tax provision
2023
2022
2021
$
13,393 $
7,716
4,238 $
2,104
651
1,703
36,825
(8,381)
(278)
49,275 $
55,968
14,185
(300)
76,195 $
25,030
6,224
(322)
33,286
$
As of September 30, the temporary differences, which give rise to deferred tax assets (liabilities), consist of the
following:
(Thousands)
Deferred tax assets
Investment tax credits (1)
State net operating losses
Deferred revenue
Fair value of derivatives
Impairment of equity method investment
Postemployment benefits
Incentive compensation
Amortization of intangibles
Overrecovered natural gas costs
Allowance for doubtful accounts
Other
Total deferred tax assets
Less: Valuation allowance
Total deferred tax assets net of valuation allowance
Deferred tax liabilities
Property-related items
Remediation costs
Investments in equity investees
Conservation incentive program
Other
Total deferred tax liabilities
Total net deferred tax liabilities
2023
2022
191,948 $
39,612
8,205
5,386
14,004
6,502
8,949
6,308
8,564
4,485
7,636
301,599
(5,747)
295,852 $
212,506
36,950
—
6,506
14,124
2,751
7,297
6,474
4,977
5,761
5,748
303,094
(22,241)
280,853
(487,294) $
(18,532)
(28,325)
(14,075)
(4,670)
(552,896) $
(468,115)
(18,490)
(19,176)
(6,457)
(4,615)
(516,853)
(257,044) $
(236,000)
$
$
$
$
$
(1)
Includes approximately $0.7M for NJNG for both fiscal 2023 and 2022, which is being amortized over the life of the related assets.
Page 114
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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)
Statutory income tax expense
Change resulting from:
Investment/production tax credits
Cost of removal of assets placed in service prior to 1981
AFUDC equity
State income taxes, net of federal benefit
Valuation allowance
Tax Act - utility excess deferred income taxes amortized
Other
Income tax provision
Effective income tax rate
2023
$ 65,940
2022
$ 73,735
2021
$ 31,747
(278)
(4,758)
(1,499)
13,293
(16,494)
(3,573)
(3,356)
$ 49,275
(300)
(3,533)
(2,361)
13,072
(1,372)
(3,573)
527
$ 76,195
(322)
(5,366)
(786)
6,124
5,974
(3,573)
(512)
$ 33,286
15.7 %
21.7 %
22.0 %
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, Florida, Indiana, Louisiana, Maryland, Michigan,
Mississippi, New Jersey, New York, North Carolina, Pennsylvania, Rhode Island, Texas 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 U.S. federal income tax returns through fiscal 2019 have either been reviewed by the IRS, or the related
statute of limitations has expired and all matters have been settled. U.S. federal income tax returns for periods subsequent to
fiscal 2019 are open to examination by the IRS. For all periods subsequent to those ended September 30, 2019, 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, 2018, are statutorily open to
examination.
NJR evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations
associated with uncertain tax positions. A tax benefit claimed, or expected to be claimed, on a tax return may be recognized
only if it is more likely than not that the tax position will be upheld upon examination by the applicable taxing authority and is
measured based on the largest tax benefit that is more than 50% likely to be realized. 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.
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 provided 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% of the deferred taxes were
required to be deposited by the end of 2021 and the remaining 50% were required to be deposited by the end of 2022.
As of September 30, 2021, the Company deferred approximately $5.1M related to the employer portion of the OASDI tax.
During fiscal 2022, the Company made the first of two installment payments, which reduced the balance to approximately
$2.7M. The second installment payment was made during the first quarter of fiscal 2023, which reduced the balance to zero as
of September 30, 2023.
Inflation Reduction Act
In August 2022, the President of the U.S. signed the Inflation Reduction Act, which contains provisions addressing
inflation, clean energy, healthcare and taxes beginning in 2023. The Inflation Reduction Act imposes a 15% minimum tax rate
on corporations with higher than $1B of annual income, along with a 1% excise tax on corporate stock repurchases. The
Inflation Reduction Act raised the ITC from 26% to 30% through the end of 2032, dropping to 26% for property under
construction before the end of 2033 and to 22% for property under construction before the end of 2034. The ITC expires
Page 115
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
starting in 2035 unless it is renewed. There are additional opportunities to increase the credit amount for certain facilities that
are placed in service after December 31, 2022. The credit amount can be increased by 10% if certain domestic content
requirements are satisfied or if the facility is located in an energy community, such as a brownfield site. ITCs are also expanded
to include stand-alone energy storage projects without being integrated into a solar facility, allowing solar to claim production
tax credits that are a production-based credit extending for 10 years following the placed-in-service date of the facility, and
introducing the concept of transferability of tax credits, providing an additional option to monetize such credits.
The Company evaluated the impacts of the Inflation Reduction Act on its financial position, results of operations and cash
flows, noting the corporate alternative minimum tax does not impact the Company as the applicable income thresholds have not
been met. Upon the repurchase of common stock through the Company’s share repurchase program, the Company would be
subject to the 1% excise tax.
Other Tax Items
As of September 30, 2023 and 2022, the Company has tax credit carryforwards of approximately $191.2M and $211.8M,
respectively, which each have a life of 20 years. The Company expects to utilize this entire carryforward prior to expiration,
which would begin in fiscal 2036.
The impairment of the equity method investment in PennEast created net capital loss attributes totaling approximately
$56.6M, which could only be utilized to offset capital gains income and carried back three years and forward five years prior to
expiration. During the fourth quarter of fiscal 2023, the Company determined that the tax losses created by the impairment may
qualify as an ordinary loss, rather than a capital loss. As of September 30, 2023 and 2022, the Company had a valuation
allowance of approximately $5.0M and $5.1M, respectively.
As of September 30, 2023, the Company evaluated certain tax benefits recorded in the Consolidated Financial Statements
and concluded that a portion of the tax benefits are uncertain at this time. As a result, the Company recorded a reserve for
uncertain tax benefits. The reserve for uncertain tax benefits is as follows:
(Thousands)
Balance at October 1,
Additions based on tax positions related to the current fiscal period
Balance at September 30,
2023
2022
$
$
— $
4,978
4,978 $
—
—
—
As of September 30, 2023, there are $5.0M of unrecognized tax benefits that if recognized would affect the annual
effective tax rate. The tax benefits relate to fiscal tax years open to examination by the IRS and the state of Pennsylvania and
may be subject to subsequent adjustment.
As of September 30, 2023 and 2022, the Company has state income tax net operating losses of approximately $631.2M
and $544.4M, 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, with the majority expiring after 2037. The
Company expects to utilize this entire carryforward, other than as described below.
As of September 30, 2022, the Company had a valuation allowance of approximately $17.2M related to the recognition of
state net operating loss carryforwards. As of September 30, 2023, it was determined that the realization of certain deferred tax
assets was more likely than not, and thus the associated valuation allowance of approximately $15.8M was no longer required.
Reversal of the valuation allowance resulted in a corresponding income tax benefit on the Consolidated Statement of
Operations. As of September 30, 2023, the remaining valuation allowance of approximately $0.7M related primarily to other
state income tax attributes which the Company could not conclude were realizable on a more-likely-than-not basis.
The Consolidated Appropriations Act extended the 30% 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% federal ITC if 5% 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 toward completion of the project, based on the IRS guidance around ITC safe harbor determination. The credit
declined to 26% for property under construction before the end of 2020. The Consolidated Appropriations Act of 2021
extended the 26% tax credit for property under construction during 2021 and 2022. The Inflation Reduction Act raised the ITC
from 26% to 30% through the end of 2032, as previously stated.
