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Property Plant and Equipment (Details)
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Capitalized and Deferred Interest (Details)
64: R51 Summary of Significant Accounting Policies - Cash, HTML 44K
Cash Equivalents and Restricted Cash (Details)
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Natural Gas in Storage (Details)
66: R53 Summary of Significant Accounting Policies - HTML 62K
Software Costs (Details)
67: R54 Summary of Significant Accounting Policies- Asset HTML 63K
Retirement Obligations (Details)
68: R55 Summary of Significant Accounting Policies - HTML 74K
Accumulated Other Comprehensive Income (Details)
69: R56 Revenue - Disaggregated Revenue - Product HTML 134K
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72: R59 Revenue - Timing of Revenue Recognition - Balance HTML 65K
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Disclosures (Details)
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Liabilities (Details)
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Stock/Non-Employee Director Stock (Details)
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Postemployment Benefit Plans, Narrative (Details)
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Funded Status and Liabilities (Details)
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Aoci (Details)
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Proceedings (Details)
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Reconciliation of Segment Income to Consolidated
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(Exact name of registrant as specified in its charter)
iNew Jersey
i22-2376465
(State
or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification Number)
i1415 Wyckoff Road,
iWall,
iNew
Jersey
i07719
i(732)
i938‑1000
(Address
of principal executive offices)
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12 (b) of the Act:
Title of each class
Trading symbol(s)
Name of each exchange on which registered
iCommon
Stock ‑ $2.50 Par Value
iNJR
iNew York Stock Exchange
Securities registered pursuant to Section 12 (g) of the Act:
None
Indicate by check mark if the
registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☒iYes☐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 ☒iNo
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. ☒iYes☐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).
☒iYes☐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.
iLarge
accelerated filer
☒
Accelerated filer
☐
Non-accelerated filer
☐
Smaller reporting company
i☐
Emerging
growth company
i☐
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. i☒
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. i☐
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). i☐Yes ☒No
The aggregate market value of the registrant’s common stock held by non-affiliates was $i5,138,493,161
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 i97,707,564.
Coronavirus Aid, Relief, and Economic Security Act
CIP
Conservation Incentive Program
Clean Energy Ventures or CEV
Clean Energy Ventures segment
CME
Chicago Mercantile Exchange
COVID-19
Novel
coronavirus disease
CR&R
Commercial Realty & Resources Corp.
CSI
Competitive Solar Incentive
Degree-day
The measure of the variation in the weather based on the extent to which the average daily temperature falls below 65 degrees Fahrenheit
DEI
Diversity, equity and inclusion
DRP
NJR Direct Stock Purchase and Dividend Reinvestment Plan
Dths
Dekatherms
EDECA
Electric
Discount and Energy Competition Act
EE
Energy Efficiency
EMP
New Jersey Energy Master Plan
Energy Services or ES
Energy Services segment
Exchange Act
Securities Exchange Act of 1934, as amended
FASB
Financial Accounting Standards Board
FCM
Futures Commission
Merchant
FERC
Federal Energy Regulatory Commission
Financial Margin
A non-GAAP financial measure, which represents revenues earned from the sale of natural gas less costs of natural gas sold including any transportation and storage costs, and excludes 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
Fitch Ratings Company
FMB
First Mortgage Bond
GAAP
Generally
Accepted Accounting Principles of the United States
GWRA
Global Warming Response Act of 2007
HCCTR
Health Care Cost Trend Rate
Home Services and Other or HSO
Home Services and Other Operations
ICE
Intercontinental Exchange
IIP
Infrastructure Investment Program
Inflation Reduction Act
Inflation
Reduction Act of 2022
IRS
Internal Revenue Service
ISDA
The International Swaps and Derivatives Association
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
MW
Megawatts
Page
1
New Jersey Resources Corporation
GLOSSARY OF KEY TERMS (cont.)
MWh
Megawatt Hour
NAESB
The North American Energy Standards Board
NAV
Net Asset Value
NFE
Net
Financial Earnings
NJ RISE
New Jersey Reinvestment in System Enhancement
NJCEP
New Jersey’s Clean Energy Program
NJDEP
New Jersey Department of Environmental Protection
NJNG
New Jersey Natural Gas Company or our Natural Gas Distribution segment
NJNG Credit Facility
The $250M unsecured committed credit facility expiring in September 2027
NJR
Credit Facility
The $650M unsecured committed credit facility expiring in September 2027
Safety Acceleration and Facility Enhancement Program, Phase II
Sarbanes-Oxley
Sarbanes-Oxley Act of 2002
SAVEGREEN
The SAVEGREEN Project®
Savings Plan
Employees’ Retirement Savings Plan
SBC
Societal Benefits Charge
SEC
Securities
and Exchange Commission
Securities Act
Securities Act of 1933, as amended
SOFR
Secured Overnight Financing Rate
SREC
Solar Renewable Energy Certificate
SRL
Southern Reliability Link
S&P
Standard & Poor’s Financial Services, LLC
Steckman Ridge
Collectively, Steckman Ridge GP, LLC and
Steckman Ridge, LP
Storage and Transportation or S&T
Storage and Transportation segment
TETCO
Texas Eastern Transmission
TREC
Transition Renewable Energy Certificate
Trustee
U.S. Bank National Association
TSR
Total Shareholder Return
U.S.
The United States of America
Union
International
Brotherhood of Electrical Workers Local 1820
USF
Universal Service Fund
Utility Gross Margin
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:
•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;
•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.
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.
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
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)
2023
2022
2021
Net
income
$
264,724
$
274,922
$
117,890
Add:
Unrealized (gain) loss on derivative instruments and related transactions
(38,081)
(59,906)
54,203
Tax
effect
9,050
14,248
(12,887)
Effects of economic hedging related to natural gas inventory
34,699
19,939
(42,405)
Tax effect
(8,246)
(4,738)
10,078
(Gain
on) impairment of equity method investment
(300)
(5,521)
92,000
Tax effect
(19)
1,377
(11,167)
NFE
$
261,827
$
240,321
$
207,712
Basic
earnings per share
$
2.73
$
2.86
$
1.23
Add:
Unrealized (gain) loss on derivative instruments and related transactions
(0.39)
(0.62)
0.56
Tax effect
0.09
0.15
(0.13)
Effects
of economic hedging related to natural gas inventory
0.36
0.21
(0.44)
Tax effect
(0.09)
(0.05)
0.10
(Gain on) impairment of equity method investment
—
(0.06)
0.96
Tax
effect
—
0.01
(0.12)
Basic NFE per share
$
2.70
$
2.50
$
2.16
NFE by reporting segment and other business operations for the fiscal years ended September 30, are as follows:
Page
6
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:
2023
2022
2021
($
in thousands)
Operating Revenue
Bcf
Operating Revenue
Bcf
Operating Revenue
Bcf
Residential
$
643,756
43.4
$
598,433
45.5
$
484,407
46.2
Commercial
and other
137,343
8.4
140,727
8.7
103,341
8.6
Firm transportation
79,537
12.1
80,915
13.0
69,353
13.7
Total
residential and commercial
860,636
63.9
820,075
67.2
657,101
68.5
Interruptible/off-tariff agreements/other
9,996
29.5
9,740
32.4
7,239
22.9
Total
system
870,632
93.4
829,815
99.6
664,340
91.4
BGSS incentive programs (1)
142,001
34.9
298,952
44.5
67,456
20.8
Total
$
1,012,633
128.3
$
1,128,767
144.1
$
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.
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
Dths
(1)
Expiration
Transcontinental Gas Pipe Line Corp.
332,531
Various dates between 2024 and 2033
Texas Eastern Transmission, L.P.
383,588
Various dates between 2024 and 2025
Columbia Gas Transmission Corp.
50,000
Various dates between 2024 and
2030
Tennessee Gas Pipeline Co.
25,166
Various dates between 2028 and 2029
Algonquin Gas Transmission
12,000
2025
Total
803,285
(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
Dths
Expiration
Texas
Eastern Transmission, L.P.
94,557
2025
Transcontinental Gas Pipe Line Corp.
8,384
2028
Total
102,941
NJNG also has upstream storage contracts. The maximum daily deliverability and contract
expiration dates are as follows:
Company
Dths
Expiration
Eastern Gas Transmission and Storage
286,829
Various dates between 2024 and 2026
Steckman Ridge, L.P.
38,000
2025
Stagecoach
Pipeline & Storage Company LLC
25,337
2028
Total
350,166
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
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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.
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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.
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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.
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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 Analysisof 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.
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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
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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
•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 Jersey07719.
INFORMATION ABOUT OUR EXECUTIVE OFFICERS
The
Company’s Executive Officers and their age, position and business experience during the past five years are below.
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)
Patrick J. Migliaccio
49
2013
Senior Vice President and Chief Operating Officer (January 2022 -
present) Senior Vice President and Chief Financial Officer (January 2016 - December 2021)
Amy Cradic
52
2018
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)
Richard Reich
48
2016
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)
Lori DelGiudice
48
2023
Senior Vice President, Human Resources (November 2022 - present) Vice President of Human Resources for Honeywell Advanced Materials (September 2017 - October 2022)
Jacqueline K. Shea
59
2016
Senior Vice President and Chief Information Officer (January 2023 - present) Vice President and Chief Information Officer (June 2016 - December 2022)
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
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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 RNGand 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
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16
New Jersey Resources Corporation
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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.
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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.
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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
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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.
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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.