Page 116
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
13. LEASES
Lessee Accounting
The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control
the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right
to direct the use of the asset. After the criteria are satisfied, the Company accounts for these arrangements as leases in
accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease
term, and lease liabilities represent the Company’s obligation to make lease payments arising from the lease. Right-of-use assets
and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term,
including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not
have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease
commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily
available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The
Company uses the implicit rate for agreements in which it is a lessor. The Company has not entered into any material
agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for
operating leases.
The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases,
equipment and real property, including land and office facilities, office equipment and the sale leaseback of certain natural gas
meters.
Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment
component that relates to the change in the inflation metrics that are not known past the current payment period. The variable
components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use
lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The
capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns.
Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend
the terms for an additional five to 20 years. The Company’s office leases vary in duration, ranging from two to 17 years, and
may or may not include extension or early purchase options. The Company’s meter lease terms are between seven and 10 years
with purchase options available prior to the end of the term. Equipment leases include general office equipment that also vary in
duration, with an average term of eight years. The Company’s storage and capacity leases have assumed terms of 50 years to
coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company’s lease terms
may include options to extend, purchase the leased asset or terminate a lease, and they are included in the lease liability
calculation when it is reasonably certain that those options will be exercised. The Company has elected an accounting policy
that exempts leases with an original term of one year or less from the recognition requirements of ASC 842, Leases.
The Company has lease agreements with lease and non-lease components and has elected the practical expedient to
combine lease and non-lease components for certain classes of leases, such as office buildings, solar land leases and office
equipment. Variable payments are not considered material to the Company. The Company’s lease agreements do not contain
any material residual value guarantees, material restrictions or material covenants. In July 2021, NJNG entered into 16-year
lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office space at the Company’s headquarters in Wall,
New Jersey, the effects of which are eliminated in consolidation.
Page 117
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table presents the Company’s lease costs included in the Consolidated Statements of Operations for the
fiscal year ended September 30:
(Thousands)
Operating lease cost (1)
Finance lease cost
Income Statement Location
Operation and maintenance
2023
2022
2021
$
9,336 $
9,702 $
8,182
Amortization of right-of-use assets
Interest on lease liabilities
Depreciation and amortization
Interest expense, net of capitalized interest
Total finance lease cost
Short-term lease cost
Variable lease cost
Total lease cost
(1) Net of capitalized costs.
Operation and maintenance
Operation and maintenance
2,105
1,084
3,189 $
—
1,128
13,653 $
1,769 $
612
2,381
34
781
12,898 $
3,442
710
4,152
543
1,381
14,258
$
$
The following table presents supplemental cash flow information related to leases for the fiscal year ended September 30:
(Thousands)
Cash paid for amounts included in the measurement of lease liabilities
2023
2022
2021
Operating cash flows for operating leases
Operating cash flows for finance leases
Financing cash flows for finance leases
$
$
$
8,942 $
1,084 $
7,379 $
7,417 $
831 $
7,145 $
6,675
1,167
8,180
Assets obtained or modified for operating lease liabilities totaled approximately $13.2M and $0.9M during fiscal 2023
and 2022, respectively. Assets obtained or modified through other leases, including those which are finance leases and
financing transactions for accounting purposes, totaled approximately $8.4M and $17.3M during fiscal 2023 and 2022,
respectively.
The following table presents the balance and classifications of the Company’s right of use assets and lease liabilities
included in the Consolidated Balance Sheets for the fiscal year ended September 30:
(Thousands)
Assets
Noncurrent
Balance Sheet Location
2023
2022
Operating lease assets
Finance lease assets
Operating lease assets
Utility plant
Total lease assets
Liabilities
Current
Operating lease liabilities
Finance lease liabilities
Operating lease liabilities
Current maturities of long-term debt
Noncurrent
Operating lease liabilities
Finance lease liabilities
Operating lease liabilities
Long-term debt
Total lease liabilities
$
$
$
$
175,740 $
28,248
203,988 $
168,520
21,913
190,433
4,772 $
8,477
4,562
6,538
148,023
22,875
184,147 $
138,382
23,752
173,234
For operating lease assets and liabilities, the weighted average remaining lease term was 29.2 years for both September
30, 2023 and 2022, and the weighted average discount rate used in the valuation over the remaining lease term was 3.5% and
3.2% for September 30, 2023 and 2022, respectively.
For finance lease assets and liabilities as of September 30, 2023 and 2022, the weighted average remaining lease term
was 3.3 years and 4.0 years, respectively, and the weighted average discount rate used in the valuation over the remaining lease
term was 2.7% as of both September 30, 2023 and 2022.
Page 118
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table presents the Company’s maturities of lease liabilities as of September 30, 2023:
(Thousands)
2024
2025
2026
2027
2028
Thereafter
Total future payments
Less: interest
Total liability
Operating
Finance
$
$
7,913 $
7,875
7,799
7,743
7,803
213,927
253,060
(100,265)
152,795 $
9,362
7,479
6,407
4,083
4,715
1,676
33,722
(2,370)
31,352
14. COMMITMENTS AND CONTINGENT LIABILITIES
Cash Commitments
NJNG has entered into long-term contracts, expiring at various dates through September 2039, for the supply,
transportation and storage of natural gas. These contracts include annual fixed charges of approximately $198.3M at current
contract rates and volumes, which are recoverable through BGSS.
For the purpose of securing storage and pipeline capacity, ES enters into storage and pipeline capacity contracts, which
require the payment of certain demand charges by ES 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, 2023, for natural gas purchases and future demand fees for the next five fiscal year
periods, are as follows:
(Thousands)
ES:
Natural gas purchases
Storage demand fees
Pipeline demand fees
Sub-total ES
NJNG:
Natural gas purchases
Storage demand fees
Pipeline demand fees
Sub-total NJNG
Total
2024
2025
2026
2027
2028
Thereafter
$ 66,525 $
16,944
43,755
— $
3,505
13,719
$ 127,224 $ 53,868 $ 37,759 $ 29,112 $ 17,224 $
2,498 $
8,099
43,271
— $
6,010
31,749
— $
4,878
24,234
—
6,780
14,457
21,237
— $
14,975
— $
30,673
$ 23,952 $
42,469
—
— $
—
5,084
155,875 155,559 134,555 128,651 113,998
966,963
$ 222,296 $ 186,232 $ 149,530 $ 138,814 $ 119,082 $ 966,963
$ 349,520 $ 240,100 $ 187,289 $ 167,926 $ 136,306 $ 988,200
— $
10,163
Certain pipeline demand fees totaling approximately $4.0M per year, for which ES is the responsible party, are being paid
for by the counterparty to a capacity release transaction beginning November 1, 2021 for a period of 10 years.
As of September 30, 2023, the Company’s future minimum lease payments under various operating leases will not be
more than $7.9M annually for the next five years and $213.9M in the aggregate for all years thereafter.
Guarantees
As of September 30, 2023, there were NJR guarantees covering approximately $192.3M of ES’s natural gas purchases
and demand fee commitments not yet reflected in accounts payable on the Consolidated Balance Sheets.
Page 119
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Legal Proceedings
Manufactured Gas Plant Remediation
NJNG is responsible for the remedial cleanup of certain former MGP sites, dating back to gas operations in the late 1800s
and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved
in administrative proceedings with the NJDEP, and is participating in various studies and investigations by outside consultants,
to determine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action,
where warranted, under NJDEP regulations.
NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic
Highlands, Berkeley, Long Branch, Manchester, Toms River, Freehold and Aberdeen, New Jersey, including a review of
potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future
expenditures at the former MGP sites for which it is responsible, including potential liabilities for natural resource damages that
might be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites, will range
from approximately $137.3M to $201.5M. NJNG’s estimate of these liabilities is based upon known facts, existing technology
and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and
the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no
point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of
September 30, 2023, NJNG recorded a MGP remediation liability and a corresponding regulatory asset of approximately
$169.4M on the Consolidated Balance Sheets based on the most likely amount. The actual costs to be incurred by NJNG are
dependent upon several factors, including final determination of remedial action, changing technologies and governmental
regulations, the ultimate ability of other responsible parties to pay and insurance recoveries, if any.
NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC
approved by the BPU. In March 2022, the BPU approved an increase in the RAC, which increased the pre-tax annual recovery
from $11.1M to $11.7M, effective April 1, 2022. On April 12, 2023, the BPU approved on a final basis NJNG’s annual SBC
filing of RAC expenditures through June 30, 2022, as well as an increase to the RAC annual recoveries of $3.7M, which
increased the pre-tax annual recovery to $15.4M, effective May 1, 2023. As of September 30, 2023, $66.3M 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, the Company
establishes accruals for litigation for those matters that present loss contingencies as to which it is both probable that a loss will
be incurred and the amount of such loss can be reasonably estimated. The Company also discloses contingent matters for which
there is a reasonable possibility of a loss. Based upon currently available information, the Company believes that the results of
litigation that are currently pending, taken together, will not have a materially adverse effect on the Company’s financial
condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially
higher than the amounts accrued.
The foregoing statements about the Company’s litigation are based upon the Company’s judgments, assumptions and
estimates and are necessarily subjective and uncertain. The Company has a number of threatened and pending litigation matters
at various stages.
Page 120
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
15. REPORTING SEGMENT AND OTHER OPERATIONS DATA
The Company organizes its businesses based on a combination of factors, including its products and its regulatory
environment. As a result, the Company manages its businesses through the following reporting segments and other business
operations: NJNG consists of regulated energy and off-system, capacity and storage management operations; CEV consists of
capital investments in clean energy projects; ES consists of unregulated wholesale and retail energy operations; S&T consists of
the Company’s investments in natural gas transportation and storage facilities; the HSO business 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 business operations, as of September 30, is detailed below:
(Thousands)
2023
Operating revenues
External customers
Intercompany
Depreciation and amortization
Interest income (3)
Interest expense, net of
capitalized interest
Income tax provision (benefit)
Equity in earnings of affiliates
Net financial earnings
Capital expenditures
2022
Operating revenues
External customers
Intercompany
Depreciation and amortization
Interest income (3)
Interest expense, net of
capitalized interest
Income tax provision
Equity in earnings of affiliates
Net financial earnings (loss)
Capital expenditures
Return of capital from equity
investees
2021
Operating revenues
External customers
Intercompany
Depreciation and amortization
Interest income (3)
Interest expense, net of
capitalized interest
Income tax provision (benefit)
Equity in loss of affiliates
Net financial earnings (loss)
Capital expenditures
Investments in equity investees
NJNG
Segments
ES
CEV
S&T
Subtotal
HSO Elims
Total
1,349
$ 1,011,284 124,131 681,446 (1)
$
$ 102,326 25,320
—
$
— 10,170
1,713
221 (2)
1,119
$ 56,595 28,569 11,400
$ 33,065 (7,683) 24,343
$
—
$ 131,414 44,458 68,517
—
$ 390,394 107,303
—
—
88,700 $ 1,905,561 57,433
4,159 $
15,678
24,185 $ 152,052
6,957 $
205 (15,883) $
889
9,789 2,977 (3,847) $
— $ 1,962,994
—
— $ 152,941
8,919
— $ 123,014
647
25,803 $ 122,367
49,275
53,169 (1,477) (2,417) $
3,444 $
804 $
3,126 $
3,930
3,126 —
(155) $ 261,827
12,835 $ 257,224 4,758
— $ 540,919
40,916 $ 538,613 2,306
1,350
$ 1,127,417 128,280 1,529,178 (1)
$
—
$ 94,579 21,396
—
$
94
148 (2)
16
895
65,286 $ 2,850,161 55,818
2,449 $
3,893
12,302 $ 128,425
3,021
2,110 $
364 (4,257) $
824
944 (1,249) $
— $ 2,905,979
—
— $ 129,249
2,716
$ 46,394 21,968
4,725
$ 40,141 11,361 21,776
$
—
$ 140,124 39,403 39,121
—
$ 298,374 146,676
—
—
12,097 $
— $
85,184
646
1,879 $
75,157 1,059
(21) $
9,865 $
9,865 — (1,688) $
(781)
22,454 $ 241,102
151,988 $ 597,038 1,390
85,830
76,195
8,177
— $ 240,321
— $ 598,428
$
—
—
—
(5,479) $
(5,479) —
— $
(5,479)
$ 731,796 95,275 1,228,846 (1)
$
—
—
$ 80,045 20,567
241
85
$
(426)
111 (2)
11
49,252 $ 2,105,169 51,444
1,768 $
1,342
9,960 $ 110,683
2,580
2,243 $
— $ 2,156,613
—
(276) $ 111,387
2,167
(935) $
785 (2,127) $
980
522
—
$ 36,405 22,548
2,204
$ 19,054 5,048 18,371
$
—
$ 107,375 16,789 71,117
—
$ 426,628 87,852
—
—
—
$
—
— $
74,505 4,054
13,348 $
(196) 1,052 $
32,430
(10,043) $
(81,072) — (2,140) $
(81,072) $
13,046 $ 208,327
(826)
107,500 $ 621,980 2,630
690 —
78,559
33,286
(83,212)
211 $ 207,712
— $ 624,610
690
— $
690 $
Includes sales to Canada for ES, which are $8.4M, $2.4M and $0.1M in the fiscal years ended September 30, 2023, 2022 and 2021, respectively.
(1)
(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.
Included in other income, net on the Consolidated Statements of Operations.
(3)
Page 121
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The Company’s assets at end of period for the various reporting segments and other business operations, as of September
30, are detailed below:
Segments
Intercompany
Assets (1)
Total
(Thousands)
2023
2022
2021
NJNG
CEV
ES
S&T
Subtotal
HSO
$ 4,414,829 1,128,577 123,775 1,011,959 $ 6,679,140 171,275
999,520 $ 6,378,335 159,068
$ 4,030,686 1,015,065 333,064
862,407 $ 5,850,079 162,134
914,788 365,423
$ 3,707,461
(312,919) $ 6,537,496
(275,987) $ 6,261,416
(289,935) $ 5,722,278
(1)
Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation.
The Chief Executive Officer, who uses NFE as a measure of profit or loss in measuring the results of the Company’s
reporting segments and other business operations, is the chief operating decision maker of the Company. A reconciliation of
consolidated NFE to consolidated net income, as of September 30, is as follows:
(Thousands)
Net financial earnings
Less:
Unrealized (gain) loss on derivative instruments and related transactions
Tax effect
Effects of economic hedging related to natural gas inventory
Tax effect
(Gain on) impairment of equity method investment
Tax effect
Net income
2023
2022
$ 261,827 $ 240,321 $ 207,712
2021
(38,081)
9,050
34,699
(8,246)
(300)
(19)
54,203
(12,887)
(42,405)
10,078
92,000
(11,167)
$ 264,724 $ 274,922 $ 117,890
(59,906)
14,248
19,939
(4,738)
(5,521)
1,377
The Company uses derivative instruments as economic hedges of purchases and sales of physical natural gas inventory.
For GAAP purposes, these derivatives are recorded at fair value and related changes in fair value are included in reported
earnings. Revenues and cost of natural gas related to physical natural gas flow are recognized when the natural gas is delivered
to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and
physical natural gas flows. Timing differences occur in two ways:
•
•
unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical natural gas
inventory flows; and
unrealized gains and losses of prior periods are reclassified as realized gains and losses when derivatives are settled in
the same period as physical natural gas inventory movements occur.