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New Jersey Resources Corporation
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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
2018
2019
2020
2021
2022
2023
NJR
$100.00
$100.52
$62.55
$83.47
$96.11
$104.30
S&P
500 Utilities
$100.00
$127.10
$120.79
$134.09
$141.56
$131.63
S&P 500
$100.00
$104.25
$120.05
$156.07
$131.92
$160.44
Peer Group
$100.00
$117.06
$89.97
$98.14
$109.62
$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
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
07/01/23 - 07/31/23
—
$
—
—
1,685,053
08/01/23 - 08/31/23
—
$
—
—
1,685,053
09/01/23
- 09/30/23
—
$
—
—
1,685,053
Total
—
$
—
—
1,685,053
ITEM
6. [RESERVED]
Page 28
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
Increase/ (Decrease)
Estimated
Increase/(Decrease) on PBO
(Thousands)
Estimated
Increase/(Decrease) to Expense
(Thousands)
Discount rate
1.00
%
$
(28,573)
$
(88)
Discount
rate
(1.00)
%
$
34,313
$
4,131
Rate of return on plan assets
1.00
%
n/a
$
(2,854)
Rate
of return on plan assets
(1.00)
%
n/a
$
2,854
Other
Postemployment Benefits
Actuarial Assumptions
Increase/ (Decrease)
Estimated
Increase/(Decrease) on PBO
(Thousands)
Estimated
Increase/(Decrease) to Expense
(Thousands)
Discount rate
1.00
%
$
(25,370)
$
(154)
Discount
rate
(1.00)
%
$
31,353
$
2,515
Rate of return on plan assets
1.00
%
n/a
$
(961)
Rate
of return on plan assets
(1.00)
%
n/a
$
960
Actuarial Assumptions
Increase/ (Decrease)
Estimated
Increase/(Decrease)
on PBO
(Thousands)
Estimated
Increase/(Decrease) to Expense
(Thousands)
Health care cost trend rate
1.00
%
$
30,818
$
4,522
Health care cost trend rate
(1.00)
%
$
(25,283)
$
(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)
2023
2022
2021
Net
Income
Assets
Net Income
Assets
Net Income
Assets
NJNG
$
131,414
$
4,414,829
$
140,124
$
4,030,686
$
107,375
$
3,707,461
CEV
44,458
1,128,577
39,403
1,015,065
16,789
914,788
ES
78,848
123,775
69,650
333,064
58,957
365,423
S&T
13,154
1,011,959
26,598
999,520
(67,787)
862,407
HSO
4,758
171,275
(781)
159,068
(826)
162,134
Intercompany
(1)
(7,908)
(312,919)
(72)
(275,987)
3,382
(289,935)
Total
$
264,724
$
6,537,496
$
274,922
$
6,261,416
$
117,890
$
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)
2023
2022
2021
Net income
$
264,724
$
274,922
$
117,890
Add:
Unrealized (gain) loss on derivative instruments and related transactions
(38,081)
(59,906)
54,203
Tax
effect
9,050
14,248
(12,887)
Effects of economic hedging related to natural gas inventory (1)
34,699
19,939
(42,405)
Tax effect
(8,246)
(4,738)
10,078
(Gain
on) impairment of equity method investment
(300)
(5,521)
92,000
Tax effect
(19)
1,377
(11,167)
Net financial earnings
$
261,827
$
240,321
$
207,712
Basic
earnings per share
$
2.73
$
2.86
$
1.23
Add:
Unrealized (gain) loss on derivative instruments and related transactions
(0.39)
(0.62)
0.56
Tax effect
0.09
0.15
(0.13)
Effects
of economic hedging related to natural gas inventory (1)
0.36
0.21
(0.44)
Tax effect
(0.09)
(0.05)
0.10
(Gain on) impairment of equity method investment
—
(0.06)
0.96
Tax
effect
—
0.01
(0.12)
Basic NFE per share
$
2.70
$
2.50
$
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)
2023
2022
2021
NJNG
$
131,414
50
%
$
140,124
58
%
$
107,375
52
%
CEV
44,458
17
39,403
17
16,789
8
ES
68,517
26
39,121
16
71,117
34
S&T
12,835
5
22,454
9
13,046
6
HSO
4,758
2
(781)
—
(826)
—
Eliminations
(1)
(155)
—
—
—
211
—
Total
$
261,827
100
%
$
240,321
100
%
$
207,712
100
%
(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
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:
2023
2022
2021
Firm
customers
Residential
520,682
512,264
502,546
Commercial, industrial & other
31,725
31,227
30,615
Residential transport
15,457
17,316
21,882
Commercial
transport
8,033
8,397
8,815
Total firm customers
575,897
569,204
563,858
Other
103
96
47
Total
customers
576,000
569,300
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)
2023
2022
Loans
$
198,600
$
175,300
Grants,
rebates and related investments
205,200
168,700
Total
$
403,800
$
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)
2023
2022
2021
Weather (1)
$
44,675
$
22,263
$
13,273
Usage
3,276
2,032
(1,852)
Total
$
47,951
$
24,295
$
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.
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New Jersey Resources Corporation
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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
(Continued)
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.
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New
Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Results
NJNG’s operating results for the fiscal years ended September 30, are as follows:
(Thousands)
2023
2022
2021
Operating
revenues (1)
$
1,012,633
$
1,128,767
$
731,796
Operating expenses
Natural gas purchases (2) (3)
425,457
557,232
260,714
Operation
and maintenance
226,780
198,546
203,740
Regulatory rider expense (4)
50,542
59,437
38,304
Depreciation and amortization
102,326
94,579
80,045
Total
operating expenses
805,105
909,794
582,803
Operating income
207,528
218,973
148,993
Other income, net
13,546
7,686
13,841
Interest
expense, net of capitalized interest
56,595
46,394
36,405
Income tax provision
33,065
40,141
19,054
Net income
$
131,414
$
140,124
$
107,375
(1)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.
(2)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.
(3)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.
(4)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:
2023
v. 2022
(Thousands)
Operating revenues
Natural gas purchases
BGSS incentives
$
(156,951)
$
(157,384)
Bill credits
(31,581)
(31,581)
Firm sales
(24,005)
(19,536)
Average
BGSS rates
75,105
75,105
CIP adjustments
23,656
—
Base rate impact
6,927
—
Riders and other (1)
(9,285)
1,621
Total
decrease
$
(116,134)
$
(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
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New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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)
2023
2022
2021
Operating
revenues
$
1,012,633
$
1,128,767
$
731,796
Less:
Natural gas purchases
425,457
557,232
260,714
Operation
and maintenance (1)
115,292
93,164
110,364
Regulatory rider expense
50,542
59,437
38,304
Depreciation and amortization
102,326
94,579
80,045
Gross
margin
319,016
324,355
242,369
Add:
Operation and maintenance (1)
115,292
93,164
110,364
Depreciation and amortization
102,326
94,579
80,045
Utility
Gross Margin
$
536,634
$
512,098
$
432,778
(1)Excludes selling, general and administrative expenses of approximately $111.5M, $102.8M and $97.0M for the fiscal years 2023, 2022 and 2021, respectively.
Utility Gross Margin consists of three components:
•Utility firm gross margin generated from only the delivery component of either a sales tariff or a transportation
tariff from residential and commercial customers who receive natural gas service from NJNG;
•BGSS incentive programs, where revenues generated or savings achieved from BPU-approved off-system sales, capacity release or storage incentive programs are shared between customers and NJNG; and
•Utility Gross Margin generated from off-tariff customers, as well as interruptible customers.
The following provides more information on the components of Utility Gross Margin and associated throughput (Bcf) of natural gas delivered to customers:
2023
2022
2021
($
in thousands)
Margin
Bcf
Margin
Bcf
Margin
Bcf
Utility Gross Margin/Throughput
Residential
$
360,138
43.4
$
341,167
45.5
288,723
45.5
Commercial,
industrial and other
76,550
8.4
77,629
8.7
64,950
8.7
Firm transportation
76,114
12.1
69,933
13.0
61,870
13.0
Total
utility firm gross margin/throughput
512,802
63.9
488,729
67.2
415,543
67.2
BGSS incentive programs
20,020
72.6
19,587
95.2
13,415
95.2
Interruptible/off-tariff
agreements
3,812
29.5
3,782
32.4
3,820
32.4
Total Utility Gross Margin/Throughput
$
536,634
166.0
$
512,098
194.8
$
432,778
194.8
Utility
Firm Gross Margin
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)
2023 v. 2022
Storage
$
417
Capacity release
208
Off-system
sales
$
(192)
Total increase
$
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.
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New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF
OPERATIONS (Continued)
Solar
Solar projects placed in service and related expenditures for the fiscal years ended September 30, are as follows:
($
in Thousands)
2023
2022
2021
Placed in service
Projects
MW
Costs
Projects
MW
Costs
Projects
MW
Costs
Grid-connected (1) (2)
5
42.0
$
106,558
3
14.0
$
31,411
1
2.9
$
3,433
Net-metered:
Commercial
(1) (3)
5
36.1
50,610
2
1.0
2,440
1
2.7
5,576
Residential
339
4.1
12,677
360
3.9
11,544
421
4.8
13,885
Total
placed in service
349
82.2
$
169,845
365
18.9
$
45,395
423
10.4
$
22,894
(1)Includes
projects subject to sale leaseback arrangements.
(2)Includes an operational 2.9 MW commercial solar project acquired in December 2020.
(3)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.
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New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
REC activity consisted of the following:
Inventory
balance as of October 1,
RECs
Inventory balance as of September 30,
Average
Generated
Delivered
Sale Price
2023
SRECs
116,005
422,039
(393,906)
144,138
$202
TRECs
(1)
10,759
80,520
(81,159)
10,120
$144
SREC IIs (1)
247
10,260
(4,494)
6,013
$90
2022
SRECs
(2)
108,104
425,453
(417,305)
116,252
$202
TRECs
6,944
38,914
(35,099)
10,759
$139
2021
SRECs
35,011
406,118
(333,025)
108,104
$196
TRECs
(1)
9,270
31,767
(34,093)
6,944
$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)
Percent
of SRECs Hedged
2024
100%
2025
89%
2026
80%
2027
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)
2023
2022
2021
Operating
revenues
$
124,131
$
128,280
$
95,275
Operating expenses
Operation and maintenance
40,089
40,706
36,715
Depreciation
and amortization
25,320
21,396
20,567
Total operating expenses
65,409
62,102
57,282
Operating income
58,722
66,178
37,993
Other
income, net
6,622
6,554
6,392
Interest expense, net
28,569
21,968
22,548
Income tax (benefit) provision
(7,683)
11,361
5,048
Net
income
$
44,458
$
39,403
$
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.
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New
Jersey Resources Corporation
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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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.
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New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Results
ES’s financial results for the fiscal
years ended September 30, are summarized as follows:
(Thousands)
2023
2022
2021
Operating revenues (1)
$
691,616
$
1,529,272
$
1,228,420
Operating
expenses
Natural gas purchases (including demand charges (2)(3))
558,932
1,394,405
1,098,261
Operation and maintenance
19,351
39,080
50,885
Depreciation
and amortization
221
148
111
Total operating expenses
578,504
1,433,633
1,149,257
Operating income
113,112
95,639
79,163
Other
income, net
1,479
512
369
Interest expense, net
11,400
4,725
2,204
Income tax provision
24,343
21,776
18,371
Net
income
$
78,848
$
69,650
$
58,957
(1)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.
(2)Costs associated with pipeline and storage capacity are expensed over the term of the related contracts, which generally varies from less than one year to 10 years.
(3)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:
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 Analysisof Financial Condition and Results of Operations - Natural Gas DistributionforTETCO 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)
2023
2022
2021
Operating
revenues
$
691,616
$
1,529,272
$
1,228,420
Less:
Natural gas purchases
558,932
1,394,405
1,098,261
Operation
and maintenance (1)
20,199
23,709
33,263
Depreciation and amortization
221
148
111
Gross margin
112,264
111,010
96,785
Add:
Operation
and maintenance (1)
20,199
23,709
33,263
Depreciation and amortization
221
148
111
Unrealized (gain) loss on derivative instruments and related transactions
(2)
(48,251)
(60,000)
58,362
Effects
of economic hedging related to natural gas inventory (3)
34,699
19,939
(42,405)
Financial margin
$
119,132
$
94,806
$
146,116
(1)Excludes general and administrative
expenses of $(0.8)M, $15.4M and $17.6M for fiscal 2023, 2022 and 2021, respectively.
(2)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.
(3)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.
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New Jersey Resources Corporation
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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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)
2023
2022
2021
Net
income
$
78,848
$
69,650
$
58,957
Add:
Unrealized (gain) loss on derivative instruments and related transactions
(48,251)
(60,000)
58,362
Tax
effect (1)
11,467
14,270
(13,875)
Effects of economic hedging related to natural gas inventory
34,699
19,939
(42,405)
Tax effect
(8,246)
(4,738)
10,078
Net
financial earnings
$
68,517
$
39,121
$
71,117
(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.
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New Jersey Resources Corporation
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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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)
2023
2022
2021
Operating revenues (1)
$
92,859
$
67,735
$
51,020
Operating
expenses
Natural gas purchases
1,601
2,702
1,266
Operation and maintenance
34,648
30,568
29,135
Depreciation and amortization
24,185
12,302
9,960
Total
operating expenses
60,434
45,572
40,361
Operating income
32,425
22,163
10,659
Other income, net
6,850
8,546
5,931
Interest
expense, net
25,803
12,097
13,348
Income tax provision (benefit)
3,444
1,879
(10,043)
Equity in earnings (loss) of affiliates
3,126
9,865
(81,072)
Net
income (loss)
$
13,154
$
26,598
$
(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.
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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)
2023
2022
2021
Net income (loss)
$
13,154
$
26,598
$
(67,787)
Add:
(Gain
on) impairment of equity method investment
(300)
(5,521)
92,000
Tax effect
(19)
1,377
(11,167)
Net financial earnings
$
12,835
$
22,454
$
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)
2023
2022
2021
Operating revenues
$
57,638
$
56,182
$
52,229
Income
(loss) before income taxes
$
3,281
$
278
$
(1,022)
Income tax (benefit) provision
(1,477)
1,059
(196)
Net income (loss)
$
4,758
$
(781)
$
(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:
2023
2022
Common stock equity
39
%
38
%
Long-term debt
54
52
Short-term
debt
7
10
Total
100
%
100
%
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New Jersey Resources Corporation
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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
(Continued)
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.
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New
Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
Weighted
average interest rate for average balance
5.78
%
Month end maximum for the period
$
465,000
NJNG
Commercial Paper and Notes Payable to banks:
Balance at end of period
$
34,800
Weighted
average interest rate at end of period
5.48
%
Average balance for the period
$
40,685
Weighted average interest rate for average balance
4.82
%
Month end maximum for the period
$
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.
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New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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;
•enter into transactions with affiliates; and
•merge,
consolidate, transfer, sell or lease all or substantially all of the borrowers’ or guarantors’ assets.
These covenants are subject to a number of exceptions and qualifications set forth in the applicable agreements.
Default Provisions
The agreements governing our long-term and short-term debt obligations include provisions that, if not complied with, could require early payment or similar actions. Default events include, but are not limited to, the following:
•defaults for non-payment;
•defaults for breach of representations and warranties;
•defaults
for insolvency;
•defaults for non-performance of covenants;
•cross-defaults to other debt obligations of the borrower; and
•guarantor defaults.
The occurrence of an event of default under these agreements could result in all loans and other obligations of the borrower becoming immediately due and payable and the termination of the credit facilities or term loan.
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 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);
•incur
liens and encumbrances;
•make loans and investments;
•make dispositions of assets;
•make dividends or restricted payments;
•enter into transactions with affiliates; and
•merge, consolidate, transfer, sell or lease substantially all of the borrower’s assets.
The aforementioned covenants are subject to a number of exceptions and qualifications set forth in the applicable note purchase agreements.
In addition, the FMBs issued by NJNG under the Mortgage Indenture
are subject to certain default provisions. Events of Default, as defined in the Mortgage Indenture, consist mainly of:
•failure for 30 days to pay interest when due;
•failure to pay principal or premium when due and payable;
•failure to make sinking fund payments when due;
•failure to comply with any other covenants of the Mortgage Indenture after 30 days’ written notice from the Trustee;
•failure to pay or provide for
judgments in excess of $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.
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New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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.
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New Jersey Resources Corporation
Part II
ITEM
7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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.
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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:
Moody’s
Fitch
Corporate
Rating
N/A
A-
Commercial Paper
P-2
F-2
Senior Secured
A1
A+
Ratings Outlook
Stable
Stable
The Fitch ratings and outlook were reaffirmed on 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:
There
were no changes in methods of valuations during the fiscal year ended September 30, 2023.
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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)
2024
2025
2026 - 2028
After 2028
Total Fair Value
Price
based on ICE
$
21,604
$
593
$
71
$
—
$
22,268
The
following is a summary of financial derivatives by type as of September 30, 2023:
Volume Bcf
Price per MMBtu
Amounts included in Derivatives (Thousands)
NJNG
Futures
32.1
$0.97
- $5.89
$
6,090
ES
Futures
(6.9)
$0.00 - $6.87
16,178
Total
$
22,268
The
following table reflects the changes in the fair market value of physical commodity contracts:
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)
Henry Hub Futures and Fixed Price Swaps
Percent increase in NYMEX natural gas futures prices
0%
5%
10%
15%
20%
Estimated change in derivative fair value
$
—
$
(1,805)
$
(3,611)
$
(5,417)
$
(7,222)
Ending
derivative fair value
$
14,392
$
12,587
$
10,781
$
8,975
$
7,170
Percent decrease in NYMEX natural gas futures prices
0%
(5)%
(10)%
(15)%
(20)%
Estimated
change in derivative fair value
$
—
$
1,805
$
3,611
$
5,417
$
7,222
Ending derivative fair value
$
14,392
$
16,197
$
18,003
$
19,809
$
21,614
Wholesale
Credit Risk
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.
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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)
Gross
Credit Exposure
Net Credit Exposure
Investment grade
$
105,765
$
102,746
Noninvestment grade
4,548
372
Internally-rated investment grade
19,549
18,802
Internally-rated
noninvestment grade
19,897
16,850
Total
$
149,759
$
138,770
NJNG’s counterparty credit exposure as of September 30, 2023, is as follows:
(Thousands)
Gross
Credit Exposure
Net Credit Exposure
Investment grade
$
13,464
$
13,112
Noninvestment grade
227
—
Internally-rated investment grade
794
679
Internally-rated
noninvestment grade
256
192
Total
$
14,741
$
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.
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 Factorsfor additional information related to the impact of recent increases in inflation rates.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
Management of New Jersey Resources Corporation is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) and 15d-15(f) of the 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.
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.
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ITEM
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
NJNG is subject to cost-based regulation; therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility capital investments based on the BPU’s approval. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets, and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations. Regulatory decisions can have an impact on the recovery of costs, the rate of return earned on investment, and the timing and amount of assets to be recovered by rates. Decisions to be made by the BPU in the future will
impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required.
Accounting for the economics of rate-regulation impacts multiple financial statement line items and disclosures, such as regulated property, plant, and equipment, regulatory assets and liabilities, operating revenues and depreciation expense. While NJNG 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.
We have served as the Company’s auditor since 1951.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareowners and the Board of Directors of New Jersey Resources Corporation:
Opinion on 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.
(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
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New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
i
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 i576,000 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 i50%
combined ownership interest in Steckman Ridge, located in Pennsylvania, which is accounted for under the equity method of accounting, and i20% ownership interest in PennEast, which ceased operations in fiscal 2022.
NJR Retail Holdings Corporation has ione
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.
/
i
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
i
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.
i
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.
/
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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.
i
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 i5
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 $i48.5M
and $i53.0M of operating revenue on the Consolidated Statements of Operations during fiscal 2023 and 2022, respectively. Amounts received in excess of revenue recognized totaling $i58.7M and $i33.8M
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.
/
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
i
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.
i
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 i10 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.
/
i
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)
2023
2022
2021
ES
$
i74.6
$
i95.4
$
i120.5
NJNG
i183.4
i170.3
i123.2
Total
$
i258.0
$
i265.7
$
i243.7
/
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.
i
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.
iStock-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)
i
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.
i
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.
i
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 i2.68% of average depreciable property in fiscal 2023, i2.66%
in fiscal 2022 and i2.42% in fiscal 2021. The Company recorded $i152.9M,
$i129.2M and $i111.4M 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)
i
Property, plant and equipment was comprised of the following as of September 30:
(Thousands)
Estimated
Property
Classifications
Useful Lives
2023
2022
Distribution facilities
i11 to i54
years
$
i3,063,111
$
i2,797,936
Transmission
facilities
i28 to i42 years
i650,817
i649,241
Storage
facilities
i27 to i86 years
i85,603
i85,449
Solar
property
i20 to i35 years
i864,838
i710,224
Storage
and transportation property
i5 to i50 years
i884,647
i850,186
All
other property
i5 to i40 years
i61,327
i60,914
Construction
work in progress
i380,196
i361,766
Total
property, plant and equipment
i5,990,539
i5,515,716
Accumulated
depreciation and amortization
(i968,484)
(i865,790)
Property,
plant and equipment, net
$
i5,022,055
$
i4,649,926
/
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 $i20.9M and $i15.1M,
respectively.
i
Capitalized and Deferred Interest
NJNG’s base rates include the ability to recover AFUDC on its construction work in progress. For all NJNG construction projects, an incremental cost of equity is recoverable during periods when NJNG’s short-term debt balances are lower than its construction work in progress. For more information on AFUDC treatment with respect to certain accelerated infrastructure projects, see Note 4. Regulation
- Infrastructure Programs. Capitalized amounts associated with the debt and equity components of NJNG’s AFUDC are recorded in utility plant on the Consolidated Balance Sheets. Corresponding amounts for the debt component are recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations.