NFE is a measure of the earnings based on eliminating these timing differences, to effectively match the earnings effects
of the economic hedges with the physical sale of natural gas, SRECs and foreign currency contracts. Consequently, to reconcile
between net income and NFE, current-period unrealized gains and losses on the derivatives are excluded from NFE as a
reconciling item. Realized derivative gains and losses are also included in current-period net income. However, NFE includes
only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the
derivatives with realized margins on physical natural gas flows. NFE also excludes certain transactions associated with equity
method investments, including impairment charges, which are non-cash charges, and return of capital in excess of the carrying
value of our investment. These are considered unusual in nature and occur infrequently such that they are not indicative of the
Company’s performance for its ongoing operations. Included in the tax effects are current and deferred income tax expense
corresponding with the components of NFE.
Page 122
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
16. RELATED PARTY TRANSACTIONS
Effective April 1, 2020, NJNG entered into a 5-year agreement for 3 Bcf of firm storage capacity with Steckman Ridge,
which expires on March 31, 2025. Under the terms of the agreement, NJNG incurs demand fees, at market rates, of
approximately $9.3M 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.
ES may periodically enter into storage or park and loan agreements with an affiliated FERC-jurisdictional natural gas
storage facility, Steckman Ridge. As of September 30, 2023, ES has entered into transactions with Steckman Ridge for varying
terms, all of which expire by March 31, 2024.
Demand fees, net of eliminations, associated with Steckman Ridge during the fiscal years ended September 30, were as
follows:
(Thousands)
NJNG
ES
Total
2023
2022
2021
$
$
6,549 $
657
7,206 $
6,663 $
732
7,395 $
6,449
564
7,013
The following table summarizes demand fees payable to Steckman Ridge as of September 30:
(Thousands)
NJNG
ES
Total
2023
2022
$
$
775 $
84
859 $
775
76
851
NJNG and ES enter into various AMAs, the effects of which are eliminated in consolidation. Under the terms of these
agreements, NJNG releases certain transportation and storage contracts to ES. As of September 30, 2023, NJNG and ES had
one AMA with an expiration date of March 31, 2024.
NJNG entered into a 5-year transportation agreement with Adelphia for committed capacity of 130,000 Dths per day in
Zone South, which began on August 9, 2022.
ES has a 5-year agreement for 3 Bcf of firm storage capacity with Leaf River, which is eliminated in consolidation and
expires in March 2024.
In March 2021, NJNG and CEV entered into a 15-year sublease and PPA related to an onsite solar array and the related
energy output at the Company’s headquarters in Wall, New Jersey, the effects of which are immaterial to the consolidated
financial statements.
In July 2021, NJNG entered into 16-year lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office
space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation.
In June 2022, NJNG and CEV entered into a 20-year sublease and PPA related to an onsite solar array and the related
energy output at the Company’s LNG plant in Howell, New Jersey, the effects of which are immaterial to the consolidated
financial statements.
NJNG entered into a 15-year transportation agreement with Adelphia for committed capacity of 130,000 Dth per day in
Zone North, beginning November 1, 2023.
The intercompany profits for certain transactions between NJNG and ES and NJNG and Adelphia are not eliminated in
accordance with ASC 980, Regulated Operations.
Page 123
New Jersey Resources Corporation
Part II
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
None
ITEM 9A. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
Under the supervision and with the participation of the Company’s management, including the principal executive officer
and principal financial officer, the Company conducted an evaluation of the effectiveness of the design and operation of its
disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act), as of the end of the
period covered by this report. Based on this evaluation, the Company’s principal executive officer and principal financial
officer concluded that, as of end of the period covered by this report, the Company’s disclosure controls and procedures are
effective to ensure that information required to be disclosed by the Company in the reports that it files or submits under the
Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms,
and that such information is accumulated and communicated to the Company’s management, including its principal executive
officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.
Management’s Annual Report on Internal Control over Financial Reporting
The report of management required under this Item 9A is contained in Item 8 of this Form 10-K under the caption
Management’s Report on Internal Control over Financial Reporting.
Attestation Report of Registered Public Accounting Firm
The attestation report required under this Item 9A is contained in Item 8 of this 10-K under the caption Report of
Independent Registered Public Accounting Firm.
Changes in Internal Control over Financial Reporting
We periodically review our internal controls over financial reporting as part of our efforts to ensure compliance with the
requirements of Section 404 of the Sarbanes-Oxley Act of 2002. In addition, we routinely review our system of internal
controls over financial reporting to identify potential changes to our processes and systems that may improve controls and
increase efficiency, while ensuring that we maintain an effective internal controls environment. There were no changes in our
internal controls over financial reporting that occurred during the quarter ended September 30, 2023, that have materially
affected, or are reasonably likely to materially affect, our internal controls over financial reporting.
ITEM 9B. OTHER INFORMATION
During the three months ended September 30, 2023, no director or officer (as defined by Rule 16a-1(f) of the Exchange
Act) of the Company adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as
each term is defined in Item 408(a) of Regulation S-K.
Page 124
New Jersey Resources Corporation
Part III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Information required by this item, including information concerning the Board of Directors of the Company, the members
of the Company’s Audit Committee, the Company’s Audit Committee Financial Expert, compliance with Section 16(a) of the
Exchange Act and shareowner proposals, is incorporated by reference to the Company’s Proxy Statement for the 2024 Annual
Meeting of Shareowners, which will be filed with the SEC pursuant to Regulation 14A within 120 days after September 30,
2023. The information regarding executive officers is included in this report as Item 1 under the caption Information About our
Executive Officers and incorporated herein by reference.
The Board of Directors has adopted the Code of Conduct, a code for all directors, officers and employees, as required by
the New York Stock Exchange rules, and governing the chief executive officer and senior financial officers, in compliance with
Sarbanes-Oxley and SEC regulations. Copies of the Code of Conduct are available free of charge on the Company’s website at
http://investor.njresources.com under the caption Corporate Governance. A printed copy of the Code of Conduct is available
free of charge to any shareowner who requests it by contacting the Corporate Secretary at 1415 Wyckoff Road, Wall, New
Jersey 07719. The Company will disclose any amendments to, or waivers from, a provision of the Code of Conduct that applies
to the principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing
similar functions that relate to any element of the Code of Conduct as defined in Item 406 of Regulation S-K by posting such
information on the Company’s website.
ITEM 11. EXECUTIVE COMPENSATION
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND
RELATED STOCKHOLDER MATTERS
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
Page 125
New Jersey Resources Corporation
Part IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a) 1. Financial Statements.
All Financial Statements of the Registrant are filed as part of this report and included in Item 8 of Part II of this Form 10-K.
(a) 2. Financial Statement Schedules-See Index to Financial Statement Schedules in Item 8.
(a) 3. Exhibits-See Exhibit Index on page 129.
Page 126
New Jersey Resources Corporation
Part IV
INDEX TO FINANCIAL STATEMENT SCHEDULES
Schedule II - Valuation and qualifying accounts and reserves for each of the three years in the period ended
September 30, 2023
Page
128
Schedules other than those listed above are omitted because they are either not required or are not applicable, or the
required information is shown in the financial statements or notes thereto.