Adelphia’s base rates include the ability to recover AFUDC on its construction work in progress. Capitalized amounts associated with Adelphia’s AFUDC are recorded in nonutility plant on the Consolidated Balance Sheets. Corresponding amounts for the debt component are recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations.
i
Capitalized
and deferred interest include the following for the fiscal years ended September 30:
($ in thousands)
2023
2022
2021
AFUDC:
NJNG
Adelphia
NJNG
Adelphia
NJNG
Adelphia
Debt
$
i3,546
$
i90
$
i1,648
$
i4,019
$
i5,648
$
i2,101
Equity
i6,979
i158
i4,169
i7,074
i16,605
i3,698
Total
$
i10,525
$
i248
$
i5,817
$
i11,093
$
i22,253
$
i5,799
Weighted
average interest rate
i6.41
%
i8.28
%
i4.91
%
i8.28
%
i5.97
%
i8.28
%
/
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 iseven-year constant maturity treasury rate plus i60 basis points. The rate was i4.79%,
i3.85% and i1.68% for the fiscal years ended September 30, 2023, 2022 and 2021, respectively. Accordingly, other income included $i1.8M,
$i0.9M and $i0.3M 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)
i
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.
i
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)
2023
2022
2021
Balance Sheet
Cash and cash equivalents
$
i954
$
i1,107
$
i4,749
Restricted
cash in other noncurrent assets
$
i563
$
i345
$
i1,294
Statements
of Cash Flow
Cash, cash equivalents and restricted cash
$
i1,517
$
i1,452
$
i6,043
/
i
Allowance
for Doubtful Accounts
The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations and macroeconomic factors, such as unemployment rates among others.
iLoans
Receivable
NJNG currently provides loans, with terms ranging from two to i10 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 $i15.1M
and $i14.5M recorded in other current assets and $i39.0M and $i34.7M
in other noncurrent assets as of September 30, 2023 and 2022, respectively, on the Consolidated Balance Sheets, related to the loans. The Company regularly evaluates the credit quality and collection profile of its customers. If NJNG determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of September 30, 2023 and 2022, the Company has not recorded any impairments for SAVEGREEN loans.
i
Regulatory
Assets & Liabilities
Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment.
NJNG is subject to accounting requirements resulting from the effects of rate regulation by the BPU. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of NJNG’s regulatory
assets and liabilities.
Adelphia capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of Adelphia’s regulatory assets and liabilities.
Page 77
New Jersey Resources Corporation
Part II
ITEM
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
iNatural Gas in Storage
Natural gas in storage is reflected at average cost on the Consolidated Balance Sheets and represents natural gas and LNG that will be utilized in the ordinary course of business. iThe
following table summarizes natural gas in storage, at average cost by company, as of September 30:
2023
2022
($ in thousands)
Natural Gas in Storage
Bcf
Natural Gas in Storage
Bcf
NJNG
$
i175,025
i29.1
$
i191,175
i29.0
ES
i24,476
i14.6
i82,469
i10.8
Total
$
i199,501
i43.7
$
i273,644
i39.8
i
Derivative
Instruments
The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts and interest rate contracts, as well as its physical commodity contracts related to the purchase and sale of natural gas at 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 $ii0.2/M
for NJNG and $ii1.1/M
for NJR.
/
Page 78
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
i
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.
i
The
following table presents the software costs included in the Consolidated Financial Statements, as of September 30:
(Thousands)
2023
2022
Balance Sheets
Utility plant, at cost
$
i51,282
$
i40,437
Construction
work in progress
$
i55,012
$
i14,381
Nonutility
plant and equipment, at cost
$
i344
$
i344
Accumulated
depreciation and amortization, utility plant
$
(i7,480)
$
(i3,361)
Accumulated
depreciation and amortization, nonutility plant and equipment
$
(i36)
$
(i25)
Software
costs
$
i8,375
$
i6,120
Statements
of Operations
Operation and maintenance (1)
$
i14,299
$
i11,141
Depreciation
and amortization
$
i4,130
$
i2,024
(1)During
both fiscal 2023 and 2022, $ii0.5/M was amortized from software
costs into O&M.
/
i
Intangible Assets
Finite-lived intangible assets are stated at cost less accumulated amortization. The Company amortizes intangible assets based upon the pattern in which the economic benefits are consumed over the life of the asset unless
a pattern cannot be reliably determined, in which case the Company uses a straight-line amortization method. As of September 30, 2023, intangible assets consist primarily of acquired wholesale natural gas energy contracts totaling $i0.1M, 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.
/
i
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)
i
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.
i
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.
i
Pension
and Postemployment Plans
The Company has itwo 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 iino/t
make any discretionary contributions to the pension plans during fiscal 2023 and 2022.
/
The Company also provides itwo 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 $i4.2M and $i6.1M
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)
i
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.
i
The
following is an analysis of the change in the Company’s ARO for the fiscal years ended September 30:
(Thousands)
Balance at October 1
Accretion
Additions
Change in assumptions
Retirements
Balance
at period end
2023
NJNG
$
i49,874
i2,693
i155
i4,089
(i1,526)
$
i55,285
NJRCEV
$
i5,161
i213
i1,334
i—
i—
$
i6,708
2022
NJNG
$
i41,611
i2,052
i161
i7,339
(i1,289)
$
i49,874
NJRCEV
$
i4,694
i186
i281
i—
i—
$
i5,161
/
i
Accretion
for the next five years, for the fiscal years ended September 30, is estimated to be as follows:
(Thousands)
2024
2025
2026
2027
2028
Total
Estimated
Accretion
$
i3,114
i3,268
i3,429
i3,597
i3,781
$
i17,189
/
Page
81
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Accumulated Other Comprehensive Income
i
The following table presents the changes in the components of accumulated other
comprehensive income, net of related tax effects:
(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.
/
i
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.
i
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.
i
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.
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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.
i
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.
i
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
Performance Obligation
Description
NJNG
Natural
gas utility sales
NJNG’s performance obligation is to provide natural gas to residential, commercial and industrial customers as demanded, based on regulated tariff rates, which are established by the BPU. Revenues from the sale of natural gas are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for quantities consumed but not billed during the period. Payment is due each month for the previous month’s deliveries. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the billing period. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects and the most current tariff rates. NJNG is entitled to be compensated for performance completed until service is terminated. Customers may elect to purchase
the natural gas commodity from NJNG or may contract separately to purchase natural gas directly from third-party suppliers. As NJNG is acting as an agent on behalf of the third-party supplier, revenue is recorded for the delivery of natural gas to the customer.
CEV
Commercial solar electricity
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
Residential solar electricity
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.
/
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Revenue
Recognized Over Time (continued):
Segment/ Operations
Performance Obligation
Description
CEV
Renewable energy certificates
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. Revenue is recognized upon generation.
ES
Natural
gas services
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.
S&T
Natural gas services
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.
Revenue
is recognized upon the transfer of the underlying contractual rights.
S&T
Natural gas services
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. Usage fees and hub services revenues are recognized as services are performed.
HSO
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.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
i
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:
(1)Includes
building rent related to the Wall headquarters, which is eliminated in consolidation.
(2)Consists of transactions between subsidiaries that are eliminated in consolidation.
(3)Includes CIP revenue.
(4)Includes SREC revenue.
/
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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)
NJNG
CEV
ES
S&T
HSO
Total
2023
Residential
$
i621,663
i13,668
i—
i—
i57,091
$
i692,422
Commercial
and industrial
i136,011
i30,701
i76,975
i88,700
i342
i332,729
Firm
transportation
i77,722
i—
i—
i—
i—
i77,722
Interruptible,
off-tariff and other
i8,647
i—
i—
i—
i—
i8,647
Revenues
out of scope
i167,241
i79,762
i604,471
i—
i—
i851,474
Total
operating revenues
$
i1,011,284
i124,131
i681,446
i88,700
i57,433
$
i1,962,994
2022
Residential
$
i586,678
i12,579
i—
i—
i55,629
$
i654,886
Commercial
and industrial
i265,970
i31,225
i83,801
i65,286
i189
i446,471
Firm
transportation
i92,531
i—
i—
i—
i—
i92,531
Interruptible,
off-tariff and other
i5,097
i—
i—
i—
i—
i5,097
Revenues
out of scope
i177,141
i84,476
i1,445,377
i—
i—
i1,706,994
Total
operating revenues
$
i1,127,417
i128,280
i1,529,178
i65,286
i55,818
$
i2,905,979
2021
Residential
$
i487,018
i11,319
i—
i—
i50,689
$
i549,026
Commercial
and industrial
i124,519
i18,522
i26,933
i49,252
i755
i219,981
Firm
transportation
i79,256
i—
i—
i—
i—
i79,256
Interruptible,
off-tariff and other
i3,842
i—
i—
i—
i—
i3,842
Revenues
out of scope
i37,161
i65,434
i1,201,913
i—
i—
i1,304,508
Total
operating revenues
$
i731,796
i95,275
i1,228,846
i49,252
i51,444
$
i2,156,613
Customer
Accounts Receivable/Credit Balances and Deposits
i
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:
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)
NJNG
CEV
ES
S&T
HSO
Total
2023
Customer
accounts receivable
Billed
$
i55,234
i9,962
i23,716
i6,577
i2,051
$
i97,540
Unbilled
i10,784
i8,316
i—
i—
i—
i19,100
Customers’
credit balances and deposits
(i44,898)
i—
i—
(i12)
i—
(i44,910)
Total
$
i21,120
i18,278
i23,716
i6,565
i2,051
$
i71,730
2022
Customer
accounts receivable
Billed
$
i78,508
i5,566
i129,199
i7,012
i2,012
$
i222,297
Unbilled
i10,814
i2,955
i—
i—
i—
i13,769
Customers’
credit balances and deposits
(i33,246)
i—
i—
i—
i—
(i33,246)
Total
$
i56,076
i8,521
i129,199
i7,012
i2,012
$
i202,820
/
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New Jersey Resources Corporation
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
i
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 i6.84% and a return on common equity of i9.6%. 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.
/
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New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
ii
Regulatory
assets and liabilities included on the Consolidated Balance Sheets for NJNG are comprised of the following, as of September 30:
(Thousands)
2023
2022
Regulatory assets-current
New Jersey Clean Energy Program
$
i15,804
$
i15,697
Conservation
Incentive Program
i50,356
i23,099
Derivatives
at fair value, net
i6,017
i—
Other current
regulatory assets
i1,410
i1,290
Total
current regulatory assets
$
i73,587
$
i40,086
Regulatory
assets-noncurrent
Environmental remediation costs:
Expended, net of recoveries
$
i66,298
$
i66,149
Liability
for future expenditures
i169,390
i127,070
Deferred
income taxes
i41,667
i40,520
SAVEGREEN
i83,589
i52,690
Postemployment
and other benefit costs
i55,274
i56,021
Deferred
storm damage costs
i—
i2,172
Cost
of removal
i112,362
i104,850
Other
noncurrent regulatory assets
i51,019
i45,828
Total
noncurrent regulatory assets
$
i579,599
$
i495,300
Regulatory
liability-current
Overrecovered natural gas costs
$
i30,637
$
i17,807
Derivatives
at fair value, net
i—
i7,972
Total
current regulatory liabilities
$
i30,637
$
i25,779
Regulatory
liabilities-noncurrent
Tax Act impact (1)
$
i180,347
$
i185,367
Derivatives
at fair value, net
i—
i116
Other
noncurrent regulatory liabilities
i111
i151
Total noncurrent regulatory liabilities
$
i180,458
$
i185,634
(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 $i3.9M
and $i6.9M 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)
2023
2022
Total noncurrent regulatory assets
$
i5,231
$
i5,366
Total
current regulatory liabilities
$
i1,650
$
i5,311
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.
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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 iseven-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 i10-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 iseven-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 iseven-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.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Other Regulatory Assets
Other regulatory
assets consist primarily of deferred costs associated with certain components of NJNG’s SBC, as discussed further in the regulatory proceedings section, and NJNG’s compliance with federal and state-mandated PIM provisions. NJNG’s related costs to maintain the operational integrity of its distribution and transmission main are recoverable, without interest, subject to BPU review and approval.
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 $i79.0M
increase to base rates, effective December 1, 2021. The increase includes an overall rate of return on rate base of i6.84%, return on common equity of i9.6%, a common equity ratio
of i54.0% and a depreciation rate of i2.78%.
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 itwo 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 ifive
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 $i20.6M,
$i19.3M 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 $i2.9M
increase to the annual revenues credited to BGSS and a $i13.0M annual increase related to its balancing charge, as well as changes to CIP rates, which will result in a $i6.3M
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 $i2.9M increase to the annual revenues credited to BGSS and a $i13.0M
annual increase related to its balancing charge, as well as changes to CIP rates, which resulted in a $i6.3M 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 $i24.2M
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 $i81.9M increase to the annual revenues credited to BGSS and a $i9.0M
annual increase related to its balancing charge, as well as a $i10.2M increase to CIP rates, effective October 1, 2022, which was approved on a final basis on April 12, 2023.
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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 $i29.9M, 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 $i32.4M.
•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 $i38.6M decrease to the annual revenues credited to BGSS, a $i7.4M annual decrease related to its
balancing charge and a $i27.5M 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 $i27.0M
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 i10-year period through a tariff rider mechanism. In March 2021, the BPU approved a ithree-year
SAVEGREEN program that included $i126.1M of direct investment, $i109.4M in financing options and $i23.4M
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 $i11.4M,
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 $i2.2M, 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 $i3.5M, 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 $i10.7M. On September 27, 2023, the BPU approved an increase to the EE rate increasing annual recoveries by $i9.0M
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 $i1.3M annually and an increase to the NJCEP factor, which resulted in an annual increase of approximately $i6.0M,
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 $i4.9M.
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 $i0.6M and decrease the NJCEP by $i2.9M,
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 $i1.6M,
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 $i3.8M and an increase to the NJCEP annual recoveries of $i2.2M,
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 $i3.7M and a decrease to the NJCEP annual recoveries of $i0.9M,
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 $i0.7M 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 $i2.4M
and an increase to the NJCEP annual recoveries of $i5.0M, 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 $i130.0M,
exclusive of AFUDC, over a ifour-year period. SAFE II was approved to invest up to $i200.0M, excluding AFUDC, over a ifive-year
period. NJNG recovered approximately $i157.5M 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 isix
capital investment projects estimated to cost $i102.5M over a ifive-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 i6.74% to i6.9% and a return on equity of i9.75%.
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 $i3.4M 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 $i0.3M. 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 ifive-year IIP. The IIP consists of itwo
components, transmission and distribution investments and information technology replacement and enhancements. The total investment for the IIP is approximately $i507.0M. 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 $i150.0M
over ifive 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 $i28.9M
through June 30, 2022. In September 2022, the BPU approved the rate increase resulting in a $i3.2M 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 $i31.4M
through June 30, 2023. This filing was updated on July 28, 2023, with actual expenses of approximately $i28.2M through June 30, 2023. The BPU approved this filing on September 27, 2023, which resulted in a $i3.2M
revenue increase, effective October 1, 2023.
i
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
i
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:
Derivatives
at Fair Value
2023
2022
(Thousands)
Balance Sheet Location
Assets
Liabilities
Assets
Liabilities
Derivatives not designated as hedging instruments:
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.
ii
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.
(1)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.
(2)Includes transactions with NAESB netting election, transactions held by FCMs with net margining and transactions with ISDA netting.
(3)Financial collateral includes cash balances at FCMs, as well as cash received from or pledged to other counterparties.
(4)Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.
//
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)
i
The following table presents the effect of derivative
instruments recognized on the Consolidated Statements of Operations as of September 30:
(Thousands)
Location of gain (loss) recognized in income on derivatives
Amount of gain (loss) recognized in income on derivatives
Derivatives not designated as hedging instruments:
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.
i
The
following table reflects the gains and/or (losses) associated with NJNG’s derivative instruments as of September 30:
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 $ii1.4/M
were reclassified during both fiscal 2023 and 2022.
i
NJNG and ES had the following outstanding long (short) derivatives as of September 30:
Natural
Gas Distribution
Energy Services
Volumes (Bcf)
Futures
Physical Commodity
Futures
Physical Commodity
2023
i32.1
i12.1
(i6.9)
i0.2
2022
i30.5
i6.8
(i0.7)
i2.7
/
Not
included in the above table are i1.3M and i1.2M 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.
i
The balances as of September 30, by reporting segment, are as follows:
(Thousands)
Balance
Sheet Location
2023
2022
NJNG
Restricted broker margin accounts - current assets
$
i5,915
$
i26,138
ES
Restricted
broker margin accounts - current assets
$
i14,881
$
i68,123
Restricted
broker margin accounts - current liabilities
$
i8,029
$
i—
/
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.
i
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)
Gross Credit Exposure
Investment grade
$
i119,229
Noninvestment
grade
i4,775
Internally-rated investment grade
i20,343
Internally-rated
noninvestment grade
i20,153
Total
$
i164,500
/
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 $i0.1M and $i0.2M
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)
i
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.
i
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)
2023
2022
NJNG (2) (3)
Carrying value
$
i1,467,845
$
i1,292,845
Fair
market value
$
i1,097,088
$
i979,388
NJR
(4)
Carrying value
$
i1,120,000
$
i1,070,000
Fair
market value
$
i1,009,448
$
i966,968
(1)See
Note 9. Debt for a reconciliation to long-term and short-term debt.
(2)Excludes the sale leasebacks of natural gas meters of $i31.4M and $i30.3M
as of September 30, 2023 and 2022, respectively. The fair value of certain sale leasebacks of natural gas meters amounted to $i20.9M and $i15.7M as of September
30, 2023 and 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 $i268.1M
and $i124.1M, 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.
i
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)
i
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
Fair Value Technique
Level 1
Unadjusted quoted prices for identical assets or liabilities in active markets
The
Company’s Level 1 assets and liabilities include exchange-traded natural gas futures and options contracts, listed equities and money market funds. Exchange-traded futures and options contracts include all energy contracts traded on the NYMEX, CME and ICE that the Company refers to internally as basis swaps, fixed swaps, futures and financial options that are cleared through an FCM.
Level 2
Other significant observable inputs, such as interest rates or price data, including both commodity and
basis pricing that is observed either directly or indirectly from publications or pricing services
The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management
judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:
•widely accepted and public;
•non-proprietary and sourced from an independent third party; and
•observable
and published.
These additional adjustments are generally not considered to be significant to the ultimate recognized values.
Level 3
Inputs derived from a significant amount of unobservable market data
These include the Company’s best estimate of fair value and are derived primarily through the use of internal valuation methodologies.