Page 127
New Jersey Resources Corporation
Part IV
SCHEDULE II
VALUATION AND QUALIFYING ACCOUNTS
YEARS ENDED SEPTEMBER 30, 2023, 2022 and 2021
(Thousands)
CLASSIFICATION
2023
Valuation allowance for deferred tax assets
Allowance for doubtful accounts
2022
Valuation allowance for deferred tax assets
Allowance for doubtful accounts
2021
Valuation allowance for deferred tax assets
Allowance for doubtful accounts
BEGINNING
BALANCE
ADDITIONS/
(DEDUCTIONS),
NET TO
EXPENSE
OTHER
ENDING
BALANCE
$
$
$
$
$
$
22,241
19,379
23,613
24,652
17,639
7,242
(16,494) (1)
—
$
1,570
(9,913) (2) $
(1,372)
2,401
6,355
18,986
—
$
(7,674) (2) $
(381)
$
(1,576) (2) $
5,747
11,036
22,241
19,379
23,613
24,652
(1)
(2)
Includes valuation allowance release for CEV, see Note 12. Income Taxes for more details.
Uncollectible accounts written off, less recoveries and adjustments.
Page 128
New Jersey Resources Corporation
Part IV
EXHIBIT INDEX
Exhibit
Number
Exhibit Description
3.1
3.2
4.1
4.2
4.3
4.3(a)
4.3(b)
4.3(c)
4.3(d)
4.3(e)
4.3(f)
4.3(g)
4.3(h)
4.3(i)
4.3(j)
4.3(k)
4.3(l)
Restated Certificate of Incorporation of New Jersey Resources Corporation, as amended through March 3, 2015
(incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K, as filed on January 23, 2014, and
Exhibit 3.1 to the Current Report on Form 8-K, as filed on March 3, 2015)
Bylaws of New Jersey Resources Corporation, as amended and restated on July 12, 2023 (incorporated by
reference to Exhibit 3.1 to the Current Report on Form 8-K, as filed on July 13, 2023)
Description of Common Stock (incorporated by reference to Exhibit 4.1 to the Annual Report on Form 10-K for
the fiscal year ended September 30, 2019, as filed on November 22, 2019)
Specimen Common Stock Certificate (incorporated by reference to Exhibit 4.1 to the Annual Report on Form 10-
K for the fiscal year ended September 30, 2013, as filed on November 25, 2013)
Amended and Restated Indenture of Mortgage, Deed of Trust and Security Agreement, dated as of September 1,
2014, between NJNG and U.S. Bank National Association, as Trustee (incorporated by reference to Exhibit 99.3
to the Current Report on Form 8-K, as filed on September 30, 2014)
36th Supplemental Indenture dated as of September 1, 2014, between NJNG and U.S. Bank National Association,
as Trustee (incorporated by reference to Exhibit 99.2 to the Current Report on Form 8-K, as filed on September
30, 2014)
First Supplemental Indenture dated as of April 1, 2015 between NJNG and U.S. Bank National Association, as
Trustee (incorporated by reference to Exhibit 4.2 to the Quarterly Report on Form 10-Q, as filed on May 7, 2015)
Second Supplemental Indenture dated as of June 1, 2016, between New Jersey Natural Gas Company and U.S.
Bank National Association, as Trustee (incorporated by reference to Exhibit 4.2 to Form 8-K as filed on June 22,
2016)
Third Supplemental Indenture, dated as of May 1, 2018, by and between New Jersey Natural Gas Company and
U.S. Bank National Association (incorporated by reference to Exhibit 4.2 to the Current Report on Form 8-K, as
filed on May 11, 2018)
Fourth Supplemental Indenture, dated as of April 1, 2019, between NJNG and U.S. Bank National Association, as
Trustee (incorporated by reference to Exhibit 4.4 to the Quarterly Report on Form 10-Q, as filed on May 3, 2019)
Fifth Supplemental Indenture, dated as of July 1, 2019, by and between New Jersey Natural Gas Company and
the Purchasers party thereto (incorporated by reference to Exhibit 4.3 to the Current Report on Form 8-K, as filed
on July 17, 2019)
Sixth Supplemental Indenture, dated as of August 1, 2019, between NJNG and U.S. Bank National Association,
as Trustee (incorporated by reference to Exhibit 4.3(g) to the Annual Report on Form 10-K for the fiscal year
ended September 30, 2019, as filed on November 22, 2019)
Seventh Supplemental Indenture, dated as of June 1, 2020, between NJNG and U.S. Bank National Association,
as Trustee (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K, as filed on July 2, 2020)
Eighth Supplemental Indenture, dated as of July 23, 2020, between NJNG and U.S. Bank National Association,
as Trustee (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K, as filed on July 23, 2020)
Ninth Supplemental Indenture, dated as of September 2, 2020, between NJNG and U.S. Bank National
Association, as Trustee (incorporated by reference to Exhibit 4.3 to the Current Report on Form 8-K, as filed on
September 2, 2020)
Tenth Supplemental Indenture, dated as of October 1, 2021, by and between New Jersey Natural Gas Company
and U.S. Bank National Association, as Trustee (incorporated by reference to Exhibit 4.2 to the Current Report on
Form 8-K, as filed on November 3, 2021)
Eleventh Supplemental Indenture, dated as of May 1, 2022, by and between New Jersey Natural Gas Company
and U.S. Bank Trust Company, National Association, as Trustee (incorporated by reference to Exhibit 4.2 to the
Current Report on Form 8-K, as filed on June 1, 2022)
4.3(m)
Twelfth Supplemental Indenture, dated as of October 1, 2022, by and between New Jersey Natural Gas Company
and U.S. Bank Trust Company, National Association, as Trustee (incorporated by reference to Exhibit 4.3 to the
Current Report on Form 8-K, as filed on October 28, 2022)
Page 129
New Jersey Resources Corporation
Part IV
Exhibit
Number
4.3(n)
4.3(o)
4.4
4.4(a)
4.4(b)
4.4(c)
4.4(d)
4.5
4.6
4.7
4.8
4.9
4.10
4.11
4.12
4.13
Exhibit Description
Thirteenth Supplemental Indenture, dated as of September 1, 2023, by and between New Jersey Natural Gas
Company and U.S. Bank Trust Company, National Association, as Trustee (incorporated by reference to Exhibit
4.2 to the Current Report on Form 8-K, as filed on October 2, 2023)
Fourteenth Supplemental Indenture, dated as of October 1, 2023, by and between New Jersey Natural Gas
Company and U.S. Bank Trust Company, National Association, as Trustee (incorporated by reference to Exhibit
4.1 to the Current Report on Form 8-K, as filed on October 31, 2023)
$75,000,000 Shelf Note Purchase Agreement, dated as of June 30, 2011, between New Jersey Resources
Corporation and Prudential Investment Management, Inc. (incorporated by reference to Exhibit 4.1 to the Current
Report on Form 8-K as filed on July 6, 2011)
First Amendment to the Prudential Facility, dated as of July 25, 2014, between the Company and Prudential
Investment Management, Inc. (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K as
filed on November 12, 2014)
Second Amendment to the Prudential Facility, dated as of September 28, 2015, between the Company and
Prudential Investment Management, Inc. (incorporated by reference to Exhibit 10.2 to the Current Report on
Form 8-K as filed on October 2, 2015)
Third Amendment to the Shelf Note Purchase Agreement dated as of June 30, 2011, dated as of November 1,
2021 among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party
thereto (incorporated by reference to Exhibit 4.3 to the Current Report on Form 8-K, as filed on November 3,
2021)
Fourth Amendment to the Shelf Note Purchase Agreement, among New Jersey Resources Corporation, PGIM,
Inc. (formerly Prudential Investment Management, Inc.) and the Purchasers party thereto dated as of September
16, 2022 (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K as filed on September 20,
2022)
$125,000,000 Note Purchase Agreement, dated as of February 7, 2014, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.5 to the Quarterly Report on
Form 10-Q, as filed on May 7, 2014)
Loan Agreement between New Jersey Economic Development Authority and New Jersey Natural Gas Company,
dated as of August 1, 2011 (incorporated by reference to Exhibit 4.10 to the Annual Report on Form 10-K for the
fiscal year ended September 30, 2011, as filed on November 23, 2011)
First Amendment to the Loan Agreement, dated as of August 1, 2019, between NJNG and New Jersey Economic
Development Authority (incorporated by reference to Exhibit 4.7 to the Annual Report on Form 10-K for the
fiscal year ended September 30, 2019, as filed on November 22, 2019)
First Supplemental Indenture, dated as of August 1, 2019, between NJNG and U.S. Bank National Association, as
Trustee (incorporated by reference to Exhibit 4.8 to the Annual Report on Form 10-K for the fiscal year ended
September 30, 2019, as filed on November 22, 2019)
$50,000,000 Note Purchase Agreement, dated as of February 8, 2013, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.12 to the Quarterly Report on
Form 10-Q, as filed on May 3, 2013)
$150,000,000 Note Purchase Agreement, dated as of February 12, 2015, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on February 17, 2015)