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)
i
Assets and liabilities measured at fair value on a recurring basis are summarized as follows:
Quoted
Prices in Active Markets for Identical Assets
The Company holds a i50% 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 $i104.1M
and $i106.6M as of September 30, 2023 and 2022, respectively, which includes loans with a total outstanding principal balance of $ii70.4/M
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 i20% investor in PennEast, a partnership whose purpose was to construct and operate a i120-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 $i92.0M,
or approximately $i74.5M, 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 $i11.0M and reduced the remaining carrying value of its equity method investment in PennEast to izero
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 $i0.3M during fiscal 2023, which is recognized in equity in earnings of affiliates in the Consolidated Statements of Operations.
i
The
following is the summarized financial information for Steckman Ridge and PennEast for fiscal years ended September 30:
(Thousands)
2023
2022
2021
Steckman Ridge
Operating revenues
$
i22,659
$
i19,812
$
i21,847
Gross
profit
$
i13,385
$
i11,349
$
i13,350
Income
from continuing operations
$
i5,769
$
i8,686
$
i11,483
Net
income
$
i5,769
$
i8,686
$
i11,483
Net
income attributable to NJR
$
i2,884
$
i4,343
$
i5,741
Current
assets
$
i12,724
$
i28,609
Noncurrent
assets
$
i193,779
$
i198,052
Current
liabilities
$
i148,577
$
i23,618
Noncurrent
liabilities
$
i—
$
i140,810
PennEast
Operating
revenues
$
i—
$
i—
$
i—
Gross
profit
$
i—
$
i—
$
i—
Loss
from continuing operations
$
(i9,543)
$
(i3,778)
$
(i406,305)
Net
loss
$
(i9,543)
$
(i3,778)
$
(i406,305)
Net
loss attributable to NJR
$
(i1,909)
$
(i756)
$
(i81,261)
Current
assets
$
i1,481
$
i1,801
Noncurrent
assets
$
i—
$
i—
Current
liabilities
$
i127
$
i82
Noncurrent liabilities
$
i—
$
i500
/
i
8. EARNINGS
PER SHARE
i
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)
2023
2022
2021
Net income, as reported
$
i264,724
$
i274,922
$
i117,890
Basic
earnings per share
Weighted average shares of common stock outstanding-basic
i97,028
i96,100
i96,227
Basic
earnings per common share
$i2.73
$i2.86
$i1.23
Diluted
earnings per share
Weighted average shares of common stock outstanding-basic
i97,028
i96,100
i96,227
Incremental
shares (1)
i599
i388
i333
Weighted
average shares of common stock outstanding-diluted
i97,627
i96,488
i96,560
Diluted
earnings per common share
$i2.71
$i2.85
$i1.22
(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)
i
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
i
The
following table presents the long-term debt of the Company as of September 30:
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
i
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)
2024
2025
2026
2027
2028
Thereafter
NJR
$
i—
$
i100,000
$
i100,000
$
i110,000
$
i100,000
$
i710,000
NJNG
$
i70,000
$
i50,000
$
i—
$
i—
$
i50,000
$
i1,297,845
/
NJR
On
October 24, 2022, NJR entered into a Note Purchase Agreement, which closed on December 15, 2022, under which NJR issued $i50M, senior notes at a fixed rate of i6.14%, 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 i30%.
As of September 30, 2023, NJNG’s equity-to-total-capitalization ratio is i54.4% and NJNG has the capacity to issue up to $i1.4B of FMB under the terms of the Mortgage Indenture.
On
October 24, 2022, NJNG entered into a Note Purchase Agreement under which it sold $i125M of its senior notes at an interest rate of i5.47%, maturing in 2052.
On
September 28, 2023, NJNG entered into a Note Purchase Agreement for $i100M aggregate principal amount of its senior notes consisting of $i50M of i5.56%
senior notes due September 28, 2033, which closed on September 28, 2023, and $i50M of i5.85% 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 $i8.4M and $i17.3M
during fiscal 2023 and 2022, respectively, in connection with the sale leaseback of its natural gas meters, with terms ranging from seven to i10 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 $i1.1M
for fiscal 2022. There were ino early purchase options exercised during fiscal 2023.
i
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)
2024
2025
2026
2027
2028
Thereafter
Subtotal
Lease
Payments
$
i9,362
i7,479
i6,407
i4,083
i4,715
i1,676
$
i33,722
Less:
Interest component
(i2,370)
Total
$
i31,352
/
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 i15
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 $i167.8M
and $i24.1M 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.
i
Contractual
commitments for the solar asset financing obligation payments, as of the fiscal years ended September 30, are as follows:
(Thousands)
2024
2025
2026
2027
2028
Thereafter
Subtotal
Lease
Payments
$
i54,033
i50,663
i13,875
i16,385
i26,392
i87,881
$
i249,229
Less:
Interest component
(i42,942)
Total
$
i206,287
/
Credit
Facilities and Short-term Debt
On February 7, 2023, NJR's 364-day $i150M term loan credit agreement, that was entered into in February 2022, expired. The Company had $i50M
that was borrowed on February 9, 2022 and $i100M that was borrowed on February 14, 2022, which was paid in full at expiration of the term loan agreement.
i
The
following table summarizes NJR’s credit facility and NJNG’s commercial paper program and credit facility as of September 30:
At
end of period
(Thousands)
Total borrowing capacity
Loans outstanding
Weighted average interest rate
Remaining borrowing capacity
Expiration dates
2023
NJR
Bank
revolving credit facilities (1)
$
i650,000
$
i217,300
i6.53
%
$
i426,967
(2)
Sep
2027
NJNG
Bank revolving credit facilities (3)
$
i250,000
$
i34,800
i5.48
%
$
i214,469
(4)
Sep
2027
2022
NJR
Bank revolving credit facilities (1)
$
i650,000
$
i200,150
i3.97
%
$
i440,177
(2)
Sep
2027
Bank term loan credit agreement
$
i150,000
$
i150,000
i3.81
%
$
i—
Feb
2023
NJNG
Bank revolving credit facilities (3)
$
i250,000
$
i73,800
i3.34
%
$
i175,469
(4)
Sep
2027
(1)Committed credit facilities, which require commitment fees of i0.10% on the unused amounts.
(2)Letters of credit outstanding total $i5.7M
and $i9.7M as of September 30, 2023 and September 30, 2022, respectively, which reduces amount available by the same amount.
(3)Committed credit facilities, which require commitment fees of i0.075%
on the unused amounts.
(4)Letters of credit outstanding total $ii0.7/M
as of both September 30, 2023 and 2022, which reduces amount available by the same amount.
/
Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit. Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.
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 $i650M NJR Credit Facility with a maturity date of September 2, 2027. The NJR Credit Facility is subject
to a ione-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 $i50M,
with the total revolving credit commitments not exceeding $i750M. The NJR Credit Facility also permits the borrowing of revolving loans and swingline loans, as well as a $i75M
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 iseven letters of credit outstanding
totaling $i5.7M 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 $i250M NJNG Credit Facility with a maturity date of September 2, 2027. The NJNG Credit Facility
is subject to a ione-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 $i50M
up to a maximum of $i100M. The NJNG Credit Facility also permits the borrowing of revolving loans and swingline loans, as well as a $i30M sublimit
for the issuance of letters of credit.
As of September 30, 2023, NJNG has itwo letters of credit outstanding for $i0.7M,
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.
i
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, i2,774,527 shares remain available for future issuance.
i
The
following table summarizes all stock-based compensation expense recognized during the following fiscal years:
(Thousands)
2023
2022
2021
Stock-based compensation expense:
Performance share awards
$
i4,882
$
i4,131
$
i3,856
Restricted
and non-restricted stock
i3,647
i3,189
i3,193
Deferred
retention stock
i6,187
i7,507
i100
Compensation
expense included in operation and maintenance expense
i14,716
i14,827
i7,149
Income
tax benefit (1)
(i3,563)
(i3,624)
(i1,613)
Total,
net of tax
$
i11,153
$
i11,203
$
i5,536
(1)Excludes
additional tax (expense) benefit related to delivered shares of $(i0.6)M, $(i0.1)M and $(i0.2)M
as of September 30, 2023, 2022and 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 i39,614
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 i73,047 performance
shares, of which i42,449 vest on September 30, 2025 and i30,598
vest annually over a ithree-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 i44,965
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 i73,561 performance
shares, of which i44,596 vest on September 30, 2024 and i28,965
vest annually over a ithree-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 i46,813
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 i70,138 performance
shares, of which i44,156 vested in September 30, 2023 and i25,982
vest annually over a ithree-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 $i5.2M
of deferred compensation related to unvested performance shares that is expected to be recognized over the weighted average period of i1.7 years.
i
The
following table summarizes the performance share activity under the stock award and incentive plans for the past three fiscal years:
(1)The
number of common shares issued related to certain performance shares may range from izero to i150% of the number of shares shown in the table above based on the
Company’s achievement of performance goals.
(2)As certified by the Company’s Leadership and Compensation Committee on November 10, 2021, there were ino common shares earned related to TSR performance, the number of common shares earned related to NFE performance was i93%
or i31,116 shares, and the number of common shares earned related to Performance Based Restricted Stock was i100% or i25,982
shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of i100%.
(3)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 i112%
or i30,472 shares, the number of common shares earned related to NFE performance was i105% or i26,282
shares, and the number of common shares earned related to Performance Based Restricted Stock was i100% or i28,965 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of i100%.
(4)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 i150% or i59,192
shares, the number of common shares earned related to NFE performance was i150% or i55,832 shares, and the number of common shares earned related to Performance Based Restricted Stock was i100%
or i30,598 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of i100%.
/
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 i64,080,
i54,826 and i67,726
shares of restricted stock during fiscal 2023, 2022 and 2021, respectively. The shares vest annually over a iiithree-year//
period beginning in October of the fiscal year in which they were granted. There is approximately $i1.4M of deferred compensation related to unvested restricted stock shares that is expected to be recognized over the weighted average period of i1.8
years.
i
The following table summarizes the restricted stock activity under the stock award and incentive plans for the past three fiscal years:
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. iThe following table summarizes the deferred retention stock award under the stock award and incentive
plans for the past three fiscal years:
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.
i
The following summarizes non-employee director share awards for the past three fiscal years:
The Company has itwo trusteed, noncontributory defined benefit retirement plans covering eligible regular represented and non-represented employees with more than ione
year of service. Defined benefit plan benefits are based on years of service and average compensation during the highest i60 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 iinot/
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 $i4.2M
and $i6.1M in fiscal 2023 and 2022, respectively, and estimates that it will contribute between $i5M and $i10M
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)
i
The
following summarizes the changes in the funded status of the plans and the related liabilities recognized on the Consolidated Balance Sheets as of September 30:
Pension (1)
OPEB
(Thousands)
2023
2022
2023
2022
Change
in Benefit Obligation
Benefit obligation at beginning of year
$
i290,823
$
i395,547
$
i173,217
$
i244,674
Service
cost
i5,402
i8,291
i2,471
i4,305
Interest
cost
i15,174
i9,632
i9,146
i6,355
Plan
participants’ contributions (2)
i32
i59
i552
i423
Actuarial
(gain) loss
(i7,057)
(i109,320)
i25,363
(i77,775)
Benefits
paid, net of retiree subsidies received
(i14,053)
(i13,386)
(i7,343)
(i4,765)
Benefit
obligation at end of year
$
i290,321
$
i290,823
$
i203,406
$
i173,217
Change
in plan assets
Fair value of plan assets at beginning of year
$
i284,347
$
i355,284
$
i99,736
$
i114,183
Actual
return (loss) on plan assets
i27,456
(i58,239)
i9,826
(i15,996)
Employer
contributions
i579
i628
i4,192
i6,082
Benefits
paid, net of plan participants’ contributions (2)
(2)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.