Note Purchase Agreement, dated as of March 22, 2016, among New Jersey Resources Corporation and each of
the Purchasers listed in Schedule A thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on March 25, 2016)
$125,000,000 Note Purchase Agreement, dated as of June 21, 2016, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on June 22, 2016)
$125,000,000 Note Purchase Agreement, dated as of May 11, 2018, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on May 11, 2018)
Page 130
Exhibit
Number
4.14
4.15
4.16
4.17
4.18
4.19
4.20
4.21
4.22
4.23
4.24
4.25
4.26
4.27
4.28
4.29
4.30
New Jersey Resources Corporation
Part IV
Exhibit Description
$100,000,000 Note Purchase Agreement, dated as of June 8, 2018, by and among New Jersey Resources
Corporation and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on June 8, 2018)
Amended and Restated Indenture, dated as of April 1, 2019, between NJNG and New Jersey Economic
Development Authority and U.S. Bank National Association, as Trustee (incorporated by reference to Exhibit 4.1
to the Quarterly Report on Form 10-Q, as filed on May 3, 2019)
Second Amendment to the Loan Agreement, dated as of April 1, 2019, between NJNG and New Jersey Economic
Development Authority (incorporated by reference to Exhibit 4.2 to the Quarterly Report on Form 10-Q, as filed
on May 3, 2019)
Amended and Restated Continuing Disclosure Undertaking, dated as of April 18, 2019 (incorporated by reference
to Exhibit 4.3 to the Quarterly Report on Form 10-Q, as filed on May 3, 2019)
$150,000,000 Note Purchase Agreement, dated as of July 17, 2019, by and among New Jersey Resources
Corporation and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on July 17, 2019)
$185,000,000 Note Purchase Agreement, dated as of July 17, 2019, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.2 to the Current Report on
Form 8-K, as filed on July 17, 2019)
Amended and Restated Continuing Disclosure Undertaking, dated as of August 22, 2019 (incorporated by
reference to Exhibit 4.20 to the Annual Report on Form 10-K for the fiscal year ended September 30, 2019, as
filed on November 22, 2019)
$260,000,000 Note Purchase Agreement, dated as of May 14, 2020, by and among New Jersey Resources
Corporation and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on May 18, 2020)
$125,000,000 Note Purchase Agreement, dated as of May 14, 2020, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.2 to the Current Report on
Form 8-K, as filed on May 18, 2020)
$200,000,000 Note Purchase Agreement, dated as of September 1, 2020, by and among New Jersey Resources
Corporation and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on September 2, 2020)
$75,000,000 Note Purchase Agreement, dated as of September 1, 2020, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.2 to the Current Report on
Form 8-K, as filed on September 2, 2020)
$100,000,000 Note Purchase Agreement, dated as of October 28, 2021, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on November 3, 2021)
First Amendment to the Note Purchase Agreement dated as of March 22, 2016, dated as of November 1, 2021
among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto
(incorporated by reference to Exhibit 4.4 to the Current Report on Form 8-K, as filed on November 3, 2021)
First Amendment to the Note Purchase Agreement dated as of June 8, 2018, dated as of November 1, 2021
among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto
(incorporated by reference to Exhibit 4.5 to the Current Report on Form 8-K, as filed on November 3, 2021)
First Amendment to the Note Purchase Agreement dated as of July 17, 2019, dated as of November 1, 2021
among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto
(incorporated by reference to Exhibit 4.6 to the Current Report on Form 8-K, as filed on November 3, 2021)
First Amendment to the Note Purchase Agreement dated as of May 14, 2020, dated as of November 1, 2021
among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto
(incorporated by reference to Exhibit 4.7 to the Current Report on Form 8-K, as filed on November 3, 2021)
First Amendment to the Note Purchase Agreement dated as of September 1, 2020, dated as of November 1, 2021
among New Jersey Resources Corporation, each Guarantor signatory thereto, and each Noteholder party thereto
(incorporated by reference to Exhibit 4.8 to the Current Report on Form 8-K, as filed on November 3, 2021)
Page 131
New Jersey Resources Corporation
Part IV
Exhibit
Number
4.31
4.32
4.33
4.34
4.35
Exhibit Description
$100,000,000 Note Purchase Agreement, dated as of May 27, 2022, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on June 1, 2022)
$110,000,000 Note Purchase Agreement, dated as of June 23, 2022, by and among New Jersey Resources
Corporation and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on June 27, 2022)
$125,000,000 Note Purchase Agreement, dated as of October 24, 2022, by and among New Jersey Natural Gas
Company and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on October 28, 2022)
$50,000,000 Note Purchase Agreement, dated as of October 24, 2022, by and among New Jersey Resources
Corporation and the Purchasers party thereto (incorporated by reference to Exhibit 4.2 to the Current Report on
Form 8-K, as filed on October 28, 2022)
$100,000,000 Note Purchase Agreement, dated as of September 28, 2023, by and among New Jersey Resources
Corporation and the Purchasers party thereto (incorporated by reference to Exhibit 4.1 to the Current Report on
Form 8-K, as filed on October 2, 2023)
10.1*
Form of Amended and Restated Supplemental Executive Retirement Plan Agreement between the Company and
Named Executive Officer (incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K for the
fiscal year ended September 30, 2020, as filed on November 30, 2020)
10.1(a)*
Schedule of Supplemental Executive Retirement Plan Agreements for named executive officers (incorporated by
reference to Exhibit 10.1(a) to the Annual Report on Form 10-K for the fiscal year ended September 30, 2020, as
filed on November 30, 2020)
10.2
10.3*
10.4*
10.5*
10.6*
10.7*
10.8*
10.9*
Service Agreement for Rate Schedule SS-1 by and between NJNG and Texas Eastern Transmission Company,
dated as of June 21, 1995 (incorporated by reference to Exhibit 10-5B to the Annual Report on Form 10-K for the
fiscal year ended September 30, 1996, as filed on December 30, 1996)
Summary of 2023 Non-Employee Director Compensation Plan (incorporated by reference to Exhibit 10.1 to the
Current Report on Form 8-K, as filed on September 20, 2022)
Summary of 2022 Non-Employee Director Compensation Plan (incorporated by reference to Exhibit 10.3 to the
Current Report on Form 8-K, as filed on September 9, 2021)
The Company’s 2017 Stock Award and Incentive Plan (incorporated by reference to Appendix A to the Proxy
Statement for the 2017 Annual Meeting as filed on December 15, 2016)
New Jersey Resources Savings Equalization Plan (as amended and restated as of November 16, 2020)
(incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K for the fiscal year ended
September 30, 2020, as filed on November 30, 2020)
New Jersey Resources Pension Equalization Plan (as amended and restated as of November 16, 2020)
(incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K for the fiscal year ended
September 30, 2020, as filed on November 30, 2020)
New Jersey Resources Corporation Officers’ Deferred Compensation Plan (as amended and restated on
November 16, 2020) (incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K for the fiscal
year ended September 30, 2020, as filed on November 30, 2020)
Amended and Restated New Jersey Resources Corporation Directors’ Deferred Compensation Plan (amended
and restated as of November 16, 2020) (incorporated by reference to Exhibit 10.1 to the Annual Report on Form
10-K for the fiscal year ended September 30, 2020, as filed on November 30, 2020)
10.10*
Form of Amended and Restated Employment Continuation Agreement between the Company and named
executive officer (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K, as filed on
November 18, 2019)
10.10(a)* Schedule of Employee Continuation Agreements (incorporated by reference to Exhibit 10.1 to the Annual Report
on Form 10-K for the fiscal year ended September 30, 2020, as filed on November 30, 2020)
10.10(b)* Form of Amended and Restated Employment Continuation Agreement for officers of NJR Energy Services
Company dated as of November 12, 2019 (incorporated by reference to Exhibit 10.2 to the Current Report on
Form 8-K, as filed on November 18, 2019)