i
The following table summarizes the amounts recognized in regulatory assets and accumulated OCI as of September 30:
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:
Regulatory
Assets
Accumulated Other Comprehensive Income (Loss)
Pension
OPEB
Pension
OPEB
(Thousands)
2023
2022
2023
2022
2023
2022
2023
2022
Net
actuarial loss (gain)
$
i24,577
$
i35,157
$
i30,046
$
i20,110
$
i742
$
i5,003
$
i5,498
$
(i6,822)
Prior
service cost
i61
i164
i—
i—
i—
i—
i—
i—
Total
$
i24,638
$
i35,321
$
i30,046
$
i20,110
$
i742
$
i5,003
$
i5,498
$
(i6,822)
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:
Regulatory Assets
Accumulated
Other Comprehensive Income (Loss)
(Thousands)
Pension
OPEB
Pension
OPEB
Net actuarial loss (gain)
$
i815
$
i667
$
(i12)
$
i661
Prior
service cost
i62
i—
i—
i—
Total
$
i877
$
i667
$
(i12)
$
i661
i
The
projected benefit and accumulated benefit obligations and the fair value of plan assets as of September 30, are as follows:
Pension
(Thousands)
2023
2022
Projected benefit obligation
$
i290,321
$
i290,823
Accumulated
benefit obligation
$
i267,794
$
i265,933
Fair
value of plan assets
$
i298,361
$
i284,347
/
i
The
components of the net periodic cost for pension benefits, including the Company’s PEP, and OPEB costs (principally health care and life insurance) for employees and covered dependents for fiscal years ended September 30, are as follows:
Pension
OPEB
(Thousands)
2023
2022
2021
2023
2022
2021
Service
cost
$
i5,402
$
i8,291
$
i8,730
$
i2,471
$
i4,305
$
i4,844
Interest
cost
i15,174
i9,632
i9,112
i9,146
i6,355
i6,071
Expected
return on plan assets
(i19,972)
(i21,275)
(i20,150)
(i6,721)
(i7,575)
(i6,497)
Recognized
actuarial loss
i300
i8,745
i11,446
i—
i5,684
i7,909
Prior
service cost (credit) amortization
i103
i101
i102
i—
(i144)
(i179)
Net
periodic benefit cost recognized as expense
$
i1,007
$
i5,494
$
i9,240
$
i4,896
$
i8,625
$
i12,148
/
Assumptions
i
The
weighted average assumptions used to determine the Company’s benefit costs during the fiscal years below and obligations as of September 30, are as follows:
Pension
OPEB
2023
2022
2021
2023
2022
2021
Benefit
costs:
Discount rate
i5.50/i5.50%
(1)
i3.10/i3.07%
(1)
i2.95/i2.92%
(1)
i5.51/i5.51%
(1)
i3.24/i3.17%
(1)
i3.08/i3.03%
(1)
Expected
asset return
i7.00
%
i6.75
%
i6.75
%
i7.00
%
i6.75
%
i6.75
%
Compensation
increase
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
Obligations:
Discount
rate
i5.89/i5.87%
(1)
i5.50/i5.50%
(1)
i3.10/i3.07%
(1)
i5.97/i5.94%
(1)
i5.51/i5.51%
(1)
i3.24/i3.17%
(1)
Compensation
increase
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(1)
i3.00/i3.50%
(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.
i
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)
2023
2022
2021
HCCTR
i7.4%
i6.6%
i6.9%
Ultimate
HCCTR
i4.5%
i4.5%
i4.5%
Year
ultimate HCCTR reached
2032
2027
2027
Effect of a 1 percentage point increase in the HCCTR on:
Year-end benefit obligation
$
i30,818
$
i26,710
$
i43,217
Total
service and interest cost
$
i2,117
$
i2,544
$
i2,959
Effect
of a 1 percentage point decrease in the HCCTR on:
Year-end benefit obligation
$
(i25,283)
$
(i21,853)
$
(i34,669)
Total
service and interest costs
$
(i1,700)
$
(i1,966)
$
(i2,253)
/
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.
i
The mix and targeted allocation of the pension and OPEB plans’ assets are as follows:
2024
Assets
at
Target
September 30,
Asset Allocation
Allocation
2023
2022
U.S. equity securities
i34
%
i34
%
i32
%
International
equity securities
i17
i16
i16
Fixed
income
i33
i31
i32
Collective
investment trusts at NAV
i16
i19
i20
Total
i100
%
i100
%
i100
%
/
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.
i
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following fiscal years:
(Thousands)
2024
2025
2026
2027
2028
2029
- 2033
Pension
$
i15,227
$
i16,233
$
i17,255
$
i18,246
$
i19,219
$
i110,341
OPEB
$
i6,925
$
i7,602
$
i8,481
$
i9,337
$
i10,211
$
i63,780
/
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
OPEB
(Thousands)
Quoted Prices in Active Markets for Identical Assets (Level 1)
Total
Quoted Prices in Active
Markets for Identical Assets (Level 1)
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. iThe following is a description of the valuation methodologies used for assets measured at fair value:
Asset
Types
Description of the Valuation Methodologies
Money Market funds
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 reported on the active market on which the individual securities are traded.
Collective investment trusts
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 i85% of participants’ contributions up to i6%
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 i3.5% and i4.5%
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 $i5.9M in fiscal 2023, $i5.5M in fiscal
2022 and $i5.1M in fiscal 2021. The amount contributed for the employer special contribution of the Savings Plan was $i2.1M in fiscal 2023, $i2.4M
in fiscal 2022 and $i2.1M in fiscal 2021.
i
12. INCOME
TAXES
i
The income tax provision from operations for the fiscal years ended September 30, consists of the following:
(Thousands)
2023
2022
2021
Current:
Federal
$
i13,393
$
i4,238
$
i651
State
i7,716
i2,104
i1,703
Deferred:
Federal
i36,825
i55,968
i25,030
State
(i8,381)
i14,185
i6,224
Investment/production
tax credits
(i278)
(i300)
(i322)
Income
tax provision
$
i49,275
$
i76,195
$
i33,286
/
i
As
of September 30, the temporary differences, which give rise to deferred tax assets (liabilities), consist of the following:
(Thousands)
2023
2022
Deferred tax assets
Investment tax credits (1)
$
i191,948
$
i212,506
State
net operating losses
i39,612
i36,950
Deferred
revenue
i8,205
i—
Fair
value of derivatives
i5,386
i6,506
Impairment
of equity method investment
i14,004
i14,124
Postemployment
benefits
i6,502
i2,751
Incentive
compensation
i8,949
i7,297
Amortization
of intangibles
i6,308
i6,474
Overrecovered
natural gas costs
i8,564
i4,977
Allowance
for doubtful accounts
i4,485
i5,761
Other
i7,636
i5,748
Total
deferred tax assets
i301,599
i303,094
Less:
Valuation allowance
(i5,747)
(i22,241)
Total
deferred tax assets net of valuation allowance
$
i295,852
$
i280,853
Deferred
tax liabilities
Property-related items
$
(i487,294)
$
(i468,115)
Remediation
costs
(i18,532)
(i18,490)
Investments
in equity investees
(i28,325)
(i19,176)
Conservation
incentive program
(i14,075)
(i6,457)
Other
(i4,670)
(i4,615)
Total
deferred tax liabilities
$
(i552,896)
$
(i516,853)
Total
net deferred tax liabilities
$
(i257,044)
$
(i236,000)
(1)Includes
approximately $ii0.7/M 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)
i
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)
2023
2022
2021
Statutory
income tax expense
$
i65,940
$
i73,735
$
i31,747
Change
resulting from:
Investment/production tax credits
(i278)
(i300)
(i322)
Cost
of removal of assets placed in service prior to 1981
(i4,758)
(i3,533)
(i5,366)
AFUDC
equity
(i1,499)
(i2,361)
(i786)
State
income taxes, net of federal benefit
i13,293
i13,072
i6,124
Valuation
allowance
(i16,494)
(i1,372)
i5,974
Tax
Act - utility excess deferred income taxes amortized
(i3,573)
(i3,573)
(i3,573)
Other
(i3,356)
i527
(i512)
Income
tax provision
$
i49,275
$
i76,195
$
i33,286
Effective
income tax rate
i15.7
%
i21.7
%
i22.0
%
/
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 $i5.1M
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 $i2.7M. The second installment payment was made during the first quarter of fiscal 2023, which reduced the balance to izero
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 $i191.2M and $i211.8M,
respectively, which each have a life of i20 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 $i56.6M,
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 $i5.0M
and $i5.1M, 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.
iThe reserve for uncertain tax benefits is as follows:
(Thousands)
2023
2022
Balance at October 1,
$
i—
$
i—
Additions
based on tax positions related to the current fiscal period
i4,978
i—
Balance
at September 30,
$
i4,978
$
i—
As
of September 30, 2023, there are $i5.0M 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 $i631.2M and $i544.4M, 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 i20 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 $i17.2M
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 $i15.8M 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 $i0.7M 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 i26% for property under construction before the end of 2020. The Consolidated Appropriations Act of 2021 extended the ii26/%
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)
ii
13. LEASES
i
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 i20 and i50 years and may include multiple options to extend the terms for an additional five to i20
years. The Company’s office leases vary in duration, ranging from two to i17 years, and may or may not include extension or early purchase options. The Company’s meter lease terms are between seven and i10
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 ieight years. The Company’s storage and capacity leases have assumed terms of i50 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 i16-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)
i
The following table presents the Company’s lease costs included in the Consolidated Statements of Operations for the fiscal year ended September 30:
(Thousands)
Income
Statement Location
2023
2022
2021
Operating lease cost (1)
Operation and maintenance
$
i9,336
$
i9,702
$
i8,182
Finance
lease cost
Amortization of right-of-use assets
Depreciation and amortization
i2,105
i1,769
$
i3,442
Interest
on lease liabilities
Interest expense, net of capitalized interest
i1,084
i612
i710
Total
finance lease cost
$
i3,189
$
i2,381
i4,152
Short-term
lease cost
Operation and maintenance
i—
i34
i543
Variable
lease cost
Operation and maintenance
i1,128
i781
i1,381
Total
lease cost
$
i13,653
$
i12,898
$
i14,258
(1)Net
of capitalized costs.