Page 132
New Jersey Resources Corporation
Part IV
Exhibit
Number
10.11*
Exhibit Description
Limited Liability Company Agreement of Steckman Ridge GP, LLC, dated as of March 2, 2007 (incorporated by
reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q, as filed on May 3, 2007)
10.12*
Limited Partnership Agreement of Steckman Ridge, LP dated as of March 2, 2007 (incorporated by reference to
Exhibit 10.2 to the Quarterly Report on Form 10-Q, as filed on May 3, 2007)
10.13* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Restricted Stock Units Agreement
Fiscal Year 2020 (incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K for the fiscal
year ended September 30, 2020, as filed on November 30, 2020)
10.14* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
Total Shareholder Return Fiscal Year 2020 (incorporated by reference to Exhibit 10.1 to the Annual Report on
Form 10-K for the fiscal year ended September 30, 2020, as filed on November 30, 2020)
10.15* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
NFE Fiscal Year 2020 (incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K for the
fiscal year ended September 30, 2020, as filed on November 30, 2020)
10.16* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance-Based Restricted Stock
Unit Agreement Fiscal Year 2020 (incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K
for the fiscal year ended September 30, 2020, as filed on November 30, 2020)
10.17
New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Deferred Retention Stock Award
Agreement Fiscal Year 2020 (incorporated by reference to Exhibit 10.1 to the Annual Report on Form 10-K for
the fiscal year ended September 30, 2020, as filed on November 30, 2020)
10.18
2017 Stock Award and Incentive Plan Form of Director Restricted Stock Units Agreement (incorporated by
reference to Exhibit 10.2 to the Current Report on Form 8-K, as filed on January 23, 2020)
10.19* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Restricted Stock Units Agreement
Fiscal Year 2021 (incorporated by reference to Exhibit 10.3 to the Current Report on Form 8-K, as filed on
November 13, 2020)
10.20* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
Total Shareholder Return Fiscal Year 2021 (incorporated by reference to Exhibit 10.1 to the Current Report on
Form 8-K, as filed on November 13, 2020)
10.21* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
NFE Fiscal Year 2021 (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K, as filed on
November 13, 2020)
10.22* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance-Based Restricted Stock
Unit Agreement Fiscal Year 2021 (incorporated by reference to Exhibit 10.4 to the Current Report on Form 8-K,
as filed on November 13, 2020)
10.23* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Restricted Stock Units Agreement
Fiscal Year 2022 (incorporated by reference to Exhibit 10.3 to the Current Report on Form 8-K, as filed on
November 15, 2021)
10.24* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
Total Shareholder Return Fiscal Year 2022 (incorporated by reference to Exhibit 10.1 to the Current Report on
Form 8-K, as filed on November 15, 2021)
10.25* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
NFE Fiscal Year 2022 (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K, as filed on
November 15, 2021)
10.26* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance-Based Restricted Stock
Unit Agreement Fiscal Year 2022 (incorporated by reference to Exhibit 10.4 to the Current Report on Form 8-K,
as filed on November 15, 2021)
10.27*
Incentive Award Agreement, by and between New Jersey Resources Corporation and Timothy F. Shea, dated as
of January 26, 2022 (incorporated by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q, as filed on
February 3, 2022)
10.28* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Restricted Stock Units Agreement
Fiscal Year 2023 (incorporated by reference to Exhibit 10.3 to the Current Report on Form 8-K, as filed on
November 17, 2022)
Page 133
New Jersey Resources Corporation
Part IV
Exhibit
Number
Exhibit Description
10.29* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
Total Shareholder Return Fiscal Year 2023 (incorporated by reference to Exhibit 10.1 to the Current Report on
Form 8-K, as filed on November 17, 2022)
10.30* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
NFE Fiscal Year 2023 (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K, as filed on
November 17, 2022)
10.31* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance-Based Restricted Stock
Units Agreement Fiscal Year 2023 (incorporated by reference to Exhibit 10.4 to the Current Report on Form 8-K,
as filed on November 17, 2022)
10.32* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Restricted Stock Units Agreement
Fiscal Year 2024 (incorporated by reference to Exhibit 10.3 to the Current Report on Form 8-K, as filed on
November 21, 2023)
10.33* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
Total Shareholder Return Fiscal Year 2024 (incorporated by reference to Exhibit 10.1 to the Current Report on
Form 8-K, as filed on November 21, 2023)
10.34* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Performance Share Units Agreement -
NFE Fiscal Year 2024 (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K, as filed on
November 21, 2023)
10.35* New Jersey Resources Corporation 2017 Stock Award and Incentive Plan Restricted Stock Units Agreement
Fiscal Year 2024 (incorporated by reference to Exhibit 10.4 to the Current Report on Form 8-K, as filed on
November 21, 2023)
10.36*
10.37*
10.38*
10.39*
$500,000,000 Second Amended and Restated Credit Agreement, dated as of September 2, 2021, by and among
New Jersey Resources Corporation, the guarantors thereto, the lenders party thereto, PNC Bank, National
Association, as Administrative Agent, JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association and
Mizuho Bank, Ltd., as Syndication Agents, and U.S. Bank National Association, Bank of America, N.A., TD
Bank, N.A. and The Bank of Nova Scotia, as Documentation Agents (incorporated by reference to Exhibit 10.1 to
the Current Report on Form 8-K, as filed on September 9, 2021)
$250,000,000 Second Amended and Restated Credit Agreement dated as of September 2, 2021, by and among
New Jersey Natural Gas Company, the lenders party thereto, PNC Bank, National Association, as Administrative
Agent, JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association and Mizuho Bank, Ltd., as
Syndication Agents, and U.S. Bank National Association, Bank of America, N.A., TD Bank, N.A., and The Bank
of Nova Scotia, as Documentation Agents (incorporated by reference to Exhibit 10.2 to the Current Report on
Form 8-K, as filed on September 9, 2021)
$150,000,000 Term Loan Credit Agreement, dated as of February 8, 2022, by and among NJR, the guarantors
thereto and PNC Bank, National Association, as Lender (incorporated by reference to Exhibit 10.1 to the Current
Report on Form 8-K, as filed on February 11, 2022)
First Amendment to Second Amended and Restated Credit Agreement, dated as of August 30, 2022, by and
among NJR, the guarantors thereto, the lenders party thereto and PNC Bank, National Association, as
Administrative Agent (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K, as filed on
September 6, 2022)
10.40*
First Amendment to Second Amended and Restated Credit Agreement dated as of August 30, 2022, by and
among NJNG, the lenders party thereto and PNC Bank, National Association, as Administrative Agent
(incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K, as filed on September 6, 2022)
Page 134
New Jersey Resources Corporation
Part IV
Exhibit
Number
Exhibit Description
21.1+
23.1+
31.1+
31.2+
Subsidiaries of the Registrant
Consent of Independent Registered Public Accounting Firm
Certification of the Chief Executive Officer pursuant to section 302 of the Sarbanes-Oxley Act
Certification of the Chief Financial Officer pursuant to section 302 of the Sarbanes-Oxley Act
32.1+ † Certification of the Chief Executive Officer pursuant to section 906 of the Sarbanes-Oxley Act
32.2+ † Certification of the Chief Financial Officer pursuant to section 906 of the Sarbanes-Oxley Act
97+
Dodd-Frank Clawback Policy, adopted as of November 16, 2023, and effective as of October 2, 2023
101+
104+
Interactive Data File {Annual Report on Form 10-K, for the fiscal year ended September 30, 2023, furnished in
iXBRL (Inline eXtensible Business Reporting Language)}
Cover Page Interactive Data File included in Exhibit 101
________________________________
+ Filed herewith.
* Denotes compensatory plans or arrangements or management contracts.
† This certificate accompanies this report pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not be
deemed filed by NJR for purposes of Section 18 or any other provision of the Exchange Act.
Page 135
SIGNATURES
New Jersey Resources Corporation
Part IV
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused
this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Date: November 21, 2023
NEW JERSEY RESOURCES CORPORATION
(Registrant)
By:/s/ Stephen M. Skrocki
Stephen M. Skrocki
Corporate Controller (Principal Accounting Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following
persons on behalf of the registrant in the capacities and on the dates indicated:
November 21, 2023
/s/ Roberto Bel
Roberto Bel
Senior Vice President and
Chief Financial Officer
(Principal Financial Officer)
November 21, 2023
/s/ Jane M. Kenny
Jane M. Kenny
Director
November 21, 2023
/s/ Thomas C. O’Connor
Thomas C. O’Connor
Director
November 21, 2023
/s/ Michael O’Sullivan
Michael O’Sullivan
Director
/s/ Sharon C. Taylor
Sharon C. Taylor
Director
/s/ George R. Zoffinger
George R. Zoffinger
Director
November 21, 2023
November 21, 2023
/s/ Stephen D. Westhoven
Stephen D. Westhoven
President and Chief Executive
Officer
Director
(Principal Executive Officer)
/s/ Stephen M. Skrocki
Stephen M. Skrocki
Corporate Controller
(Principal Accounting Officer)
November 21, 2023
November 21, 2023
/s/ Donald L. Correll
Donald L. Correll
Chairman
/s/ Gregory E. Aliff
Gregory E. Aliff
Director
November 21, 2023
/s/ James H. DeGraffenreidt, Jr.
James H. DeGraffenreidt, Jr.
Director
November 21, 2023
November 21, 2023
November 21, 2023
/s/ M. Susan Hardwick
M. Susan Hardwick
Director
/s/ Peter C. Harvey
Peter C. Harvey
Director
November 21, 2023
Page 136
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Shareowner Information
Annual Meeting
The Annual Shareowners Meeting will be held at 9:30 a.m. on
January 24, 2024. This year’s annual meeting will be held virtually via
webcast with no physical in-person meeting. Please refer to your
proxy statement for the link and details on how to participate.
Stock Listing
The Company’s common stock is traded on the New York Stock
Exchange under the ticker symbol “NJR.” The stock may also appear
as NewJerRes or NJRsc in stock tables in many daily newspapers,
business publications, financial websites and search engines.
Investor and Media Information
Members of the financial community are invited to contact
Adam Prior, Director — Investor Relations, at 732-938-1145. Members
of the media are invited to contact Michael Kinney, Director —
Corporate Communications, at 732-938-1031. Correspondence can
be sent to New Jersey Resources, 1415 Wyckoff Road, P.O. Box 1468,
Wall, NJ 07719.
Stock Transfer Agent and Registrar
The Transfer Agent and Registrar for the Company’s common
stock is Broadridge Corporate Issuer Solutions, Inc. (“Broadridge”).
Shareowners with questions about account activity should contact
Broadridge investor relations representatives between 9 a.m. and
6 p.m. EST, Monday through Friday, by calling toll-free 800-817-3955.
General written inquiries and address changes may be sent to:
Broadridge Corporate Issuer Solutions
P.O. Box 1342, Brentwood, NY 11717
or
For certified and overnight delivery:
Broadridge Corporate Issuer Solutions, ATTN: IWS
1155 Long Island Avenue, Edgewood, NY 11717
• Benefit from maintenance of shares of common stock in book-entry
form and detailed record keeping and reporting, provided at no charge.
• Deposit common stock certificates registered in your name with the
plan administrator into your plan account for safekeeping, at no cost.
• Receive statements of your account following each reinvestment of
dividends and each investment of an optional cash payment or
payroll deduction amount, if any.
• Execute plan transactions online.
For additional information, please visit njresources.com, then
“Shareholder Services” under “Investor Relations.” Full details are
contained in the NJR Direct prospectus, which may be obtained
from Broadridge or the company.
Dividends
Dividends on NJR common stock are currently declared quarterly by
the board of directors. Future dividends are dependent on a number
of factors, including our earnings, financial condition, shareowner
equity levels, our cash flow and business requirements, as determined
by the board of directors. Shareowners of record receive their
dividend checks from Broadridge, unless they have elected to
reinvest their dividends with NJR Direct. The company offers direct
deposit of dividends into shareowners’ bank accounts so the funds
are available the same day they are paid. Please contact Broadridge
for details.
Request for Form 10-K and other Documents
The following documents may be obtained when available, without
charge, upon written request to: Investor Relations, New Jersey Resources,
1415 Wyckoff Road, P.O. Box 1468, Wall, NJ 07719:
• Bylaws, as amended and restated
• Annual Report and Form 10-K
Shareowners can view their account information online at
shareholder.broadridge.com/NJR.
• Form 10-Q
• Form 8-K
New Jersey Resources Direct Stock Purchase and
Dividend Reinvestment Plan
The New Jersey Resources Corporation (“NJR”) Direct Stock
Purchase and Dividend Reinvestment Plan, NJR Direct, provides
a convenient and economical method for new eligible investors
to make an initial investment in shares of common stock and for
existing shareowners to invest in additional shares of common
stock or reinvest all or some of their common stock cash dividends.
This is neither an offer to sell nor a solicitation of an offer to buy
securities. NJR Direct is administered by Broadridge.
As a participant in NJR Direct, you can:
• Conveniently purchase our common stock without incurring
brokerage commissions or transaction/processing fees.
• Quarterly Earnings News Release
• Corporate Governance Guidelines
• Audit Committee Charter
• Leadership Development and Compensation Committee Charter
• Nominating/Corporate Governance Committee Charter
• NJR Code of Conduct
• Audit Complaint Procedure
• Communicating with Non-Management Directors
• Statement of Policy with Respect to Related Person Transactions
These documents, as well as other filings made with the Securities and
Exchange Commission, are also available through njresources.com.
Information in this Annual Report should not be considered a
• Build your investment over time, starting with as little as $100,
solicitation of the sale or purchase of securities.
up to a maximum of $100,000 per calendar year.
• Increase your holdings in NJR by reinvesting all or some of your
cash dividends in our common stock.
• Invest automatically with optional withdrawals from your
bank account.
Design: Decker Design, Inc., New York
Printed on recycled paper.
1415 Wyckoff Road
Post Office Box 1468
Wall, NJ 07719
732-938-1480
www.njresources.com
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