The following table presents supplemental cash flow information related to leases for the fiscal year ended September 30:
(Thousands)
2023
2022
2021
Cash paid for amounts included in the measurement of lease liabilities
Operating
cash flows for operating leases
$
i8,942
$
i7,417
$
i6,675
Operating
cash flows for finance leases
$
i1,084
$
i831
$
i1,167
Financing
cash flows for finance leases
$
i7,379
$
i7,145
$
i8,180
/
Assets
obtained or modified for operating lease liabilities totaled approximately $i13.2M and $i0.9M 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 $i8.4M and $i17.3M
during fiscal 2023 and 2022, respectively.
i
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)
Balance
Sheet Location
2023
2022
Assets
Noncurrent
Operating lease assets
Operating lease assets
$
i175,740
$
i168,520
Finance
lease assets
Utility plant
i28,248
i21,913
Total
lease assets
$
i203,988
$
i190,433
Liabilities
Current
Operating
lease liabilities
Operating lease liabilities
$
i4,772
$
i4,562
Finance
lease liabilities
Current maturities of long-term debt
i8,477
i6,538
Noncurrent
Operating
lease liabilities
Operating lease liabilities
i148,023
i138,382
Finance
lease liabilities
Long-term debt
i22,875
i23,752
Total
lease liabilities
$
i184,147
$
i173,234
/
For
operating lease assets and liabilities, the weighted average remaining lease term was ii29.2/ years for both September
30, 2023 and 2022, and the weighted average discount rate used in the valuation over the remaining lease term was i3.5% and i3.2% 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 i3.3 years and i4.0
years, respectively, and the weighted average discount rate used in the valuation over the remaining lease term was ii2.7/% as of both September
30, 2023 and 2022.
Page 118
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 $i198.3M
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 i10
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.
i
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)
2024
2025
2026
2027
2028
Thereafter
ES:
Natural
gas purchases
$
i66,525
$
i2,498
$
i—
$
i—
$
i—
$
i—
Storage
demand fees
i16,944
i8,099
i6,010
i4,878
i3,505
i6,780
Pipeline
demand fees
i43,755
i43,271
i31,749
i24,234
i13,719
i14,457
Sub-total
ES
$
i127,224
$
i53,868
$
i37,759
$
i29,112
$
i17,224
$
i21,237
NJNG:
Natural
gas purchases
$
i23,952
$
i—
$
i—
$
i—
$
i—
$
i—
Storage
demand fees
i42,469
i30,673
i14,975
i10,163
i5,084
i—
Pipeline
demand fees
i155,875
i155,559
i134,555
i128,651
i113,998
i966,963
Sub-total
NJNG
$
i222,296
$
i186,232
$
i149,530
$
i138,814
$
i119,082
$
i966,963
Total
$
i349,520
$
i240,100
$
i187,289
$
i167,926
$
i136,306
$
i988,200
/
Certain
pipeline demand fees totaling approximately $i4.0M 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 $i7.9M annually for the next five years and $i213.9M
in the aggregate for all years thereafter.
Guarantees
As of September 30, 2023, there were NJR guarantees covering approximately $i192.3M 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 $i137.3M
to $i201.5M. 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 $i169.4M 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 iseven-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 $i11.1M to $i11.7M,
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 $i3.7M, which increased the pre-tax annual recovery to $i15.4M,
effective May 1, 2023. As of September 30, 2023, $i66.3M 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)
i
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. iInformation
related to the Company’s various reporting segments and other business operations, as of September 30, is detailed below:
Segments
(Thousands)
NJNG
CEV
ES
S&T
Subtotal
HSO
Elims
Total
2023
Operating
revenues
External customers
$
i1,011,284
i124,131
i681,446
(1)
i88,700
$
i1,905,561
i57,433
—
$
i1,962,994
Intercompany
$
i1,349
i—
i10,170
i4,159
$
i15,678
i205
(i15,883)
$
—
Depreciation
and amortization
$
i102,326
i25,320
i221
(2)
i24,185
$
i152,052
i889
i—
$
i152,941
Interest
income (3)
$
i1,713
i—
i1,119
i6,957
$
i9,789
i2,977
(i3,847)
$
i8,919
Interest
expense, net of capitalized interest
$
i56,595
i28,569
i11,400
i25,803
$
i122,367
i647
i—
$
i123,014
Income
tax provision (benefit)
$
i33,065
(i7,683)
i24,343
i3,444
$
i53,169
(i1,477)
(i2,417)
$
i49,275
Equity
in earnings of affiliates
$
i—
i—
i—
i3,126
$
i3,126
i—
i804
$
i3,930
Net
financial earnings
$
i131,414
i44,458
i68,517
i12,835
$
i257,224
i4,758
(i155)
$
i261,827
Capital
expenditures
$
i390,394
i107,303
i—
i40,916
$
i538,613
i2,306
i—
$
i540,919
2022
Operating
revenues
External customers
$
i1,127,417
i128,280
i1,529,178
(1)
i65,286
$
i2,850,161
i55,818
—
$
i2,905,979
Intercompany
$
i1,350
i—
i94
i2,449
$
i3,893
i364
(i4,257)
$
—
Depreciation
and amortization
$
i94,579
i21,396
i148
(2)
i12,302
$
i128,425
i824
i—
$
i129,249
Interest
income (3)
$
i895
i—
i16
i2,110
$
i3,021
i944
(i1,249)
$
i2,716
Interest
expense, net of capitalized interest
$
i46,394
i21,968
i4,725
i12,097
$
i85,184
i646
i—
$
i85,830
Income
tax provision
$
i40,141
i11,361
i21,776
i1,879
$
i75,157
i1,059
(i21)
$
i76,195
Equity
in earnings of affiliates
$
i—
i—
i—
i9,865
$
i9,865
i—
(i1,688)
$
i8,177
Net
financial earnings (loss)
$
i140,124
i39,403
i39,121
i22,454
$
i241,102
(i781)
i—
$
i240,321
Capital
expenditures
$
i298,374
i146,676
i—
i151,988
$
i597,038
i1,390
i—
$
i598,428
Return
of capital from equity investees
$
i—
i—
i—
(i5,479)
$
(i5,479)
i—
i—
$
(i5,479)
2021
Operating
revenues
External customers
$
i731,796
i95,275
i1,228,846
(1)
i49,252
$
i2,105,169
i51,444
—
$
i2,156,613
Intercompany
$
i—
i—
(i426)
i1,768
$
i1,342
i785
(i2,127)
$
—
Depreciation
and amortization
$
i80,045
i20,567
i111
(2)
i9,960
$
i110,683
i980
(i276)
$
i111,387
Interest
income (3)
$
i85
i241
i11
i2,243
$
i2,580
i522
(i935)
$
i2,167
Interest
expense, net of capitalized interest
$
i36,405
i22,548
i2,204
i13,348
$
i74,505
i4,054
i—
$
i78,559
Income
tax provision (benefit)
$
i19,054
i5,048
i18,371
(i10,043)
$
i32,430
(i196)
i1,052
$
i33,286
Equity
in loss of affiliates
$
i—
i—
i—
(i81,072)
$
(i81,072)
i—
(i2,140)
$
(i83,212)
Net
financial earnings (loss)
$
i107,375
i16,789
i71,117
i13,046
$
i208,327
(i826)
i211
$
i207,712
Capital
expenditures
$
i426,628
i87,852
i—
i107,500
$
i621,980
i2,630
i—
$
i624,610
Investments
in equity investees
$
i—
i—
i—
i690
$
i690
i—
i—
$
i690
(1)Includes
sales to Canada for ES, which are $i8.4M, $i2.4M and $i0.1M
in the fiscal years ended September 30, 2023, 2022 and 2021, respectively.
(2)The amortization of acquired wholesale energy contracts is excluded above and is included in natural gas purchases - nonutility on the Consolidated Statements of Operations.
(3)Included in other income, net on the Consolidated Statements of Operations.
/
Page 121
New
Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
i
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
(Thousands)
NJNG
CEV
ES
S&T
Subtotal
HSO
Assets
(1)
Total
2023
$
i4,414,829
i1,128,577
i123,775
i1,011,959
$
i6,679,140
i171,275
(i312,919)
$
i6,537,496
2022
$
i4,030,686
i1,015,065
i333,064
i999,520
$
i6,378,335
i159,068
(i275,987)
$
i6,261,416
2021
$
i3,707,461
i914,788
i365,423
i862,407
$
i5,850,079
i162,134
(i289,935)
$
i5,722,278
(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. iA
reconciliation of consolidated NFE to consolidated net income, as of September 30, is as follows:
(Thousands)
2023
2022
2021
Net financial earnings
$
i261,827
$
i240,321
$
i207,712
Less:
Unrealized
(gain) loss on derivative instruments and related transactions
(i38,081)
(i59,906)
i54,203
Tax
effect
i9,050
i14,248
(i12,887)
Effects
of economic hedging related to natural gas inventory
i34,699
i19,939
(i42,405)
Tax
effect
(i8,246)
(i4,738)
i10,078
(Gain
on) impairment of equity method investment
(i300)
(i5,521)
i92,000
Tax
effect
(i19)
i1,377
(i11,167)
Net
income
$
i264,724
$
i274,922
$
i117,890
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)
i
16. RELATED PARTY TRANSACTIONS
Effective April 1, 2020, NJNG entered into a i5-year agreement for i3
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 $i9.3M 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.
i
Demand fees, net of eliminations, associated with Steckman Ridge during the fiscal years ended September 30, were as follows:
(Thousands)
2023
2022
2021
NJNG
$
i6,549
$
i6,663
$
i6,449
ES
i657
i732
i564
Total
$
i7,206
$
i7,395
$
i7,013
The
following table summarizes demand fees payable to Steckman Ridge as of September 30:
(Thousands)
2023
2022
NJNG
$
i775
$
i775
ES
i84
i76
Total
$
i859
$
i851
/
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 ione AMA with an expiration date of March 31, 2024.
NJNG entered into a i5-year
transportation agreement with Adelphia for committed capacity of i130,000 Dths per day in Zone South, which began on August 9, 2022.
ES has a i5-year
agreement for i3 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 i15-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 i16-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 i20-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
i15-year transportation agreement with Adelphia for committed capacity of i130,000 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
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 Companyiiadopted/
or iiterminated/ 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 Officersand 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 Jersey07719. 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.
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.
$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)
10.37*
$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)
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)}
104+
Cover Page Interactive Data File included in Exhibit 101
* 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
New Jersey Resources Corporation
Part IV
SIGNATURES
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.
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:
