UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10‑K
x ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended September 30, 2018
OR
FOR THE FISCAL YEAR ENDED SEPTEMBER 30, 2017
OR
o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
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FOR THE TRANSITION PERIOD FROM TO |
| Commission file number 001‑08359 |
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| NEW JERSEY RESOURCES CORPORATION |
| (Exact name of registrant as specified in its charter) |
| New Jersey | | 22‑2376465 |
(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification Number) |
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| 1415 Wyckoff Road, Wall, New Jersey 07719 | | 732‑938‑14801000 |
(Address of principal executive offices) | | (Registrant’s telephone number,
including area code) |
| Securities registered pursuant to Section 12 (b) of the Act: |
| Common Stock ‑ $2.50 Par Value | | New York Stock Exchange |
| (Title of each class) | | (Name of each exchange on which registered) |
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.
Yes:x x No:Yes oNo
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:o oNo:Yes xNo
Indicate by check mark whether the Registrantregistrant (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 Registrantregistrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yes: x No:Yes oNo
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).
Yes:x x No:Yes oNo
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S‑KK(§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of the Registrant’sregistrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. x
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging“emerging growth company"company” in Rule 12b‑2 of the Exchange Act.
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Large accelerated filer:x | | | Accelerated filer:o |
Non-accelerated filer: o | | | Non-accelerated filer:Smaller reporting company: o
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| | | | (Do not check if a smaller reporting company) |
Smaller reporting company:Emerging growth company: o
| Emerging growth company: o
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If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yes: o No:Yes xNo
The aggregate market value of the Registrant’s Common Stockregistrant’s common stock held by non-affiliates was $3,356,717,008$3,451,945,383 based on the closing price of $39.60$40.10 per share on March 31, 2017,2018, as reported on the New York Stock Exchange.
The number of shares outstanding of $2.50 par value Common Stockcommon stock as of November 17, 201716, 2018 was 86,866,461.88,505,199.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Registrant’sregistrant’s definitive Proxy Statement for the Annual Meeting of Shareowners (Proxy Statement) to be held on January 24, 2018,23, 2019, are incorporated by reference into Part I and Part III of this report.
New Jersey Resources Corporation
TABLE OF CONTENTS
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| PART I | |
| | ITEM 1. | | |
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| | ITEM 1A. | | |
| | ITEM 1B. | | |
| | ITEM 2. | | |
| | ITEM 3. | | |
| | ITEM 4. | | |
| | ITEM 4A. | | |
| PART II | |
| | ITEM 5. | | |
| | ITEM 6. | | |
| | ITEM 7. | | |
| | ITEM 7A. | | |
| | ITEM 8. | | |
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| | ITEM 9. | | |
| | ITEM 9A. | | |
| | ITEM 9B. | | |
| PART III* | |
| | ITEM 10. | | |
| | ITEM 11. | | |
| | ITEM 12. | | |
| | ITEM 13. | | |
| | ITEM 14. | | |
| PART IV | |
| | ITEM 15. | | |
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| * Portions of Item 10 and Items 11-14 are Incorporated by Reference from the Proxy Statement. |
New Jersey Resources Corporation
GLOSSARY OF KEY TERMS ��
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| Adelphia | Adelphia Gateway, LLC |
| AFUDC | Allowance for Funds Used During Construction |
AOCI | Accumulated Other Comprehensive Income |
| ARO | Asset Retirement Obligations |
| ASC | Accounting Standards Codification |
| ASU | Accounting Standards Update |
| Bcf | Billion Cubic Feet |
| BGSS | Basic Gas Supply Service |
| BPU | New Jersey Board of Public Utilities |
| CIP | Conservation Incentive Program |
| CME | Chicago Mercantile Exchange |
| CR&R | Commercial Realty & Resources Corp. |
Degree-DayDegree-day | The measure of the variation in the weather based on the extent to which the average daily temperature falls below 65 degrees Fahrenheit |
| DM | Dominion Energy Midstream Partners, L.P., a master limited partnership |
| DM Common Units | Common units representing limited partnership interests in DM |
Dodd-Frank Act | Dodd-Frank Wall Street Reform and Consumer Protection Act |
| DRP | NJR Direct Stock Purchase and Dividend Reinvestment Plan |
| Dths | Dekatherms |
| EDA | New Jersey Economic Development Authority |
| EDA Bonds | Collectively, Series 2011A, Series 2011B and Series 2011C Bonds issued to NJNG by the EDA |
| EDECA | Electric Discount and Energy Competition Act |
| EE | Energy Efficiency |
| FASB | Financial Accounting Standards Board |
| FCM | Futures Commission Merchant |
| FERC | Federal Energy Regulatory Commission |
| Financial Margin | A non-GAAP financial measure, which represents revenues earned from the sale of natural gas less costs of natural gas sold including any transportation and storage costs, and excludes any accounting impact from the change in the fair value of certain derivative instruments |
| FMB | First Mortgage Bonds |
FRM | Financial Risk Management |
| GAAP | Generally Accepted Accounting Principles of the United States |
| HCCTR | Health Care Cost Trend Rate |
| Home Services and Other | Home Services and Other Operations (formerly Retail and Other Operations) |
| ICE | Intercontinental Exchange |
| IEC | Interstate Energy Company, LLC |
| Iroquois | Iroquois Gas Transmission L.P. |
| IRS | Internal Revenue Service |
| ISDA | The International Swaps and Derivatives Association |
| ITC | Investment Tax Credit |
| LIBOR | London Inter-Bank Offered Rate |
| LNG | Liquefied Natural Gas |
| Loan Agreement | Loan Agreement between the EDA and NJNG |
MetLife | Metropolitan Life Insurance Company |
MetLife Facility | NJR’s unsecured, uncommitted $100 million private placement shelf note agreement with MetLife, Inc., which expired in September 2016 |
| MGP | Manufactured Gas Plant |
| MLP | Master limited partnershipLimited Partnership |
| MMBtu | Million British Thermal Units |
| Moody’s | Moody’s Investors Service, Inc. |
| Mortgage Indenture | The Amended and Restated Indenture of Mortgage, Deed of Trust and Security Agreement between NJNG and U.S. Bank National Association dated as of September 1, 2014 |
| MW | Megawatts |
| MWh | Megawatt Hour |
| NAESB | The North American Energy Standards Board |
| NFE | Net Financial Earnings |
NGV | Natural Gas Vehicles |
New Jersey Resources Corporation
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GLOSSARY OF KEY TERMS (cont.) |
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| 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 Natural Gas Distribution segment |
| NJNG Credit Facility | The $250 million unsecured committed credit facility expiring in May 2019 |
| NJR Credit Facility | NJR’sThe $425 million unsecured committed credit facility expiring in September 2020 |
NJR Energy | NJR Energy Corporation |
NJR or The Company | New Jersey Resources Corporation |
New Jersey Resources Corporation
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| GLOSSARY OF KEY TERMS (cont.) |
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| NJRCEV | NJR Clean Energy Ventures Corporation |
| NJRES | NJR Energy Services Company |
| NJRHS | NJR Home Services Company |
NJRPS | NJR Plumbing Services, Inc. |
| NJRRS | NJR Retail Services Company |
NJR Retail Holdings | NJR Retail Holdings Corporation |
| Non-GAAP | Not in accordance with Generally Accepted Accounting Principles of the United States |
| NPNS | Normal Purchase/Normal Sale |
| NYMEX | New York Mercantile Exchange |
| O&M | Operation and Maintenance |
OCI | Other Comprehensive Income |
| OPEB | Other Postemployment Benefit Plans |
| PBO | Projected Benefit Obligation |
| PennEast | PennEast Pipeline Company, LLC |
| PEP | Pension Equalization Plan |
| PIM | Pipeline Integrity Management |
| PPA | Power Purchase Agreement |
| Prudential | Prudential Investment Management, Inc. |
Prudential Facility | NJR’s unsecured, uncommitted private placement shelf note agreement with Prudential Investment Management, Inc. |
| PTC | Production Tax Credit |
| RAC | Remediation Adjustment Clause |
| REC | Renewable Energy Certificate |
| S&P | Standard & Poor’s Financial Services, LLC |
| SAFE I | Safety Acceleration and Facility Enhancement Program, Phase I |
| SAFE II | 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 |
| SREC | Solar Renewable Energy Certificate |
| SRL | Southern Reliability Link |
| Steckman Ridge | Collectively, Steckman Ridge GP, LLC and Steckman Ridge, LP |
| Superstorm Sandy | Post-Tropical Cyclone Sandy |
| Talen | Talen Energy Marketing, LLC or Talen Generation, LLC |
| Tetco | Texas Eastern Transmission |
| The Exchange Act | The Securities Exchange Act of 1934, as amended |
| The Tax Act | An Act to Provide for Reconciliation Pursuant to Titles II and V of the Concurrent Resolution on the Budget for Fiscal Year 2018, previously known as The Tax Cuts and Jobs Act of 2017 |
| 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 |
New Jersey Resources Corporation
TABLE OF CONTENTS
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 Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995. Forward-looking statements can also be identified by the use of forward-looking terminology such as “anticipate,” “estimate,” “may,” “could,” “might,” “intend,” “expect,” “believe,” “will” “plan” or “should” or comparable terminology and are made based upon management’s current expectations, assumptions and beliefs as of this date concerning future developments and their potential effect on us. There can be no assurance that future developments will be in accordance with management’s expectations, assumptions or beliefs, or that the effect of future developments on us will be those anticipated by management.
We caution readers that the expectations, assumptions and beliefs that form the basis for forward-looking statements regarding customer growth, customer usage, qualifications for ITCs PTCs and SRECs, 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 20182019 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:
risks associated with our investments in clean energy projects, including the availability of regulatory incentives and federal tax incentives,credits, the availability of viable projects, our eligibility for ITCs, and PTCs, the future market for SRECs and electricity prices, and operational risks related to projects in service;
our ability to obtain governmental and regulatory approvals, land-use rights, electric grid connection (in the case of clean energy projects) and/or financing for the construction, development and operation of our unregulated energy investments, pipeline transportation systems and NJNG’s and Midstream infrastructure projects, including NJ RISE, SRL, PennEast and Adelphia, in a timely manner;
risks associated with acquisitions and the related integration of acquired assets with our current operations;operations, including our planned Adelphia acquisition;
volatility of natural gas and other commodity prices and their impact on NJNG customer usage, NJNG’s BGSS incentive programs, our Energy Services segment operations and on our risk management efforts;
our ability to comply with current and future regulatory requirements;
the level and rate at which NJNG’s costs and expenses are incurred and the extent to which they are approved for recovery from customers through the regulatory process, including through future base rate case filings;
the impact of a disallowance of recovery of environmental-related expenditures and other regulatory changes;
the performance of our subsidiaries;
operating risks incidental to handling, storing, transporting and providing customers with natural gas;
access to adequate supplies of natural gas and dependence on third-party storage and transportation facilities for natural gas supply;
the regulatory and pricing policies of federal and state regulatory agencies;
timing of qualifying for ITCs and PTCs due to delays or failures to complete planned solar and wind energy projects and the resulting effect on our effective tax rate and earnings;
the results of legal or administrative proceedings with respect to claims, rates, environmental issues, gas cost prudence reviews and other matters;
risks related to cyberattacks or failure of information technology systems;
changes in rating agency requirements and/or credit ratings and their effect on availability and cost of capital to our Company;
our abilityrisks related to comply with current and future regulatory requirements;cyberattacks or failure of information technology systems;
the impact of volatility in the equity and credit markets on our access to capital;
the impact to the asset values and resulting higher costs and funding obligations of our pension and postemployment benefit plans as a result of potential downturns in the financial markets, lower discount rates, revised actuarial assumptions or impacts associated with the Patient Protection and Affordable Care Act;Protection;
commercial and wholesale credit risks, including the availability of creditworthy customers and counterparties, and liquidity in the wholesale energy trading market;
accounting effects and other risks associated with hedging activities and use of derivatives contracts;
our ability to optimize our physical assets;
weather and economic conditions;
changes to tax laws and regulations;
any potential need to record a valuation allowance for our deferred tax assets;
changes to tax laws and regulations;
weather and economic conditions;
our ability to comply with debt covenants;
demographic changes in NJRour’s service territory and their effect on NJR’sour customer growth;
the impact of natural disasters, terrorist activities and other extreme events on our operations and customers;
the costs of compliance with present and future environmental laws, including potential climate change-related legislation;
environmental-related and other uncertainties related to litigation or administrative proceedings;
risks related to our employee workforce; and
risks associated with the management of our joint ventures and partnerships, and investment in a master limited partnership.
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.
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS
ORGANIZATIONAL STRUCTURE
New Jersey Resources Corporation is a New Jersey corporation formed in 1981 pursuant to a corporate reorganization. We are an energy services holding company whose principal business is the distribution of natural gas through a regulated utility, providing other retail and wholesale energy services to customers and investing in clean energy projects and midstream assets. We are an exempt holding company under section 1263 of the Energy Policy Act of 2005.
Our primary subsidiaries include:
New Jersey Natural Gas Company provides regulated retail natural gas service to approximately 529,800538,700 residential and commercial customers in central and northern New Jersey and participates in the off-system sales and capacity release markets. NJNG, a local natural gas distribution company, is regulated by the BPU and comprises the Company’s Natural Gas Distribution segment and is referred to herein as NJNG or Natural Gas Distribution.
NJR Clean Energy Ventures Corporation includes the results of operations and assets related to the Company’s unregulated capital investments in clean energy projects, including commercial and residential solar projects and onshore wind investments. NJRCEV comprises the Company’s Clean Energy Ventures segment and is referred to herein as Clean Energy Ventures.
NJR Energy Services Company maintains and transacts around a portfolio of physical assets consisting of natural gas storage and transportation contracts in the U.S. and Canada. NJRES also provides unregulated wholesale energy management services to other energy companies and natural gas producers.
NJRES comprises our Energy Services segment and is referred to herein as Energy Services. NJR Retail Services Companyprovidesprovided unregulated retail natural gas supply and transportation services to commercial and industrial customers in Delaware, Maryland, Pennsylvania and New Jersey from July 2017 through February 2018. NJRRS was sold to an unrelated third party on February 28, 2018.
NJRES, and NJRRS comprisewas included as part of our Energy Services segment for fiscal 2018 and are referred to herein as Energy Services.2017.
NJR Energy Investments Corporation is an unregulated affiliate that consolidates our unregulated energy-related investments.
NJR Midstream Holdings Corporation,which comprises the Midstream segment, invests in energy-related ventures through its subsidiaries,subsidiaries. Investments include NJR Steckman Ridge Storage Company, which holds the Company’sour 50 percent combinedownership interest in Steckman Ridge, a natural gas storage facility, located in Pennsylvania; NJNR Pipeline, which holds our DM Common Units; and NJR Pipeline Company, which holds the Company’sincludes Adelphia Gateway, LLC and our 20 percent ownership interest in PennEast and NJNR Pipeline Company, which holds approximately 1.84 million DM Common Units. See Note 6. Investments in Dominion Midstream Partners, L.P. The investments inEquity Investees Steckman Ridge, PennEast and DM comprise the Company’s Midstream segment.for more information.
NJR Retail Holdings Corporation is an unregulated affiliate that consolidates our unregulated retail operations.
NJR Home Services Company provides heating, ventilation and cooling service, sales and installation of appliances to approximately 112,000110,000 service contract customers, as well as solar installation projects.projects, and is the primary contributor to Home Services and Other operations.
Commercial Realty & Resources Corp., holds commercial real estate.
NJR Plumbing Services, Inc. provides plumbing repair and installation services.
NJR Service Corporation provides shared administrative services, including corporate communications, finance and accounting, internal audit, legal, human resources and information technology for NJR and all of its subsidiaries.
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 Midstream.
The Natural Gas Distribution segment consists of regulated natural gas services, off-system sales, capacity and storage management operations. The Energy Services segment consists of unregulated wholesale and retail energy operations. The Clean Energy Ventures segment consists of capital investments in clean energy projects. The Midstream segment consists of investments in the midstream natural gas market, such as natural gas transportation and storage facilities.
Net income by reporting segment and other business operations for the years ended September 30, are as follows:
* Energy Services’ net income for fiscal 2017 was $476,000 and does not show clearly in the above graph.
Assets composition by reporting segment and other business operations at September 30, are as follows ($ in Thousands):follows:
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
Management uses NFE, a non-GAAP financial measure, when evaluating our operating results. NFE is a measure of the earnings based on eliminating timing differences surrounding the recognition of certain gains or losses to effectively match the earnings effects of the economic hedges with the physical sale of gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. Energy Services economically hedges its natural gas inventory with financial derivative instruments and calculates the related tax effect based on the statutory rate.
Non-GAAP financial measures are not in accordance with, or an alternative to GAAP, and should be considered in addition to, and not as a substitute for, the comparable GAAP measure. The following is a reconciliation of consolidated net income, the most directly comparable GAAP measure, to NFE:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Net income | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
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| Add: | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (11,241 | ) | 46,883 |
| (38,681 | ) | |
| Unrealized loss (gain) on derivative instruments and related transactions | | 26,770 |
| (11,241 | ) | 46,883 |
|
| Tax effect | 4,062 |
| (17,018 | ) | 14,391 |
| (4,512 | ) | 4,062 |
| (17,018 | ) |
| Effects of economic hedging related to natural gas inventory | 38,470 |
| (36,816 | ) | (8,225 | ) | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Tax effect | (13,964 | ) | 13,364 |
| 3,058 |
| 7,362 |
| (13,964 | ) | 13,364 |
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NFE | $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
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| Basic earnings per share | $ | 1.53 |
| $ | 1.53 |
| $ | 2.12 |
| $ | 2.66 |
| $ | 1.53 |
| $ | 1.53 |
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| Add: | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (0.13 | ) | 0.55 |
| (0.45 | ) | |
| Unrealized loss (gain) on derivative instruments and related transactions | | 0.31 |
| (0.13 | ) | 0.55 |
|
| Tax effect | 0.05 |
| (0.20 | ) | 0.17 |
| (0.05 | ) | 0.05 |
| (0.20 | ) |
| Effects of economic hedging related to natural gas inventory | 0.45 |
| (0.43 | ) | (0.10 | ) | (0.26 | ) | 0.45 |
| (0.43 | ) |
| Tax effect | (0.17 | ) | 0.16 |
| 0.04 |
| 0.08 |
| (0.17 | ) | 0.16 |
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| Basic NFE per share | $ | 1.73 |
| $ | 1.61 |
| $ | 1.78 |
| $ | 2.74 |
| $ | 1.73 |
| $ | 1.61 |
|
NFE during fiscal 2018 was $59.6 million, or $0.68 per share, higher due to the revaluation of deferred taxes resulting from the reduction in the federal corporate tax rate related to the Tax Act.
NFE by reporting segment and other business operations for the years ended September 30, are as follows:
Additional financial information related to these reporting segments are set forth in Note 15. Reporting Segment and Other Operations Data in the accompanying Consolidated Financial Statements and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
New Jersey Resources Corporation
Part I
ITEM 1. BUSINESS (Continued)
Natural Gas Distribution
General
Our Natural Gas Distribution segment consists of regulated utility operations that provide natural gas service to approximately 529,800538,700 customers. NJNG’s service territory includes New Jersey’s Monmouth and Ocean counties and parts of Burlington, Morris and Middlesex counties. It encompasses 1,516 square miles, covering 105 municipalities with an estimated population of 1.5 million people. It is primarily suburban, highlighted by approximately 100 miles of New Jersey coastline. It is in close proximity to New York City, Philadelphia and the metropolitan areas of northern New Jersey and is accessible through a network of major roadways and mass transportation.
NJNG’s business is subject to various risks, such as those associated with adverse economic conditions, which can negatively impact customer growth, operating and financing costs, fluctuations in commodity prices, which can impact customer usage, customer conservation efforts, certain regulatory actions and environmental remediation. It is often difficult to predict the impact of trends associated with these risks. NJNG employs strategies to manage the challenges it faces, including pursuing customer conversions from other fuel sources and monitoring new construction markets through contact with developers, utilizing incentive programs through BPU-approved mechanisms to reduce gas costs, pursuing rate and other regulatory strategies designed to stabilize and decouple gross margin, and working actively with consultants and the NJDEP to manage expectations related to its obligations associated with its former MGP sites.
Operating Revenues/Throughput
For the fiscal yearyears ended September 30, operating revenues and throughput by customer class are as follows:
| | | | 2017 | | 2016 | | 2015 | 2018 | | 2017 | | 2016 |
| ($ in thousands) | Operating Revenue | Bcf | | Operating Revenue | Bcf | | Operating Revenue | Bcf | Operating Revenue | Bcf | | Operating Revenue | Bcf | | Operating Revenue | Bcf |
| Residential | $ | 395,315 |
| 40.7 |
| | $ | 345,597 |
| 36.9 |
| | $ | 466,464 |
| 45.9 |
| $ | 441,486 |
| 45.5 |
| | $ | 395,315 |
| 40.7 |
| | $ | 345,597 |
| 36.9 |
|
| Commercial and other | 98,777 |
| 8.7 |
| | 80,994 |
| 7.3 |
| | 106,505 |
| 9.6 |
| 95,351 |
| 8.9 |
| | 98,777 |
| 8.7 |
| | 80,994 |
| 7.3 |
|
| Firm transportation | 73,206 |
| 14.4 |
| | 69,696 |
| 14.1 |
| | 77,974 |
| 16.0 |
| 65,256 |
| 15.5 |
| | 73,206 |
| 14.4 |
| | 69,696 |
| 14.1 |
|
| Total residential and commercial | 567,298 |
| 63.8 |
| | 496,287 |
| 58.3 |
| | 650,943 |
| 71.5 |
| 602,093 |
| 69.9 |
| | 567,298 |
| 63.8 |
| | 496,287 |
| 58.3 |
|
| Interruptible | 7,970 |
| 55.0 |
| | 8,867 |
| 61.5 |
| | 10,049 |
| 47.1 |
| 7,522 |
| 46.2 |
| | 7,970 |
| 55.0 |
| | 8,867 |
| 61.5 |
|
| Total system | 575,268 |
| 118.8 |
| | 505,154 |
| 119.8 |
| | 660,992 |
| 118.6 |
| 609,615 |
| 116.1 |
| | 575,268 |
| 118.8 |
| | 505,154 |
| 119.8 |
|
BGSS incentive programs (1) | 120,369 |
| 49.5 |
| | 89,192 |
| 56.6 |
| | 120,978 |
| 47.8 |
| 122,250 |
| 42.8 |
| | 120,369 |
| 49.5 |
| | 89,192 |
| 56.6 |
|
| Total | $ | 695,637 |
| 168.3 |
| | $ | 594,346 |
| 176.4 |
| | $ | 781,970 |
| 166.4 |
| $ | 731,865 |
| 158.9 |
| | $ | 695,637 |
| 168.3 |
| | $ | 594,346 |
| 176.4 |
|
| |
(1) | Does not include 128.9107.4, 160.1128.9 and 174.6160.1 Bcf for the capacity release program and related amounts of $5.7 million, $6.5 million $8.1 million and $8.9$8.1 million, which are recorded as a reduction of gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30, 20172018, 20162017 and 20152016, respectively. |
NJNG added 9,1269,596 and 8,1709,126 new customers and added natural gas heat and other services to another 662613 and 644662 existing customers in fiscal 20172018 and 2016,2017, respectively. NJNG expects its new customer annual growth rate to continue to be approximately 1.71.8 percent with projected additions in the range of approximately 26,00028,000 to 28,00030,000 new customers over the next three years. This anticipated customer growth represents approximately $5.3$5.5 million in new annual utility gross margin, a non-GAAP financial measure, as calculated under NJNG’s current CIP tariff. For a definition of utility gross margin see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution Segment.
In fiscal 20172018, no single customer represented more than 10 percent of consolidated operating revenues.
Seasonality of Gas Revenues
Therm sales are significantly affected by weather conditions, with customer demand being greatest during the winter months when natural gas is used for heating purposes. The relative measurement of the impact of weather is in degree-days. Degree-day data is used to estimate amounts of energy required to maintain comfortable indoor temperature levels based on each day’s average temperature. A degree-day is the measure of the variation in the weather based on the extent to which the average daily temperature falls below 65 degrees Fahrenheit. Each degree of temperature below 65 degrees Fahrenheit is counted as one heating degree-day. Normal heating degree-days are based on a 20-year average, calculated based on three reference areas representative of NJNG’s service territory.
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The CIP, a mechanism authorized by the BPU, stabilizes NJNG’s utility gross margin, regardless of variations in weather. In addition, the CIP decouples the link between utility gross margin and customer usage, allowing NJNG to promote energy conservation measures. Recovery of utility gross margin is subject to additional conditions, including an earnings test, a revenue test and an evaluation of BGSS-related savings achieved over a 12-month period. In May 2014, the BPU approved the continuation of the CIP program with no expiration date.program.
Concurrent with its annual BGSS filing, NJNG files for an annual review of its CIP, during which time it can request rate changes, as appropriate. For additional information regarding the CIP, including rate actions and impact to margin, see Note 4.3. Regulation in the accompanying Consolidated Financial Statements and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution Segment.
Gas Supply
Firm Natural Gas Supplies
In fiscal 20172018, NJNG purchased natural gas from approximately 8079 suppliers under contracts ranging from one day to one year and purchased over 10 percent of its natural gas from one supplier. NJNG believes the loss of this supplier would not have a material adverse impact on its results of operations, financial position or cash flows, as an adequate number of alternative suppliers exist. NJNG believes that its supply strategy should adequately meet its expected firm load overfor the next several years.upcoming winter season.
Firm Transportation and Storage Capacity
NJNG maintains agreements for firm transportation and storage capacity with several interstate pipeline companies to take delivery of firm natural gas supplies, which ensures the ability to reliably service its customers. NJNG receives natural gas at 10 citygate stations located in Middlesex, Morris and Passaic counties in New Jersey.
The pipeline companies that provide firm transportation service to NJNG’s citygate stations, the maximum daily deliverability of that capacity for the upcoming winter season and the contract expiration dates are as follows:
| | | Pipeline | Dths(1) | Expiration | Dths(1) | Expiration |
| Texas Eastern Transmission, L.P. | 300,738 |
| | Various dates between 2018 and 2023 | 300,738 |
| | Various dates between 2019 and 2023 |
| Transcontinental Gas Pipe Line Corp. | | 202,531 |
| | Various dates between 2019 and 2032 |
| Columbia Gas Transmission Corp. | 50,000 |
| | Various dates between 2024 and 2030 | 50,000 |
| | Various dates between 2024 and 2030 |
| Transcontinental Gas Pipe Line Corp. | 42,531 |
| | Various dates between 2018 and 2032 | |
| Tennessee Gas Pipeline Co. | 25,166 |
| | Various dates between 2018 and 2023 | 25,166 |
| | Various dates between 2023 and 2024 |
| Algonquin Gas Transmission | 12,000 |
| | 2019 | 12,000 |
| | 2020 |
| Total | 430,435 |
| | 590,435 |
| |
| |
| (1) | Numbers are shown net of any capacity release contracted amounts. |
Dominion Energy Transmission, Inc. provides NJNG firm contract transportation service and supplies the pipelines included in the table above.
In addition, NJNG has storage contracts that provide an additional 102,941 Dths of maximum daily deliverability to NJNG’s citygate stations from storage fields in its Northeast market area. The storage suppliers, the maximum daily deliverability of that storage capacity and the contract expiration dates are as follows:
| | | Pipeline | Dths | Expiration | Dths | Expiration |
| Texas Eastern Transmission, L.P. | 94,557 |
| | 2019 | 94,557 |
| | 2020 |
| Transcontinental Gas Pipe Line Corp. | 8,384 |
| | 2019 | 8,384 |
| | 2028 |
| Total | 102,941 |
| | 102,941 |
| |
NJNG also has upstream storage contracts. The maximum daily deliverability and contract expiration dates are as follows:
|
| | | | |
| Company | Dths | Expiration |
| Dominion Transmission Corporation | 154,714 |
| | Various dates between 2020 and 2023 |
| Steckman Ridge, L.P. | 38,000 |
| | 2020 |
| Central New York Oil & Gas | 25,337 |
| | 2023 |
| Total | 218,051 |
| | |
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|
| | | | |
| Company | Dths | Expiration |
| Dominion Transmission Corporation | 208,214 |
| | Various dates between 2021 and 2024 |
| Steckman Ridge, L.P. | 38,000 |
| | 2020 |
| Stagecoach Pipeline & Storage Company LLC | 25,337 |
| | 2023 |
| Total | 271,551 |
| | |
NJNG utilizes its transportation contracts to transport gas to NJNG’s citygates from the Dominion Transmission Corporation, Steckman Ridge and Central New York OilStagecoach Pipeline & GasStorage Company LLC storage fields. NJNG has sufficient firm transportation, storage and supply capacity to fully meet its firm sales contract obligations.
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ITEM 1. BUSINESS (Continued)
Citygate Supplies from Energy Services
NJNG has several citygate supply agreements with Energy Services. NJNG and Energy Services have an agreement where NJNG releases 10,000 Dths/day of Texas Eastern TransmissionTetco capacity, 2,200 Dths/day of Dominion Energy Transmission, Inc. capacity, 10,728 Dths/day of Tennessee Gas Pipeline capacity and 1.6 million Dths of Central New York OilStagecoach Pipeline & GasStorage Company LLC storage capacity to Energy Services for the period of April 1, 20172018 to March 31, 2018.2019. NJNG can call upon a supply of up to 20,000 Dths/day delivered to NJNG’s Texas Eastern citygate. Energy Services manages the storage inventory and NJNG can call on that storage supply as needed at NJNG’s Tennessee citygate or storage point.
NJNG also has agreements where it releases 80,000160,000 Dths/day of its Texas Eastern TransmissionTetco capacity to Energy Services for the period of April 1, 2016 to October 31, 2020.2021. Under these agreements, NJNG can call upon a supply of up to 80,000160,000 Dths/day delivered to its Texas Eastern citygate as needed. See Note 16.15. Related Party Transactions in the accompanying Consolidated Financial Statements for additional information regarding these transactions.
Peaking Supply
To manage its winter peak day demand, NJNG maintains two LNG facilities with a combined deliverability of approximately 170,000 Dths/day, which represents approximately 1918 percent of its estimated peak day sendout. In June 2016, NJNG’s liquefaction facility became operational and now 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 is also designed to allowallows each natural gas utility to provisionally increase residential and small commercial customer BGSS rates on December 1 and February 1 for up to a five percent increase to the average residential heat customer’s bill on a self-implementing basis afterwith proper notice and BPU action on the June filing.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 4.3. 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 and was part of its FRM program. The FRM program was terminated effective November 2015.clause.
Future Natural Gas Supplies
NJNG expects to meet the natural gas requirements for existing and projected firm customers into the foreseeable future.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. In September 2016, the BPU approved NJNG'sNJNG’s filing for an increase to base rates in the amount of $45 million, effective October 2016. See Note 4.3. Regulation in the accompanying Consolidated Financial Statements for additional information regarding NJNG’s rate proceedings.
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ITEM 1. BUSINESS (Continued)
Federal
FERC regulates rates charged by interstate pipeline companies for the transportation and storage of natural gas. This affects NJNG’s agreements with several interstate pipeline companies for the purchase of such services. Costs associated with these services are currently recoverable through the BGSS.
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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, coal, electricity and propane. At the present time, however, natural gas is used in over 95 percent of new construction due to its efficiency, reliability and price advantage. Natural gas prices are a function of market supply and demand. Although NJNG believes natural gas will remain competitive with alternate fuels, no assurance can be given in this regard.
The BPU, within the framework of the EDECA, fully opened NJNG’s residential markets to competition, including third-party suppliers, and restructured rates to segregate its BGSS and delivery (i.e., transportation) prices. New Jersey’s natural gas utilities must provide BGSS in the absence of a third-party supplier. On September 30, 2017,2018, NJNG had 32,65326,490 residential and 10,1379,636 commercial and industrial customers utilizing the transportation service.
Clean Energy Ventures
Our Clean Energy Ventures segment invests in, owns and operates clean energy projects, including commercial and residential solar installations located in New Jersey, and wind farms located in Montana, Iowa, Kansas, Wyoming and Pennsylvania.
As of September 30, 2017,2018, Clean Energy Ventures has constructed a total of 189.1231.3 MW of solar capacity in New Jersey that has qualified for ITCs, including a combination of residential and commercial net-metered and grid-connected solar systems. As part of its solar investment program, Clean Energy Ventures operates a residential lease program, The Sunlight Advantage®, which provides qualifying homeowners with the opportunity to have a solar system installed at their home with no installation or maintenance expenses. Clean Energy Ventures owns, operates and maintains the system over the life of the lease in exchange for monthly lease payments. In addition, certain qualified non-profit institutions are served under PPAs. The program is operated by Clean Energy Ventures using qualified contracting partners in addition to strategic suppliers for material standardization and sourcing. The residential solar lease and PPA market is highly competitive, with various companies operating in New Jersey. Clean Energy Ventures competes on price, quality and brand reputation, leveraging its partner network and customer referrals.
Clean Energy Ventures’ commercial solar projects are sourced through various channels and include both net-metered and grid-connected systems. Net-metered projects involve the sale of energy to a host and grid-connected systems into the wholesale energy markets. Project construction is competitively sourced through third parties. New Jersey has the fifthsixth 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.
TheOur solar systems are registered and certified with the BPU’s Office of Clean Energy and qualified to produce SRECs. One SREC is created for every MWh of electricity produced by a solar generator. Clean Energy Ventures sells the SRECs it generates to a variety of counterparties, including electric load servingload-serving entities that serve electric customers in New Jersey and are required to comply with the solar carve-out of the Renewable Portfolio Standard.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 addition to its solar investments, Clean Energy Ventures invests in small to mid-size onshore wind projects that fit its investment profile. As of September 30, 2017,2018, Clean Energy Ventures has a total of 126.6116.9 MW of wind capacity. The wind projects are eligible for PTCs for a 10-year period following commencement of operations and have PPAs of various terms in place, which typically govern the sale of energy, capacity and/or renewable energy credits. An $89 million, 39.9 MW wind project in Somerset County, Pennsylvania was completed in December 2016.
New Jersey Resources CorporationIn March 2018, Clean Energy Ventures committed to a plan to sell its remaining wind assets and it is probable that the sale will be completed within the next 12 months. Accordingly, wind assets and related liabilities are classified as held for sale on the Consolidated Balance Sheets.
Part I
ITEM 1. BUSINESS (Continued)On June 1, 2018, Clean Energy Ventures completed the sale of its membership interest in its
9.7 MW wind farm in Two Dot, Montana to NorthWestern Energy for a total purchase price of $18.5 million. The transaction generated a pre-tax gain of approximately $951,000, which is recognized as a reduction to O&M on the Consolidated Statements of Operations.
Clean Energy Ventures is subject to various risks including those associated with adverse federal and state legislation and regulatory policies, construction delays that can impact the timing or eligibility of tax incentives, technological changes and the future market of SRECs. See Item 1A. Risk Factors for additional information regarding these risks.
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Energy Services
Our Energy Services segment consists of unregulated wholesale and retail natural gas operations and provides producer and asset management services to a diverse customer base across North America. Energy Services has acquired contractual rights to natural gas storage and transportation 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 in conjunction with identifying strategic opportunities that exist in or between the market areas that it serves. These opportunities are driven by price differentials between market locations and/or time periods. Energy Services’ activities are conducted in the market areas in which it has strong expertise, including the U.S. and Canada. Energy Services differentiates itself in the marketplace based on price, reliability and quality of service. Its competitors include wholesale marketing and trading companies, utilities, natural gas producers and financial institutions. Energy Services’ portfolio of customers includes regulated natural gas distribution companies, industrial companies, electric generators, natural gas/liquids processors, retail aggregators, wholesale marketers and natural gas producers.
While focusing on maintaining a low-risk operating and counterparty credit profile, Energy Services’ activities specifically consist of the following elements:
Providing natural gas portfolio management services to nonaffiliated and our affiliated natural gas utilities,utility, electric generation facilities and natural gas producers;
Managing strategies for new and existing natural gas storage and transportation assets to capture value from changes in price due to location or timing differences as a means to generate financial margin (as defined below);
Managing transactional logistics to minimize the cost of natural gas delivery to customers while maintaining security of supply. Transactions utilize the most optimal and advantageous natural gas supply transportation routing available within its contractual asset portfolio and various market areas; and
Managing economic hedging programs that are designed to mitigate the impact of changes in market prices on financial margin generated on its natural gas storage and transportation commitments.
OnFrom July 27, 2017 we acquired certain wholesale transportation andthrough February 2018, NJRRS provided retail natural gas energy contracts from Talen, providing servicesupply and transportation services to largecommercial and industrial retail and commercial customers in Delaware, Maryland, Pennsylvania and New Jersey and Pennsylvania. Our competitors include other retail marketing companies that provide service in the same states.Jersey. NJRRS was sold to an unrelated third party on February 28, 2018. See Note 17. Dispositions for more details.
In fiscal 2017,2018, Energy Services purchased over 10 percent of its natural gas from one supplier. Energy Services believes the loss of this supplier would not have a material adverse impact on its results of operations, financial position or cash flows, as an adequate number of alternative suppliers exist.
Transportation and Storage Transactions
Energy Services focuses on creating value from the use of its physical assets, which are typically amassed through contractual rights to natural gas storage and transportation capacity. These assets become more valuable when favorable price changes occur that impact the value between or within market areas and across time periods. On a forward basis, Energy Services may hedge these price differentials through the use of financial instruments. In addition, Energy Services may seek to optimize these assets on a daily basis, as market conditions warrant, by evaluating natural gas supply and transportation availability within its portfolio. This enables Energy Services to capture geographic pricing differences across various regions, as delivered natural gas prices may change favorably as a result of market conditions. Energy Services may, for example, initiate positions when intrinsic financial margin is present, and then enhance that financial margin as prices change across regions or time periods.
Energy Services also engages in park-and-loan transactions with storage and pipeline operators, where Energy Services will either borrow (receive a loan of) natural gas with an obligation to repay the storage or pipeline operator at a later date or “park” natural gas with an obligation to withdraw at a later date. In these cases, Energy Services evaluates the economics of the transaction to determine if it can capture pricing differentials in the marketplace and generate financial margin. Energy Services evaluates
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ITEM 1. BUSINESS (Continued)
deal attributes such as fixed fees, calendar spread value from deal inception until volumes are scheduled to be returned and/or repaid, as well as the time value of money. If this evaluation demonstrates that financial margin exists, Energy Services may enter into the transaction and hedge with natural gas futures contracts, thereby locking in financial margin.
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ITEM 1. BUSINESS (Continued)
Energy Services maintains inventory balances to satisfy existing or anticipated sales of natural gas to its counterparties and/or to create additional value, as described above. During fiscal 20172018 and 2016,2017, Energy Services managed and sold 521.6662.4 Bcf and 551.1521.6 Bcf of natural gas, respectively. In addition, as of September 30, 20172018 and 2016,2017, Energy Services had 53.934.1 Bcf or $122.9$90.2 million of gas in storage and 6253.9 Bcf or $130.5$122.9 million of gas in storage, respectively.
Weather/Seasonality
Energy Services activities are typically seasonal in nature as a result of changes in the supply and demand for natural gas. Demand for natural gas is generally higher during the winter months when there may also be supply constraints; however, during periods of milder temperatures, demand can decrease. In addition, demand for natural gas can also be high during periods of extreme heat in the summer months, resulting from the need for additional natural gas supply for gas-fired electric generation facilities. Accordingly, Energy Services can be subject to variations in earnings and working capital throughout the year as a result of changes in weather.
Volatility
Energy Services’ activities are also subject to price volatility or supply/demand dynamics within its wholesale markets, including in the Northeastern, Appalachian, West Coast and Mid-Continent regions. Changes in natural gas supply can affect capacity values and Energy Services’ financial margin, described below, that is generated from the optimization of transportation and storage assets. With its focus on risk management, Energy Services continues to diversify its revenue stream by identifying new growth opportunities in producer and asset management services. Energy Services has added new counterparties and strategic storage and transportation assets to its portfolio, which currently includes an average of approximately 44.649.1 Bcf of firm storage and 1.11.5 Bcf/day of firm transportation capacity. Energy Services continues to expand its geographic footprint.
Financial Margin
To economically hedge the commodity price risk associated with its existing and anticipated commitments for the purchase and sale of natural gas, Energy Services enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial swaps and options. These derivative instruments are accounted for at fair value with changes in fair value recognized in earnings as they occur. Energy Services views “financial margin” as a key internal financial metric. Energy Services’ financial margin, which is a non-GAAP financial measure, represents revenues earned from the sale of natural gas less costs of natural gas sold including any storage and transportation costs, and excluding any accounting impact from changes in the fair value of certain derivative instruments. For additional information regarding financial margin, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Energy Services Segment.
Risk Management
In conducting its business, Energy Services mitigates risk by following formal risk management guidelines, including transaction limits, segregation of duties and formal contract and credit review approval processes. Energy Services continuously monitors and seeks to reduce the risk associated with its counterparty credit exposures. TheOur Risk Management Committee of the Company oversees compliance with these established guidelines.
Midstream
Our Midstream segment includes investments in FERC-regulated interstate natural gas transportation and storage assets and is comprised of the following subsidiaries:
NJR Steckman Ridge Storage Company, which holds the Company’sour 50 percent equity investment in Steckman Ridge. Steckman Ridge is a Delaware limited partnership, jointly owned and controlled by our subsidiaries of the Company and subsidiaries of Enbridge Inc., that built, owns and operates a natural gas storage facility with up to 12 Bcf of working gas capacity in Bedford County, Pennsylvania. The facility has direct access to the Texas Eastern and Dominion Transmission pipelines and has access to the Northeast and Mid-Atlantic markets;
NJR Pipeline Company, which consists of aincludes our 20 percent equity investment in PennEast. PennEast is expected to construct a 120-mile, FERC-regulated interstate natural gas pipeline system that will extend from northern Pennsylvania to western New JerseyJersey. Adelphia, our wholly owned subsidiary of NJR Pipeline Company, was established in anticipation of acquiring the membership interests in IEC. Upon closing, Adelphia will include an existing 84-mile pipeline in southeastern Pennsylvania and is estimated to be completedrelated assets and operational in 2019;rights of way; and
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NJR Midstream Holdings Corporation, which, through its subsidiary NJNR Pipeline Company, holds approximately 1.84 million DM Common Units.
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ITEM 1. BUSINESS (Continued)
OTHER BUSINESS OPERATIONS
Home Services and Other
Home Services and Other operations consist primarily of the following unregulated affiliates:
NJRHS, which provides heating, ventilation and cooling service, sales and installation of appliances to approximately 112,000110,000 service contract customers, as well as installation of solar equipment;
NJRPS,NJR Plumbing Services, Inc., which provides plumbing repair and installation services;
CR&R, which holds commercial real estate;
NJR Energy, which was dissolved on November 28, 2016, invested in energy-related ventures; and
NJR Service Corporation, which provides shared administrative and financial services to the Company and all of its subsidiaries.
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 five 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 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 MGP sites for which it is responsible will range from approximately $117.6$117.7 million to $205.2$204.1 million.
NJNG’s estimate of these liabilities is based upon known and measurable facts, existing technology and enacted laws and regulations in place when the review was completed in fiscal 2017.2018. 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, 2017,2018, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $149$130.8 million on the Consolidated Balance Sheets, which represents its most likely possible liability and recoverable regulatory asset; however, actual costs may differ from these estimates. NJNG currently recovers approximately $9.4 million annually through its SBC RAC. NJNG will continue to seek recovery of these costs through its remediation rider. On November 17, 2017, NJNG filed it's annual SBC application requesting a reduction in the RAC, which will decrease the annual recovery to $7 million, effective April 1, 2018.
EMPLOYEE RELATIONS
As of September 30, 2017,2018, the Company and itsour subsidiaries employed 1,0521,068 employees compared with 1,0341,052 employees as of September 30, 2016.2017. Of the total number of employees, NJNG had 444446 and 441444 and NJRHS had 10497 and 106104 Union or “Represented”Represented employees as of September 30, 20172018 and 2016,2017, respectively. NJNG and NJRHS have collective bargaining agreements with the Union, which is affiliated with the American Federation of Labor and Congress of Industrial Organizations, that expire in December 2018 and April 2019, respectively. The labor agreements cover wage increases and other benefits, including the defined benefit pension (which was closed to all employees hired on or after January 1, 2012, with the exception of certain rehires who are eligible to resume active participation), the postemployment benefit plan (which was closed to all employees hired on or after January 1, 2012) and the enhanced 401(k) retirement savings plan. The Company considers itsCollective bargaining negotiations with the Union for represented NJNG employees commenced in October 2018 and are expected to commence in February 2019 for represented NJRHS employees. We consider our relationship with employees, including those covered by collective bargaining agreements, to be in good standing.
New Jersey Resources Corporation
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ITEM 1. BUSINESS (Continued)
AVAILABLE INFORMATION AND CORPORATE GOVERNANCE DOCUMENTS
The following reports and any amendments to those reports are available free of charge on our website at http://njr360.client.shareholder.com/sec.cfminvestor.njresources.com/corporate-governance/sec-filings as soon as reasonably possible after filing or furnishing them with the SEC:
Annual reports on Form 10-K;
Quarterly reports on Form 10-Q; and
Current reports on Form 8-K.
The following documents are available free of charge on our website (http://njr360.client.shareholder.com/governance.cfm)investor.njresources.com/corporate-governance):
Bylaws;
Corporate Governance Guidelines;
Wholesale Trading Code of Conduct;
NJR Code of Conduct;
Charters of the following Board of Directors Committees: Audit, Leadership Development and Compensation and Nominating/Corporate Governance;
Audit Complaint Procedure;
Communicating with Non-Management Directors Procedure; and
Statement of Policy with Respect to Related Person Transactions.
In Part III of this Form 10-K, we incorporate certain information by reference from our Proxy Statement for our 20182019 Annual Meeting of Shareowners. We expect to file that Proxy Statement with the SEC on or about December 14, 2017.13, 2018. We will make it available on our website as soon as reasonably possible following that filing date. Please refer to the Proxy Statement when it is available.
A printed copy of each document is available free of charge to any shareownershareholder who requests it by contacting the Corporate Secretary at New Jersey Resources Corporation, 1415 Wyckoff Road, Wall, New Jersey 07719.
ITEM 1A. RISK FACTORS
When considering any investment in our securities, investors should consider the following risk factors, as well as the information contained under the caption “Information Concerning Forward-Looking Statements,” in analyzing our present and future business performance. While this list is not exhaustive, management also places no priority or likelihood based on their descriptions or order of presentation. 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.
Our investments in cleansolar energy projects are subject to substantial risks and competition.uncertainties.
CommercialOur investments in commercial and residential solar energy projects and onshore wind projects, such as thoseare dependent, in which we invest, are dependentpart, upon current regulatory and tax incentives and there is uncertainty aboutfederal tax credits in order for the extentprojects to which such incentives will be available in the future. The potentialeconomically viable. Our return on investment offor these solar projects is based substantially on our eligibility for ITCs and the future market forvalue of SRECs that are traded in a competitive marketplace in the State of New Jersey. As a result, these projects face the risk that the current regulatory regimesprograms and tax laws may expire or be adversely modified during the life of the projects.modified. Furthermore, a sustained decrease in the value of SRECs wouldcould negatively impact the return on our investment and could result in our portfolio of solar projects. Legislative changes or declines in the price of SRECs could also lead to an impairment of solar project assets.assets becoming impaired. The market for such projects is also limited, which creates increased competition for customers and higher investment costs and could potentiallythat may result in lostfewer investment opportunities.opportunities that meet our return requirements.
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ITEM 1A. RISK FACTORS (Continued)
In addition, there are risks associated with our ability to develop and manage such projects profitably, including logistical risks and potential delays related to construction, permitting, regulatory approvals (including any approvals by the BPU required pursuant to recently enacted solar energy legislation in the State of New Jersey) and electric grid interconnection, as well as 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.
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 natural gas storage facilities, NJNG infrastructure improvements, such as SRL and NJ RISE, pipeline transportation systems, such as PennEast, planned Adelphia acquisition and IEC, solar energy projects and onshore wind 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 successfully 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 favorable interest rates. If we do not obtain the necessary regulatory approvals, property rights and financing, our equity investments could be impaired. Such impairment could have a materially adverse effect on our financial condition, results of operations and cash flows.
Uncertainties associated with our planned Adelphia acquisition of IEC could adversely affect our business, results of operations, financial condition and cash flows. Furthermore, any acquisitions that we undertake might involve risks and uncertainties. We may not realize the anticipated synergies, cost savings and growth opportunities as a result of these transactions.
In October 2017, we announced our planned Adelphia acquisition, involving the entry into an agreement to purchase IEC, whose principle operations relate to thefuture operation and maintenance of an oil anda natural gas transmission pipeline extending approximately 90 miles into eastern Pennsylvania. As part of the acquisition we expect to convert the remaining sections of the southern mainline of the pipeline utilized to transport oil to transport natural gas. The completion of the acquisition is subject to various closing conditions, including, but not limited to, receipt of necessary permits and regulatory actions, such as those from the FERC and the Pennsylvania Public Utility Commission, and other pending regulatory determinations, such as compliance with anti-trust laws. There can be no assurance that we will receive the necessary approvals for the transaction or receive them within the expected timeframe. The announcement and pendency of the IECour planned Adelphia acquisition, as well as any delays in the expected timeframe, could cause disruption and create uncertainties, which could have an adverse effect on our business, results of operations and financial condition, regardless of whether the acquisition is completed.
Furthermore,Any acquisitions that we may undertake involve risks and uncertainties. We may not realize the anticipated synergies, cost savings and growth opportunities as a results of these transactions.
The integration of any acquisitionacquisitions requires significant time and resources. Investments of resources are required to support any acquisition, which could result in significant ongoing operating expenses and may experience challenges when combining separate business cultures, information technology systems and employees, and those challenges may divert resourcessenior management’s time and management attention from other areas of our business.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 become impaired, andthe 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 timely and seamlessly. We may experience challenges when combining separate business cultures, information technology systems and employees. Even if we are able to complete the integration successfully, we may not fully realize all of the growth opportunities, cost savings and other synergies that we expect.
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Major changes in the supply and price of natural gas may affect financial results.
While NJNG expects to meet theits customers’ demand for natural gas from its customers for the foreseeable future, factors impacting 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, 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.
NJNG actively hedges 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.
New Jersey Resources Corporation
Part IWe 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.
ITEM 1A. RISK FACTORS (Continued)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.
The 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. FERC will also have regulatory authority over Adelphia’s operations. 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 impact 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.
Significant regulatory assets recorded by NJNG 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'sNJNG’s MGP sites, CIP, NJCEP, economic stimulus plans, certain deferred income tax and pension and other postemployment benefit plans. 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.
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.
New Jersey Resources Corporation
Part I
NJNGITEM 1A. RISK FACTORS (Continued)’s
Our regulated operations are subject to certain operating risks incidental to handling, storing, transporting and providing customers with natural gas.
NJNG’sOur regulated operations are subject to all operating hazards and risks incidental to handling, storing, transporting and providing customers with natural gas, including its NGVour 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. NJNGWe could suffer substantial losses should any of these events occur. Moreover, as a result, NJNG has been, and likely will be, a defendant in legal proceedings and litigation arising in the ordinary course of business. Although NJNG maintains insurance coverage, insurance may not be sufficient to cover all material expenses related to these risks.
NJNG and Energy Services rely on storage, transportation assets and suppliers, which they do not own or control, to deliver natural gas.
NJNG and Energy Services depend on natural gas pipelines and other storage and transportation 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, 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 United States. Energy deregulation legislation may increase competition among natural gas utilities and impact the quantities of natural gas requirements needed for sales service. Energy Services 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 Energy Services 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 market rates. Particularly for Energy Services, these conditions could have a material impact on our financial condition, results of operations and cash flows.
Risks related to the regulation of NJNG could affect the rates it is able to charge, its costs and its 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 obtain rate increases, including base rate increases, extend
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
its BGSS incentive and CIP programs and maintain its currently authorized rates of return may be impacted by events, including regulatory or legislative actions. There can be no assurance that NJNG will be able to obtain rate increases and continue its BGSS incentive, CIP, RAC and SAVEGREEN programs or continue the opportunity to earn its currently authorized rates of return.
A change in our effective tax rate as a result of a failure to qualify for ITCs and PTCs or being delayed in qualifying for ITCs due to delays or failures to complete planned solar energy projects and wind projects within the safe harbor period may have a material impact on our earnings.
GAAP requires that we apply an effective tax rate to interim periods that is consistent with our estimated annual effective tax rate. As a result, we project quarterly the annual effective tax rate and then adjust the tax expense recorded in that quarter to reflect the projected annual effective tax rate. The amount of the quarterly adjustment is based on information and assumptions, which are subject to change and may have a material impact on our quarterly and annual NFE. Factors we consider in estimating the probability of projects being completed during the fiscal year include, but are not limited to, Board of Directors approval, construction logistics, permitting, interconnection completion and execution of various contracts, including PPAs. If we fail to qualify for ITCs or are delayed in qualifying for some ITCs during the fiscal year due to delays or failures to complete planned solar energy projects as scheduled, our quarterly and annual net income and NFE may be materially impacted. This could have a material adverse impact on our financial condition, results of operations and cash flows.
For a wind facility to be considered a qualified facility for purposes of the PTCs, the construction of the facility must have begun prior to January 1, 2020, and placed in service before January 1, 2024. A taxpayer may establish that construction has begun by starting “physical work of a significant nature.” Only physical work of a significant nature on tangible personal property used as an integral part of the activity performed by the facility is considered for purposes of determining when construction begins. Alternatively, a taxpayer may establish that construction has begun by paying or incurring five percent of eligible project costs (the “five percent safe harbor”).
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
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.
WeIn 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, 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.
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 S&P currently rate NJNG’s debt as investment grade. If such ratings are downgraded below investment grade, borrowing costs could increase, as will 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 Energy Services, Clean Energy Ventures and Midstream, which rely on our creditworthiness, would be adversely affected. Energy Services 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. Clean Energy Ventures 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. In addition, NJNR Pipeline Company may not be able to finance its capital obligations to PennEast.
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.
Cyberattacks or failure of information technology systems could adversely affect our business operations, financial condition and results of operations.
We continue to place greaterever-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, our financial position, results of operations and cash flows.
We rely on information technology to manage our natural gas distribution, energy trading and other corporate operations, maintain customer, employee, Company and vendor data, 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. Any of the foregoing events could adversely affect our business reputation, diminish customer confidence, disrupt operations, subject us to financial liability or increased regulation, increase our costs and expose us to material legal claims and liability.
There is no guarantee that redundancies built into our networks and technology, or the procedures we have implemented to protect against cyberattack and other unauthorized access to secured data, are adequate to safeguard against all failures of technology or security breaches.
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Credit rating downgrades could increase financing costs, limit access to the financial markets and negatively affect NJR and its subsidiaries.
Rating agencies Moody’s and S&P currently rate NJNG’s debt as investment grade. If such ratings are downgraded below investment grade, borrowing costs could increase, as will 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 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 Energy Services, Clean Energy Ventures and Midstream, which rely on our creditworthiness, would be adversely affected. Energy Services 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. Clean Energy Ventures 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. In addition, NJNR Pipeline may not be able to finance its capital obligations to PennEast.
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.
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 regulatory 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.
The 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. 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 impact 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.
Adverse economic conditions, including inflation, increased natural gas costs, foreclosures and business failures, could adversely impact NJNG’s customer collections and increase our level of indebtedness.
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Inflation may cause increases in certain operating and capital costs. We continually review the adequacy of NJNG’s base tariff rates in relation to the increasing cost of providing service and the inherent regulatory lag in adjusting those rates. The ability to control operating expenses is an important factor that will influence future results.
Rapid increases in the price of purchased gas may cause NJNG 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 of monthly bills for gas delivered to customers. Increases in purchased gas costs also slow collection efforts as customers are more likely to delay the payment of their gas bills, leading to higher-than-normal accounts receivable.
If we are unable to access the financial markets or there are adverse conditions in the equity or credit markets, 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
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
regulatory approvals may be necessary for NJNG to incur debt, NJNG may be unable to access credit markets on a timely basis. 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 United States 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, particularly with respect to NJNG’s variable rate debt instruments.
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.
Energy Services 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.
The cost of providing pension and postemployment health care benefits to 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.
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 storage and transportation portfolios consist of contracts to transport and store natural gas. The value of our storage and transportation portfolio could be negatively impacted if the value of these contracts change in a direction or manner that we do not anticipate. In addition, upon expiration of these storage and transportation contracts, to the extent that they are renewed or replaced at less favorable terms, our results of operations and cash flows could be negatively impacted.
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
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 Energy Services’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, Energy Serviceswe 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.
Energy Services'Services’ earnings and cash flows are dependent upon optimization of its physical assets.
Energy Services'Services’ earnings and cash flows are based, in part, on its ability to optimize its portfolio of contractual-basedcontractually-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 Energy Services'Services’ market areas, including as a result of increased production along the Marcellus Shale, can reduce Energy Services'Services’ ability to take advantage of pricing fluctuations in the future. Changes in pricing dynamics and supply could have an adverse impact on Energy Services'Services’ optimization activities, earnings and cash flows. Energy Services incurs fixed demand fees to acquire its contractual rights to storage and transportation assets. Should commodity prices at various locations or time periods change in such a way that Energy Services is not able to recoup these costs from its customers, the cash flows and earnings at Energy Services, and ultimately the Company, could be adversely impacted.
A valuation allowance may be required for our deferred tax assets.
A valuation allowance may need to be recorded against our net deferred tax assets, which are predominantly related to net operating losses, based on available evidence, including cumulative and forecasted taxable income at the time the estimate is made. A valuation allowance related to deferred tax assets can be affected by changes to tax laws, statutory tax rates and future taxable income levels. In the event that we determine that we would not be able to realize all or a portion of our net deferred tax assets in the future, we would reduce such amounts accordingly through a charge to income tax expense in the period in which that determination was made, which could have a material adverse impact on our financial condition and results of operations.
Changes in tax laws or regulations may negatively affect our results of operations, net income, financial condition and cash flows.
We are subject to taxation by various taxing authorities at the federal, state and local levels. The current administration has made federal corporate tax reform one of its priorities and the possibility of such reform is thought to be increased in light of the Republican-led Congress. While such reform is likely to be favorable to corporations generally, the structure of any such reform is unknown and a change in tax laws or rates could in fact adversely affect our results of operations, net income, financial condition and cash flows. We cannot predict the timing or structure of such tax-related developments.
Changes in weather conditions may affect earnings and cash flows.
Weather conditions and other natural phenomena can have an adverse impact on our earnings and cash flows. Severe weather conditions can impact suppliers and the pipelines that deliver gas to NJNG’s distribution system. Extended mild weather, during either the winter period or summer period, can have a significant impact on demand for and the cost of natural gas. While we believe the CIP mitigates the impact of weather variations on NJNG’s 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.
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
Future results at Energy Services 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 Energy Services'Services’ earnings and cash flows.
Changes in tax laws or regulations may negatively affect our results of operations, net income, financial condition and cash flows.
We are subject to taxation by various taxing authorities at the federal, state and local levels. On December 22, 2017, the President signed into law the Tax Act. The newly enacted legislation included a broad range of tax reform initiatives, including a reduction to the federal statutory corporate tax rate from 35 percent to 21 percent, modification of bonus depreciation and changes to the deductibility of certain business-related expenses. Any future change in tax laws, including the Tax Act, or interpretation of such laws, could adversely affect our results of operations, net income, financial condition and cash flows. In addition, we cannot predict how our federal and state regulators will apply such tax change in our future rates.
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
A valuation allowance may be required for our deferred tax assets.
As a result of the Tax Act’s decrease to the federal statutory corporate tax rate, we revalued our deferred tax assets and liabilities at the enactment date to reflect the rates expected to be in effect when the deferred tax assets and liabilities are realized or settled. Since these adjustments are based on assumptions we made with respect to our book versus tax differences and the timing of when those differences will reverse, the revaluation of our net deferred tax liabilities is subject to change as information and assumptions are updated. Our deferred tax assets are comprised primarily of investment tax credits and state net operating losses. Any further 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.
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 and, in the case of NJNG, an interest coverage ratio. 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. 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.
Changes in customer growth may affect earnings and cash flows.
NJNG’s ability to increase its utility firm 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 firm gross margin, earnings and cash flows. Furthermore, while our estimateestimates regarding customer growth isare based in part upon information from third parties, the estimate hasestimates have not been verified by an independent source and isare subject to the aforementioned risks and uncertainties, which could cause actual results to materially deviate from the estimate.estimates.
We may be adversely impacted by natural disasters, pandemic illness, terrorist activities and other extreme events to which we may be unable to promptly respond.
Local or national natural disasters, pandemic illness, terrorist activities, 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 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. 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.
We maintain emergency planning and training programs to readily respondA slow or inadequate response to events that could cause business interruption. However, a slow or inadequate response to eventsinterruption may have an adverse impact on operations and earnings. We may be unable to obtain sufficient insurance 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.
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 extensive 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 significant financial resources to, among other things, conduct site remediation and perform environmental
New Jersey Resources Corporation
Part I
ITEM 1A. RISK FACTORS (Continued)
may require us to expend significant 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 significant expenditures to come into compliance. Additionally, any alleged violations of environmental laws and regulations may require us to expend significant resources in our defense against alleged violations.
Furthermore, the U.S. Congress has for some time been considering various forms of climate change legislation. There is a possibility that, when and if enacted, the final form of such legislation could impact our costs and put upward pressure on natural gas prices. Higher cost levels could impact the competitive position of natural gas and negatively affect our growth opportunities, cash flows and earnings.
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. Furthermore, the majority of our natural gas distribution segment workforce is represented byNJNG and NJRHS have collective bargaining agreements with the Union and is covered by a collective bargaining agreement that will expire in December 2018.2018 and April 2019, respectively. Union negotiations for represented NJNG employees commenced in October 2018 and are expected to commence in February 2019 for represented NJRHS employees. Disputes with the Union over terms and conditions of the agreement could result in instability in our labor relationship and work stoppages that could impact the timely delivery of gas and other services from our utility, 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 agreement may also increase the cost of employing our natural gas distribution segment 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.
Investing through partnerships, joint ventures or in an MLP decreases our ability to manage risk.
We have utilized joint ventures through partnerships for certain midstream investments, including Steckman Ridge and PennEast, and we own a minority interest in DM, an MLP, through our investment in DM Common Units. 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. Our financial condition, results of operations or cash flows could be harmed if a joint venture participant acts contrary to our interests.
Additionally, our investment in DM has risks that are unique to investments in MLPs. Holders of MLP common units have limited control and voting rights on matters affecting the MLP, and investments in MLPs may have limited liquidity. Additionally, if DM is treated as a corporation for federal income tax purposes as a result of a change in current law or a change in DM’s business, such treatment would result in a reduction in the after-tax return to us and may cause a reduction in the value of our investment in DM Common Units.
Our certificate of incorporation and bylaws may delay or prevent a transaction that stockholders would view as favorable.
Our certificate of incorporation and 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 currentthen-current market price. These provisions may also prevent changes in management. In addition, our Board of Directors is authorized to issue preferred stock without stockholder approval on such terms as our Board of Directors may determine. Our common stockholders 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.
New Jersey Resources Corporation
Part I
ITEM 1B. UNRESOLVED STAFF COMMENTS
None
ITEM 2. PROPERTIES
Natural Gas Distribution Segment
NJNG owns approximately 7,1977,252 miles of distribution main, 7,4247,525 miles of service main, 226227 miles of transmission main and approximately 549,000557,000 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.
NJNG owns four service centers located in Rockaway Township, Morris County; Atlantic Highlands and Wall Township, Monmouth County; and Lakewood, Ocean County. These service centers house storerooms, garages, gas distribution and administrative offices. NJNG leases its headquarters and customer service facilities in Wall Township, Monmouth County,County; a customer service office in Asbury Park, Monmouth CountyCounty; and a service center in Manahawkin, Ocean County. These customer service offices support customer contact, marketing, economic development and other functions.
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 $672 million as of September 30, 2017.2018. In addition, under the terms of the Mortgage Indenture, NJNG could have issued up to $960 million$1 billion of additional first mortgage bonds as of September 30, 2017.2018.
Clean Energy Ventures Segment
Clean Energy Ventures 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. In addition to the lease agreements and easements, Clean Energy Ventures owns solar panels with a total of 189.1231.3 MW of capacity throughout New JersyJersey and owns 79.5 acres of land in Vineland, New Jersey.
Clean Energy Ventures is also party to various land lease agreements and easements, which allow for the installation, operation and maintenance of wind turbines, associated electric collection facilities, substations, operation and maintenance buildings and access to the various properties. Clean Energy Ventures has a total of 126.6116.9 MW of wind capacity and owns wind projects in Two Dot, Montana, Carroll County, Iowa, Rush County, Kansas, Carbon County, Wyoming and Somerset County, Pennsylvania. In addition to the lease agreements and easements, Clean Energy Ventures owns 1.8 acres and 7.1 acres of land for its Carroll County and Rush County wind projects, respectively. Clean Energy Ventures also owns a building on .16 acres in Rush County, Kansas that is used for operation and maintenance purposes.
Clean Energy Ventures leases office space in Wall Township, New Jersey.
Energy Services Segment
As of September 30, 2017,2018, Energy Services leases office space in Wall Township, New Jersey, Houston, Texas, Charlotte, North Carolina and Allentown, Pennsylvania.
Midstream Segment
As of September 30, 2017,2018, Steckman Ridge owned and/or leased storage rights on approximately 6,300 acres of land in Bedford County, Pennsylvania, with a FERC-regulated natural gas storage facility with up to 12 Bcf of working gas capacity. Equipment on the property includes a compressor station, gathering pipelines and pipeline interconnections. As of September 30, 2017,2018, PennEast owned 74 acres of land in Carbon County, Pennsylvania and 58.7 acres of land in Mercer County, New Jersey.
New Jersey Resources Corporation
Part I
ITEM 2. PROPERTIES (Continued)
All Other Business Operations
As of September 30, 2017,2018, CR&R’s real estate portfolio consisted of 35 acres of undeveloped land in Atlantic County, New Jersey with a net book value of $1.4 million.
NJRHS leases service centers in Dover, Morris CountyNew Jersey and Wall Monmouth County,Township, New Jersey.
Capital Expenditure Program
See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of anticipated fiscal 20182019 and 20192020 capital expenditures, as applicable to the Company’sour reporting segments and business operations.
ITEM 3. LEGAL PROCEEDINGS
Manufactured Gas Plant Remediation
NJNG is responsible for the remedial cleanup of five 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 Administrative Consent Orders or a Memoranda of Agreement with the NJDEP.
NJNG may recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. NJNG currently recoversrecovered approximately $9.4 million annually through it'sits SBC RAC. On November 17, 2017, NJNG filed it'sJuly 25, 2018, the BPU approved NJNG’s annual SBC application requesting a reduction in the RAC, which will decreasedecreased the annual recovery to $7 million, effective September 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, and an increase in the RAC, which will result in an annual increase of approximately $1.4 million, effective April 1, 2018.2019. As of September 30, 2017, $28.52018, $33 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Consolidated Balance Sheets.
NJNG periodically, and at least annually, performs an environmental review of the MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester and Toms River, 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 to remediate and monitor the MGP sites for which it is responsible, including potential liabilities for Natural Resource Damagesnatural 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 $117.6$117.7 million to $205.2$204.1 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of September 30, 2017,2018, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $149$130.8 million on the Consolidated Balance Sheets, based on the most likely amount. This was reduced from $172$149 million in fiscal 2016,2017, due to the completion of remediation work at certain sites and a reduction to the remediation scope at another site. 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.recoveries, if any.
NJNG will continue to seek recovery of MGP-related costs through the RA.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.
LitigationGeneral
We are 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 connection with the conduct of its business, certain of which litigation matters are described in Note 14.13. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements. 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, we 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.
New Jersey Resources Corporation
Part I
ITEM 3. LEGAL PROCEEDINGS
(Continued)
In accordance with applicable accounting guidance, we establish reserves 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. Based upon currently available information, we believe that the results of litigation that is currently pending, taken together, will not have a materially adverse effect on our financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts reserved.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable
ITEM 4A. EXECUTIVE OFFICERS OF THE COMPANY
The Company’s Executive Officers and their age, position and business experience during the past five years are set forth below.
| | | Name | Age | Officer since | Office held during last five years | Age | Officer since | Office held during last five years |
| Laurence M. Downes | 60 | 1986 | Chairman of the Board (September 1996 - present)
President and Chief Executive Officer (July 1995 - present) | 61 | 1986 | Chairman of the Board (September 1996 - present)
Chief Executive Officer (July 1995 - present)
President (July 1995 - September 2018) |
| Patrick J. Migliaccio | 43 | 2013 | Senior Vice President (January 2016 - present)
Chief Financial Officer (January 2016 - present)
Vice President, Finance and Accounting (November 2014 - December 2015)
Treasurer (August 2013 - May 2015)
Corporate Controller (January 2012 - August 2013) | 44 | 2013 | Senior Vice President and Chief Financial Officer (January 2016 - present)
Vice President, Finance and Accounting (November 2014 - December 2015)
Treasurer (August 2013 - May 2015) |
| Stephen D. Westhoven | 49 | 2004 | Executive Vice President and Chief Operating Officer (November 2017 - present)
Senior Vice President and Chief Operating Officer, NJRES and NJRCEV (October 2016 -
October 2017)
Senior Vice President, NJRES (May 2010 - September 2016) | 50 | 2004 | President and Chief Operating Officer (October 2018 - present)
Executive Vice President and Chief Operating Officer (November 2017 - September 2018)
Senior Vice President and Chief Operating Officer, NJRES and NJRCEV (October 2016 -
October 2017)
Senior Vice President, NJRES (May 2010 - September 2016) |
| Kathleen T. Ellis | 64 | 2004 | Executive Vice President, Policy and Strategic Development, NJR (October 2016 - present)
Executive Vice President and Chief Operating Officer, NJNG (February 2008 - September 2016)
Senior Vice President, Corporate Affairs (December 2004 - present) | |
| Glenn C. Lockwood | | 57 | 1990 | Executive Vice President (January 2011 - present)
Chief Financial Officer (September 1995 - December 2015) |
| Amanda E. Mullan | 51 | 2015 | Senior Vice President and Chief Human Resources Officer (January 2017 - present)
Vice President and Chief Human Resources Officer (April 2015 - December 2016)
Senior Vice President of HR, N. America, Willis Group Holdings, a risk management and
insurance intermediary (April 2012 - April 2015) | 52 | 2015 | Senior Vice President and Chief Human Resources Officer (January 2017 - present)
Vice President and Chief Human Resources Officer (April 2015 - December 2016)
Senior Vice President of HR, N. America, Willis Group Holdings, a risk management and
insurance intermediary (April 2012 - April 2015) |
| Jacqueline K. Shea | 53 | 2016 | Vice President and Chief Information Officer (June 2016 - present)
Chief Information Officer, Godiva Chocolatier, a manufacturer of premium fine chocolates and
related products (March 2011 - May 2016) | 54 | 2016 | Vice President and Chief Information Officer (June 2016 - present)
Chief Information Officer, Godiva Chocolatier, a manufacturer of premium fine chocolates and
related products (March 2011 - May 2016) |
| Nancy A. Washington | 53 | 2017 | Senior Vice President and General Counsel (March 2017 - present)
Senior Vice President and Chief Litigation Counsel, CIT Group Inc., a Livingston, NJ-based
financial services firm (September 2010 - March 2017)
| 54 | 2017 | Senior Vice President and General Counsel (March 2017 - present)
Senior Vice President and Chief Litigation Counsel, CIT Group Inc., a Livingston, NJ-based
financial services firm (September 2010 - March 2017)
|
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 September 30, 20172018, NJR had 48,78452,673 holders of record of its common stock.
NJR’s common stock high and low sales prices and dividends paid per share were as follows:
|
| | | | | | |
| | 2017 | 2016 | Dividends Paid |
| | High | Low | High | Low | 2017 | 2016 |
| Fiscal Quarter | | | | | | |
| First | $37.30 | $30.46 | $34.07 | $28.02 | $0.255 | $0.240 |
| Second | $39.95 | $33.70 | $36.85 | $32.32 | $0.255 | $0.240 |
| Third | $43.50 | $38.95 | $38.56 | $33.91 | $0.255 | $0.240 |
| Fourth | $44.30 | $39.50 | $38.92 | $32.27 | $0.255 | $0.240 |
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. The Share Repurchase Planshare repurchase plan allows the Companyus to purchase itsour outstanding shares on the open market or in negotiated transactions, based on market and other conditions. The Company isWe are not required to purchase any specific number of shares and may discontinue or suspend the program at any time. The Share Repurchase Planshare repurchase plan will expire when we have repurchased all shares authorized for repurchase thereunder, unless it is earlier terminated 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, 2017:2018:
|
| | | | | | | | |
| 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 |
7/01/1718 - 7/31/1718 | — | $ | — |
| — |
| | 2,431,053 |
8/01/1718 - 8/31/1718 | — | $ | — |
| — |
| | 2,431,053 |
9/01/1718 - 9/30/1718 | — | $ | — |
| — |
| | 2,431,053 |
| Total | — | $ | — |
| — |
| | 2,431,053 |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA
CONSOLIDATED FINANCIAL STATISTICS
| | | (Thousands, except per share data) | | |
| Fiscal Years Ended September 30, | 2017 | 2016 | 2015 | 2014 | 2013 | 2018 | 2017 | 2016 | 2015 | 2014 |
| SELECTED FINANCIAL DATA | | |
| Operating revenues | $ | 2,268,617 |
| $ | 1,880,905 |
| $ | 2,733,987 |
| $ | 3,738,145 |
| $ | 3,198,068 |
| $ | 2,915,109 |
| $ | 2,268,617 |
| $ | 1,880,905 |
| $ | 2,733,987 |
| $ | 3,738,145 |
|
| Gas purchases | $ | 1,703,767 |
| $ | 1,352,686 |
| $ | 2,085,645 |
| $ | 3,139,525 |
| $ | 2,712,223 |
| $ | 2,275,342 |
| $ | 1,703,767 |
| $ | 1,352,686 |
| $ | 2,085,645 |
| $ | 3,139,525 |
|
| Net income | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
| $ | 114,809 |
| $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Total assets | $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 3,284,357 |
| $ | 3,125,388 |
| $ | 3,001,414 |
| $ | 4,143,664 |
| $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 3,284,357 |
| $ | 3,125,388 |
|
| Common stock equity | $ | 1,236,643 |
| $ | 1,166,591 |
| $ | 1,106,956 |
| $ | 966,166 |
| $ | 887,384 |
| $ | 1,418,978 |
| $ | 1,236,643 |
| $ | 1,166,591 |
| $ | 1,106,956 |
| $ | 966,166 |
|
Long-term debt (1) (2) | $ | 997,080 |
| $ | 1,055,038 |
| $ | 843,595 |
| $ | 598,209 |
| $ | 512,886 |
| $ | 1,180,619 |
| $ | 997,080 |
| $ | 1,055,038 |
| $ | 843,595 |
| $ | 598,209 |
|
| | | |
| COMMON STOCK DATA | | |
| Earnings per share-basic | $1.53 | $1.53 | $2.12 | $1.69 | $1.38 | $2.66 | $1.53 | $2.12 | $1.69 |
| Earnings per share-diluted | $1.52 | $1.52 | $2.10 | $1.67 | $1.37 | $2.64 | $1.52 | $2.10 | $1.67 |
| Dividends declared per share | $1.038 | $0.975 | $0.915 | $0.855 | $0.810 | $1.11 | $1.038 | $0.975 | $0.915 | $0.855 |
| | | |
| NON-GAAP RECONCILIATION | | |
| Net income | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
| $ | 114,809 |
| $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Add: | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (11,241 | ) | 46,883 |
| (38,681 | ) | 28,534 |
| (9,418 | ) | |
| Unrealized loss (gain) on derivative instruments and related transactions | | 26,770 |
| (11,241 | ) | 46,883 |
| (38,681 | ) | 28,534 |
|
| Tax effect | 4,062 |
| (17,018 | ) | 14,391 |
| (10,492 | ) | 3,462 |
| (4,512 | ) | 4,062 |
| (17,018 | ) | 14,391 |
| (10,492 | ) |
| Effects of economic hedging related to natural gas inventory | 38,470 |
| (36,816 | ) | (8,225 | ) | 26,639 |
| 7,635 |
| (22,570 | ) | 38,470 |
| (36,816 | ) | (8,225 | ) | 26,639 |
|
| Tax effect | (13,964 | ) | 13,364 |
| 3,058 |
| (9,794 | ) | (2,807 | ) | 7,362 |
| (13,964 | ) | 13,364 |
| 3,058 |
| (9,794 | ) |
Net financial earnings (3) | $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 176,857 |
| $ | 113,681 |
| $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 176,857 |
|
| | | |
| Basic earnings per share | $1.53 | $1.53 | $2.12 | $1.69 | $1.38 | $2.66 | $1.53 | $2.12 | $1.69 |
| Add: | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (0.13 | ) | 0.55 |
| (0.45 | ) | 0.34 |
| (0.11 | ) | |
| Unrealized loss (gain) on derivative instruments and related transactions | | 0.31 |
| (0.13 | ) | 0.55 |
| (0.45 | ) | 0.34 |
|
| Tax effect | 0.05 |
| (0.20 | ) | 0.17 |
| (0.13 | ) | 0.04 |
| (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.13 | ) |
| Effects of economic hedging related to natural gas inventory | 0.45 |
| (0.43 | ) | (0.10 | ) | 0.32 |
| 0.09 |
| (0.26 | ) | 0.45 |
| (0.43 | ) | (0.10 | ) | 0.32 |
|
| Tax effect | (0.17 | ) | 0.16 |
| 0.04 |
| (0.12 | ) | (0.04 | ) | 0.08 |
| (0.17 | ) | 0.16 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-basic (3) | $1.73 | $1.61 | $1.78 | $2.10 | $1.36 | $2.74 | $1.73 | $1.61 | $1.78 | $2.10 |
| | | |
| Diluted earnings per share | $1.52 | $1.52 | $2.10 | $1.67 | $1.37 | $2.64 | $1.52 | $2.10 | $1.67 |
| Add: | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (0.13 | ) | 0.54 |
| (0.45 | ) | 0.34 |
| (0.11 | ) | |
| Unrealized loss (gain) on derivative instruments and related transactions | | 0.30 |
| (0.13 | ) | 0.54 |
| (0.45 | ) | 0.34 |
|
| Tax effect | 0.05 |
| (0.20 | ) | 0.17 |
| (0.12 | ) | 0.04 |
| (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.12 | ) |
| Effects of economic hedging related to natural gas inventory | 0.44 |
| (0.42 | ) | (0.10 | ) | 0.31 |
| 0.09 |
| (0.25 | ) | 0.44 |
| (0.42 | ) | (0.10 | ) | 0.31 |
|
| Tax effect | (0.17 | ) | 0.15 |
| 0.04 |
| (0.12 | ) | (0.03 | ) | 0.08 |
| (0.17 | ) | 0.15 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-diluted (3) | $1.71 | $1.59 | $1.76 | $2.08 | $1.36 | $2.72 | $1.71 | $1.59 | $1.76 | $2.08 |
| |
| (1) | Includes long-term capital leases of $26.4 million, $28.9 million, $30.7 million, $35.7 million $40.4 million and $43$40.4 million, respectively. |
| |
| (2) | Includes long-term solar asset financing obligation of $28.2$89.8 million and $28.2 million in fiscal 2017.2018 and 2017, respectively. |
| |
| (3) | NFE is a non-GAAP financial measure that eliminates the timing differences surrounding the recognition of certain derivative gains or losses, to effectively match the earnings effects of economic hedges associated with the physical sale or purchase of gas and, therefore, eliminate the impact of volatility to GAAP earnings associated with the related derivative instruments. For further discussion of this financial measure, see the Energy Services segment in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA (Continued)
NJNG OPERATING STATISTICS
| | | Fiscal Years Ended September 30, | 2017 | 2016 | 2015 | 2014 | 2013 | 2018 | 2017 | 2016 | 2015 | 2014 |
Operating revenues ($ in thousands) | | |
| Residential | $ | 395,315 |
| $ | 345,597 |
| $ | 466,464 |
| $ | 469,831 |
| $ | 467,269 |
| $ | 441,486 |
| $ | 395,315 |
| $ | 345,597 |
| $ | 466,464 |
| $ | 469,831 |
|
| Commercial, industrial and other | 98,777 |
| 80,994 |
| 106,505 |
| 110,740 |
| 99,736 |
| 95,351 |
| 98,777 |
| 80,994 |
| 106,505 |
| 110,740 |
|
| Firm transportation | 73,206 |
| 69,696 |
| 77,974 |
| 86,131 |
| 73,745 |
| 65,256 |
| 73,206 |
| 69,696 |
| 77,974 |
| 86,131 |
|
| Total residential and commercial | 567,298 |
| 496,287 |
| 650,943 |
| 666,702 |
| 640,750 |
| 602,093 |
| 567,298 |
| 496,287 |
| 650,943 |
| 666,702 |
|
| Interruptible | 7,970 |
| 8,867 |
| 10,049 |
| 9,384 |
| 9,066 |
| 7,522 |
| 7,970 |
| 8,867 |
| 10,049 |
| 9,384 |
|
| Total system | 575,268 |
| 505,154 |
| 660,992 |
| 676,086 |
| 649,816 |
| 609,615 |
| 575,268 |
| 505,154 |
| 660,992 |
| 676,086 |
|
| BGSS incentive programs | 120,369 |
| 89,192 |
| 120,978 |
| 143,329 |
| 138,171 |
| 122,250 |
| 120,369 |
| 89,192 |
| 120,978 |
| 143,329 |
|
| Total operating revenues | $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 819,415 |
| $ | 787,987 |
| $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 819,415 |
|
| Throughput (Bcf) | | |
| Residential | 40.7 |
| 36.9 |
| 45.9 |
| 43.1 |
| 38.3 |
| 45.5 |
| 40.7 |
| 36.9 |
| 45.9 |
| 43.1 |
|
| Commercial, industrial and other | 8.7 |
| 7.3 |
| 9.6 |
| 8.2 |
| 7.5 |
| 8.9 |
| 8.7 |
| 7.3 |
| 9.6 |
| 8.2 |
|
| Firm transportation | 14.4 |
| 14.1 |
| 16.0 |
| 17.7 |
| 15.2 |
| 15.5 |
| 14.4 |
| 14.1 |
| 16.0 |
| 17.7 |
|
| Total residential and commercial | 63.8 |
| 58.3 |
| 71.5 |
| 69.0 |
| 61.0 |
| 69.9 |
| 63.8 |
| 58.3 |
| 71.5 |
| 69.0 |
|
| Interruptible | 55.0 |
| 61.5 |
| 47.1 |
| 10.5 |
| 10.9 |
| 46.2 |
| 55 |
| 61.5 |
| 47.1 |
| 10.5 |
|
| Total system | 118.8 |
| 119.8 |
| 118.6 |
| 79.5 |
| 71.9 |
| 116.1 |
| 118.8 |
| 119.8 |
| 118.6 |
| 79.5 |
|
| BGSS incentive programs | 178.4 |
| 216.7 |
| 222.4 |
| 180.8 |
| 141.5 |
| 150.2 |
| 178.4 |
| 216.7 |
| 222.4 |
| 180.8 |
|
| Total throughput | 297.2 |
| 336.5 |
| 341.0 |
| 260.3 |
| 213.4 |
| 266.3 |
| 297.2 |
| 336.5 |
| 341.0 |
| 260.3 |
|
| Customers at year-end | | |
| Residential | 460,013 |
| 448,273 |
| 437,979 |
| 422,742 |
| 408,399 |
| 474,495 |
| 460,013 |
| 448,273 |
| 437,979 |
| 422,742 |
|
| Commercial, industrial and other | 26,947 |
| 26,218 |
| 25,541 |
| 24,684 |
| 24,302 |
| 28,037 |
| 26,947 |
| 26,218 |
| 25,541 |
| 24,684 |
|
| Firm transportation | 42,790 |
| 46,608 |
| 48,673 |
| 56,777 |
| 64,651 |
| 36,126 |
| 42,790 |
| 46,608 |
| 48,673 |
| 56,777 |
|
| Total residential and commercial | 529,750 |
| 521,099 |
| 512,193 |
| 504,203 |
| 497,352 |
| 538,658 |
| 529,750 |
| 521,099 |
| 512,193 |
| 504,203 |
|
| Interruptible | 33 |
| 34 |
| 35 |
| 37 |
| 41 |
| 31 |
| 33 |
| 34 |
| 35 |
| 37 |
|
| BGSS incentive programs | 27 |
| 30 |
| 24 |
| 34 |
| 38 |
| 28 |
| 27 |
| 30 |
| 24 |
| 34 |
|
| Total customers at year-end | 529,810 |
| 521,163 |
| 512,252 |
| 504,274 |
| 497,431 |
| 538,717 |
| 529,810 |
| 521,163 |
| 512,252 |
| 504,274 |
|
Interest coverage ratio (1) | 7.96 |
| 8.97 |
| 9.57 |
| 10.24 |
| 10.82 |
| 6.35 |
| 7.96 |
| 8.97 |
| 9.57 |
| 10.24 |
|
| Average therm use per customer | | | | | | |
| Residential | 885 |
| 824 |
| 1,049 |
| 1,020 |
| 937 |
| 959 |
| 885 |
| 824 |
| 1,049 |
| 1,020 |
|
| Commercial, industrial and other | 11,183 |
| 11,378 |
| 9,799 |
| 4,466 |
| 3,773 |
| 10,992 |
| 11,183 |
| 11,378 |
| 9,799 |
| 4,466 |
|
| Degree days | 4,129 |
| 3,867 |
| 5,015 |
| 5,080 |
| 4,664 |
| 4,537 |
| 4,129 |
| 3,867 |
| 5,015 |
| 5,080 |
|
Weather as a percent of normal (2) | 90.0 | % | 82.5 | % | 108.3 | % | 109.6 | % | 99.9 | % | 99.5 | % | 90.0 | % | 82.5 | % | 108.3 | % | 109.6 | % |
| Number of employees | 680 |
| 670 |
| 649 |
| 626 |
| 611 |
| 686 |
| 680 |
| 670 |
| 649 |
| 626 |
|
| |
| (1) | NJNG’s income from operations divided by interest expense. |
| |
| (2) | Normal heating degree days are based on a 20-year average, calculated based upon three reference areas representative of NJNG’s service territory. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
Forward-looking and Cautionary Statements
From time to time, we may make statements that constitute “forward-looking statements” within the meaning of the “safe-harbor” provisions of Section 27A of the Securities and Exchange Act of 1933, as amended, Section 21E of the Securities and Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995. These statements are based on our then-current expectations and are subject to a number of risks and uncertainties that could cause actual results to differ materially from those addressed in the forward-looking statements. Information concerning forward-looking statements is set forth on page 3 of this annual report and is incorporated herein. A detailed discussion of risk and uncertainties that could cause actual results to differ materially from such forward-looking statements is included in Item 1A. Risk Factors and are incorporated herein. We undertake no obligation to update or revise publicly any forward-looking statement, whether as a result of new information, future events or otherwise.
Critical Accounting Policies
We prepare our financial statements in accordance with GAAP. Application of these accounting principles requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingencies during the reporting period. We regularly evaluate our estimates, including those related to the calculation of the fair value of derivative instruments, regulatory assets, income taxes, pension and postemployment benefits other than pensions asset retirement obligations and contingencies related to environmental matters and litigation. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.
Regulatory Accounting
NJNG maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and recognizes the impact of regulatory decisions on its financial statements. As a result of the ratemaking process, NJNG is required to apply the accounting principles in ASC 980, Regulated Operations, which differ in certain respects from those applied by unregulated businesses. Specifically, NJNG records regulatory assets when it is probable that certain operating costs will be recoverable from customers in future periods and records regulatory liabilities associated with probable future obligations to customers.
NJNG’s BGSS requires it to project its annual natural gas costs and provides the ability, subject to BPU approval, to recover or refund the difference, if any, of such actual costs compared with the projected costs included in prices through a BGSS charge to customers. Any underrecovery or overrecovery is recorded as a regulatory asset or liability on the Consolidated Balance Sheets and reflected in the BGSS charge to customers in subsequent years.
As recovery of regulatory assets is subject to BPU approval, if there are any changes in future regulatory positions, which indicate that indicate recovery of all or a portion of a regulatory asset is not probable, the related cost would be charged to income in the period of such determination. In September 2016,
Impairment of Long-lived assets
Property, plant and equipment and intangible assets are reviewed periodically when changes in facts and circumstances indicate that the BPU approved an increase in base tariff rates in thecarrying amount of $45 million, effective October 2016. There were no changesan asset may not be fully recoverable in accordance with the appropriate accounting guidance. When an impairment indicator is present, the Company determines if the carrying value of the asset is recoverable by comparing it to the amounts NJNG has recognized in regulatory assets as a resultexpected undiscounted future cash flows. If carrying value of the settlementasset 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 base rate petition.fair value.
Equity method investments are reviewed periodically when changes in facts and circumstances indicate that the current fair value may be less than the asset’s carrying amount and record an impairment charge in an amount equal to the excess of the carrying value of the asset over its fair value if the decline is other than temporary.
Derivative Instruments
We record our derivative instruments held as assets and liabilities at fair value on the Consolidated Balance Sheets. In addition, since we choose not to designate any of our physical and financial natural gas commodity derivatives as accounting hedges, changes in the fair value of Energy Services’ commodity derivatives are recognized in earnings, as they occur, as a component of operating revenues or gas purchases on the Consolidated Statements of Operations. Changes in the fair value of foreign exchange contracts are recognized in 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 and/or a combination of those items. Energy Services’ portfolio is valued using the most current and reasonable market information. If the price underlying a physical commodity transaction does not represent a visible and liquid market, Energy Services may utilize additional published pipeline tariff information and/or other services to determine an equivalent market price. As of September 30, 2017,2018, fair value of its derivative assets and liabilities reported on the Consolidated Balance Sheets that is based on such pricing is considered immaterial.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Should there be a significant change in the underlying market prices or pricing assumptions, Energy Services may experience a significant impact on its financial position, results of operations and cash flows. Refer to Item 7A. Quantitative and Qualitative Disclosures About Market Risks for a sensitivity analysis related to the impact to derivative fair values resulting from changes in commodity prices. The valuation methods we use to determine fair values remained consistent for fiscal 2018, 2017 2016 and 2015.2016. 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.
Clean Energy Ventures hedges certain of its expected production of SRECs through forward and futures contracts. Clean Energy Ventures intends to physically deliver all SRECs it sells and recognizes SREC revenue as operating revenue on the Consolidated Statements of Operations upon delivery of the underlying SREC.
We have not designated any derivatives as fair value or cash flow hedges as of September 30, 20172018 and 2016.
Business Combinations
We account for business combinations by applying the acquisition method of accounting. Identifiable assets acquired and liabilities assumed are measured separately at their fair value as of the acquisition date and associated transactions costs are expensed as incurred.
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, terminal values, 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. Terminal values are based on the expected life of assets acquired, forecasted life cycles and expected cash flows over that period. Our valuation of an acquired business is based on available information at the acquisition date and assumptions that we believe are reasonable, however a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date. See Note 3. Acquisition for information related to our acquisition of a gas marketing business on July 27, 2017.
Income Taxes and Credits
The determination of our provision for income taxes requires significant judgment, the use of estimates and the interpretation and application of complex tax laws. Significant judgmentJudgment is required in assessing the timingdeductibility and amountsrecoverability of deductible andcertain taxable items. We use the asset and liability method to determine and record deferred tax assets, representing future tax benefits, and deferred tax liabilities, representing future taxes payable, resulting from the differences between the financial reporting amount and the corresponding tax basis of the assets and liabilities using the enacted rates expected to be in effect at the time the differences are 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. We had net deferred tax liabilities of $506.3 million and $464.6 million, and a valuation allowance of approximately $1 million and $262,000 related to certain deferred state tax assets, as of September 30, 2017 and 2016, respectively. Any significant changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a material change to earnings and cash flows. For a more detailed description of Income Taxes see Note 13.12. Income Taxes in the accompanying Consolidated Financial Statements.
For state income tax and other taxes, estimates and judgments are required with respect to the apportionment among the various jurisdictions. In addition, we operate within multiple tax jurisdictions and are subject to audits in these jurisdictions. These audits can involve complex issues, which may require an extended period of time to resolve. We maintain a liability for the estimate of potential income tax exposure and, in our opinion, adequate provisions for income taxes have been made for all years reported. Any significant changes to the estimates and judgments with respect to the apportionment factor could result in a material change to earnings and cash flows.
Occasionally, the federal and state taxing authorities determine that it is necessary to make certain changes to the income tax laws. These changes may include but are not limited to changes in the tax rates and/or the treatment of certain items of income or expense. Accounting guidance requires that the Company reflect the effect of tax laws or tax rates at the date of enactment. Additionally, the Company is required to re-measure its deferred tax assets and liabilities as of the date of enactment. For non-regulated entities, the effect of changes in tax rates and/or tax laws are required to be included in income from continuing operations for the period that includes the enactment date. For regulated entities, if as the result of an action by a regulator it is probable that the future increase or decrease in taxes payable for items such as changes in tax law or rates will be recovered from or returned to customers through future rates, an asset or liability shall be recognized for that probable increase or decrease in future revenue. Additionally, accounting guidance also requires that regulatory liabilities/assets be considered a temporary difference for which a deferred tax asset/liability shall be recognized. As a result, NJNG grossed up its regulatory liability to reflect the required accounting for the tax effects of the revaluation.
Concurrent with the enactment of the current tax reform legislation, the SEC issued Staff Accounting Bulletin No. 118, which lays out an approach that a registrant may follow to comply with the enactment period accounting requirements. Accordingly, registrants can have up to 12 months from the enactment date to complete the accounting for some or all of the income tax effects triggered by the enactment of the new law. Registrants need to determine and use “reasonable estimates” for some or all of the expected effects beginning with the one-year measurement period. The accounting must be finalized no later than 12 months from the enactment date. If reasonable estimates cannot be determined, the accounting should continue to be based on the old law until reasonable estimates can be determined in a subsequent period. As of September 30, 2018, our accounting for the income tax effects of the Tax Act is considered complete.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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. We have no reason to believe that we have any future obligations associated with unrecognized tax benefits,benefits; therefore, as of September 30, 20172018 and 2016,2017, we have not recorded any liabilities related to uncertain tax positions. 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.
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. For our unregulated subsidiaries, we recognize ITCs as a reduction to income tax expense when the property is placed in service.
To the extent that the Company invests in property that qualifies for PTCs, the PTC is recognized as a reduction to current federal income tax expense as the PTCs are generated through the production activities of the assets.
Changes to the federal statutes related to ITCs, and PTCs, which have the effect of reducing or eliminating the credits, could have a negative impact on earnings and cash flows.
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. As of September 30, 2017, NJNG estimated these expenditures will range from approximately $117.6 million to $205.2 million. NJNG’s estimate of these liabilities is developed from then currentlythen-currently available facts, existing technology and current laws and regulations.
In accordance with accounting standards for contingencies, NJNG’s policy is to record a liability when it is probable that the cost will be incurred and can be reasonably estimated. NJNG will determine a range of liabilities and will record the most likely amount. If no point within the range is more likely than any other, NJNG will accrue the lower end of the range. Since we believe that recovery of these expenditures, as well as related litigation costs, is possible through the regulatory process, we have recorded a regulatory asset corresponding to the related accrued liability. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $149 million on the Consolidated Balance Sheets, which is based on the most likely amount. This was reduced from $172 million in fiscal 2016, due to the completion of remediation work at certain sites and a reduction to the remediation scope of work at another site.
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. As of September 30, 2017 and 2016, $28.5 million and $19.6 million of previouslyPreviously incurred remediation costs, net of recoveries from customers and insurance proceeds received are included in regulatory assets on the Consolidated Balance Sheets, respectively.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 13. Commitments and Contingent Liabilities for more details.
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 impacted by actual employee demographics including age, compensation levels and employment periods, the level of contributions made to the plans, changes in long-term interest rates and the return on plan assets. Changes made to the provisions of the plans or healthcare legislation may also impact current and future postemployment employee benefit costs. Postemployment employee benefit costs may also be significantly affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets, changes in mortality tables, health care cost trends and discount rates used in determining the PBO. In determining the PBO and cost amounts, assumptions can change from period to period and could result in material changes to net postemployment employee benefit periodic costs and the related liability recognized by us.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Our postemployment employee benefit plan assets consist primarily of U.S. equity securities, international equity securities and fixed-income investments, with a targeted allocation of 4034 percent, 2017 percent and 4041 percent, respectively. Fluctuations in actual market returns, as well as changes in interest rates, may result in increased or decreased postemployment employee benefit costs in future periods. Postemployment employee benefit expenses are included in O&M expense on the Consolidated Statements of Operations.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The following is a summary of a sensitivity analysis for each actuarial assumption:
| | | Pension Plans | | | | | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (38,398 | ) | | $ | (3,875 | ) | | 1.00 |
| % | | $ | (37,153 | ) | | $ | (4,095 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 48,110 |
| | $ | 4,720 |
| | (1.00 | ) | % | | $ | 46,432 |
| | $ | 4,756 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | $ | (2,493 | ) | | 1.00 |
| % | | n/a | | $ | (2,619 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | $ | 2,493 |
| | (1.00 | ) | % | | n/a | | $ | 2,619 |
| |
| | | Other Postemployment Benefits | | | | | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (25,977 | ) | | $ | (2,447 | ) | | 1.00 |
| % | | $ | (28,595 | ) | | $ | (2,728 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 33,412 |
| | $ | 3,072 |
| | (1.00 | ) | % | | $ | 36,736 |
| | $ | 3,406 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | $ | (615 | ) | | 1.00 |
| % | | n/a | | $ | (713 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | $ | 615 |
| | (1.00 | ) | % | | n/a | | $ | 714 |
| |
| | | | | | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Health care cost trend rate | 1.00 |
| % | | $ | 32,019 |
| | $ | 4,353 |
| | 1.00 |
| % | | $ | 36,260 |
| | $ | 3,838 |
| |
| Health care cost trend rate | (1.00 | ) | % | | $ | (25,466 | ) | | $ | (3,624 | ) | | (1.00 | ) | % | | $ | (28,743 | ) | | $ | (2,991 | ) | |
On October 1, 2016, we changed our approach used to measure the service and interest cost components of itsour net periodic benefit costs. Previously, the Companywe estimated service cost and interest cost based on a single weighted-average discount rate from the yield curve used to measure itsour projected benefit obligation. Effective October 1, 2016, weWe determine our service and interest cost based upon duration specificduration-specific spot rates that are aligned to each year’s future benefit payments. Under the new approach, net periodic benefit costs will be lower during periods of low interest rates and upward-sloping yield curves. Conversely, in a downward sloping-yielddownward-sloping yield curve environment, costs could increase. Refer to Note 11.10. Employee Benefit Plans in the accompanying Consolidated Financial Statements for further discussion of our change in method.
Asset Retirement Obligations
We recognize AROs related to the costs associated with cutting and capping NJNG’s main and service gas distribution mains, which is required by New Jersey law when taking such gas distribution mains out of service. We also recognize AROs associated with Clean Energy Ventures’ solar and wind assets when there are decommissioning provisions in lease agreements that require removal of the asset at the end of the lease term.
AROs are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on our Consolidated Statements of Operations. Prior to October 1, 2016, accretion amounts associated with NJNG’s ARO were not reflected as an expense, but rather were deferred as a regulatory asset and netted against NJNG’s regulatory liabilities for presentation purposes. Through NJNG’s new base rates settlement, effective October 1, 2016, accretion is recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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 our AROs 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, we develop possible retirement scenarios and assign probabilities based on management’s reasonable judgment and knowledge of industry practice. Accordingly, AROs are subject to change.
Recently Issued Accounting StandardsNatural Gas Distribution Segment
NJNG owns approximately 7,252 miles of distribution main, 7,525 miles of service main, 227 miles of transmission main and 557,000 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.
NJNG owns four service centers located in Rockaway Township, Morris County; Atlantic Highlands and Wall Township, Monmouth County; and Lakewood, Ocean County. These service centers house storerooms, garages, gas distribution and administrative offices. NJNG leases its headquarters and customer service facilities in Wall Township, Monmouth County; a customer service office in Asbury Park, Monmouth County; and a service center in Manahawkin, Ocean County. These customer service offices support customer contact, marketing, economic development and other functions.
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 $672 million as of September 30, 2018. In addition, under the terms of the Mortgage Indenture, NJNG could have issued up to $1 billion of additional first mortgage bonds as of September 30, 2018.
Clean Energy Ventures Segment
Clean Energy Ventures 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. In addition to the lease agreements and easements, Clean Energy Ventures owns solar panels with a total of 231.3 MW of capacity throughout New Jersey and owns 79.5 acres of land in Vineland, New Jersey.
Clean Energy Ventures is also party to various land lease agreements and easements, which allow for the installation, operation and maintenance of wind turbines, associated electric collection facilities, substations, operation and maintenance buildings and access to the various properties. Clean Energy Ventures has a total of 116.9 MW of wind capacity and owns wind projects in Carroll County, Iowa, Rush County, Kansas, Carbon County, Wyoming and Somerset County, Pennsylvania. In addition to the lease agreements and easements, Clean Energy Ventures owns 1.8 acres and 7.1 acres of land for its Carroll County and Rush County wind projects, respectively. Clean Energy Ventures also owns a building on .16 acres in Rush County, Kansas that is used for operation and maintenance purposes.
Clean Energy Ventures leases office space in Wall Township, New Jersey.
Energy Services Segment
As of September 30, 2018, Energy Services leases office space in Wall Township, New Jersey, Houston, Texas, Charlotte, North Carolina and Allentown, Pennsylvania.
Midstream Segment
As of September 30, 2018, Steckman Ridge owned and/or leased storage rights on approximately 6,300 acres of land in Bedford County, Pennsylvania, with a FERC-regulated natural gas storage facility with up to 12 Bcf of working gas capacity. Equipment on the property includes a compressor station, gathering pipelines and pipeline interconnections. As of September 30, 2018, PennEast owned 74 acres of land in Carbon County, Pennsylvania and 58.7 acres of land in Mercer County, New Jersey.
New Jersey Resources Corporation
Part I
ITEM 2. PROPERTIES (Continued)
All Other Business Operations
As of September 30, 2018, CR&R’s real estate portfolio consisted of 35 acres of undeveloped land in Atlantic County, New Jersey with a net book value of $1.4 million.
NJRHS leases service centers in Dover, New Jersey and Wall Township, New Jersey.
Capital Expenditure Program
ReferSee Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of anticipated fiscal 2019 and 2020 capital expenditures, as applicable to our reporting segments and business operations.
ITEM 3. LEGAL PROCEEDINGS
Manufactured Gas Plant Remediation
NJNG is responsible for the remedial cleanup of five 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 Administrative Consent Orders or a Memoranda of Agreement with the NJDEP.
NJNG may recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. NJNG recovered approximately $9.4 million annually through its SBC RAC. On July 25, 2018, the BPU approved NJNG’s annual SBC application requesting a reduction in the RAC, which decreased the annual recovery to $7 million, effective September 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, and an increase in the RAC, which will result in an annual increase of approximately $1.4 million, effective April 1, 2019. As of September 30, 2018, $33 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Consolidated Balance Sheets.
NJNG periodically, and at least annually, performs an environmental review of MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester and Toms River, 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 to remediate and monitor the 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 $117.7 million to $204.1 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of September 30, 2018, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $130.8 million on the Consolidated Balance Sheets, based on the most likely amount. This was reduced from $149 million in fiscal 2017, due to the completion of remediation work at certain sites and a reduction to the remediation scope at another site. 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 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
We are 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 connection with the conduct of business, certain of which litigation matters are described in Note 2. Summary of Significant Accounting Policies13. Commitments and Contingent Liabilities in the accompanying Consolidated Financial StatementsStatements. 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, we 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.
New Jersey Resources Corporation
Part I
ITEM 3. LEGAL PROCEEDINGS (Continued)
In accordance with applicable accounting guidance, we establish reserves for discussionlitigation for those matters that present loss contingencies as to which it is both probable that a loss will be incurred and the amount of recently issued accounting standards.such loss can be reasonably estimated. Based upon currently available information, we believe that the results of litigation that is currently pending, taken together, will not have a materially adverse effect on our financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts reserved.
ManagementITEM 4. MINE SAFETY DISCLOSURES
Not applicable
ITEM ’4A. EXECUTIVE OFFICERS OF THE COMPANY
The Company’s Executive Officers and their age, position and business experience during the past five years are set forth below.
|
| | | |
| Name | Age | Officer since | Office held during last five years |
| Laurence M. Downes | 61 | 1986 | Chairman of the Board (September 1996 - present)
Chief Executive Officer (July 1995 - present)
President (July 1995 - September 2018) |
| Patrick J. Migliaccio | 44 | 2013 | Senior Vice President and Chief Financial Officer (January 2016 - present)
Vice President, Finance and Accounting (November 2014 - December 2015)
Treasurer (August 2013 - May 2015) |
| Stephen D. Westhoven | 50 | 2004 | President and Chief Operating Officer (October 2018 - present)
Executive Vice President and Chief Operating Officer (November 2017 - September 2018)
Senior Vice President and Chief Operating Officer, NJRES and NJRCEV (October 2016 -
October 2017)
Senior Vice President, NJRES (May 2010 - September 2016) |
| Glenn C. Lockwood | 57 | 1990 | Executive Vice President (January 2011 - present)
Chief Financial Officer (September 1995 - December 2015) |
| Amanda E. Mullan | 52 | 2015 | Senior Vice President and Chief Human Resources Officer (January 2017 - present)
Vice President and Chief Human Resources Officer (April 2015 - December 2016)
Senior Vice President of HR, N. America, Willis Group Holdings, a risk management and
insurance intermediary (April 2012 - April 2015) |
| Jacqueline K. Shea | 54 | 2016 | Vice President and Chief Information Officer (June 2016 - present)
Chief Information Officer, Godiva Chocolatier, a manufacturer of premium fine chocolates and
related products (March 2011 - May 2016) |
| Nancy A. Washington | 54 | 2017 | Senior Vice President and General Counsel (March 2017 - present)
Senior Vice President and Chief Litigation Counsel, CIT Group Inc., a Livingston, NJ-based
financial services firm (September 2010 - March 2017)
|
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 s OverviewSeptember 30, 2018, NJR had 52,673 holders of record of its common stock.
ConsolidatedIn 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. 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 earlier terminated 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, 2018:
|
| | | | | | | | |
| 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 |
| 7/01/18 - 7/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 8/01/18 - 8/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 9/01/18 - 9/30/18 | — | $ | — |
| — |
| | 2,431,053 |
| Total | — | $ | — |
| — |
| | 2,431,053 |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA
CONSOLIDATED FINANCIAL STATISTICS
|
| | | | | | | | | | | | | | | |
| (Thousands, except per share data) | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
| SELECTED FINANCIAL DATA | | | | | |
| Operating revenues | $ | 2,915,109 |
| $ | 2,268,617 |
| $ | 1,880,905 |
| $ | 2,733,987 |
| $ | 3,738,145 |
|
| Gas purchases | $ | 2,275,342 |
| $ | 1,703,767 |
| $ | 1,352,686 |
| $ | 2,085,645 |
| $ | 3,139,525 |
|
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Total assets | $ | 4,143,664 |
| $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 3,284,357 |
| $ | 3,125,388 |
|
| Common stock equity | $ | 1,418,978 |
| $ | 1,236,643 |
| $ | 1,166,591 |
| $ | 1,106,956 |
| $ | 966,166 |
|
Long-term debt (1) (2) | $ | 1,180,619 |
| $ | 997,080 |
| $ | 1,055,038 |
| $ | 843,595 |
| $ | 598,209 |
|
| | | | | | |
| COMMON STOCK DATA | | | | | |
| Earnings per share-basic | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Earnings per share-diluted | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Dividends declared per share | $1.11 | $1.038 | $0.975 | $0.915 | $0.855 |
| | | | | | |
| NON-GAAP RECONCILIATION | | | | | |
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,770 |
| (11,241 | ) | 46,883 |
| (38,681 | ) | 28,534 |
|
| Tax effect | (4,512 | ) | 4,062 |
| (17,018 | ) | 14,391 |
| (10,492 | ) |
| Effects of economic hedging related to natural gas inventory | (22,570 | ) | 38,470 |
| (36,816 | ) | (8,225 | ) | 26,639 |
|
| Tax effect | 7,362 |
| (13,964 | ) | 13,364 |
| 3,058 |
| (9,794 | ) |
Net financial earnings (3) | $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 176,857 |
|
| | | | | | |
| Basic earnings per share | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.31 |
| (0.13 | ) | 0.55 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.13 | ) |
| Effects of economic hedging related to natural gas inventory | (0.26 | ) | 0.45 |
| (0.43 | ) | (0.10 | ) | 0.32 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.16 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-basic (3) | $2.74 | $1.73 | $1.61 | $1.78 | $2.10 |
| | | | | | |
| Diluted earnings per share | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.30 |
| (0.13 | ) | 0.54 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.12 | ) |
| Effects of economic hedging related to natural gas inventory | (0.25 | ) | 0.44 |
| (0.42 | ) | (0.10 | ) | 0.31 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.15 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-diluted (3) | $2.72 | $1.71 | $1.59 | $1.76 | $2.08 |
| |
| (1) | Includes long-term capital leases of $26.4 million, $28.9 million, $30.7 million, $35.7 million and $40.4 million, respectively. |
| |
| (2) | Includes long-term solar asset financing obligation of $89.8 million and $28.2 million in fiscal 2018 and 2017, respectively. |
| |
| (3) | NFE is a non-GAAP financial measure that eliminates the timing differences surrounding the recognition of certain derivative gains or losses, to effectively match the earnings effects of economic hedges associated with the physical sale or purchase of gas and, therefore, eliminate the impact of volatility to GAAP earnings associated with the related derivative instruments. For further discussion of this financial measure, see the Energy Services segment in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA (Continued)
NJNG OPERATING STATISTICS
|
| | | | | | | | | | | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
Operating revenues ($ in thousands) | | | | | |
| Residential | $ | 441,486 |
| $ | 395,315 |
| $ | 345,597 |
| $ | 466,464 |
| $ | 469,831 |
|
| Commercial, industrial and other | 95,351 |
| 98,777 |
| 80,994 |
| 106,505 |
| 110,740 |
|
| Firm transportation | 65,256 |
| 73,206 |
| 69,696 |
| 77,974 |
| 86,131 |
|
| Total residential and commercial | 602,093 |
| 567,298 |
| 496,287 |
| 650,943 |
| 666,702 |
|
| Interruptible | 7,522 |
| 7,970 |
| 8,867 |
| 10,049 |
| 9,384 |
|
| Total system | 609,615 |
| 575,268 |
| 505,154 |
| 660,992 |
| 676,086 |
|
| BGSS incentive programs | 122,250 |
| 120,369 |
| 89,192 |
| 120,978 |
| 143,329 |
|
| Total operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 819,415 |
|
| Throughput (Bcf) | | | | | |
| Residential | 45.5 |
| 40.7 |
| 36.9 |
| 45.9 |
| 43.1 |
|
| Commercial, industrial and other | 8.9 |
| 8.7 |
| 7.3 |
| 9.6 |
| 8.2 |
|
| Firm transportation | 15.5 |
| 14.4 |
| 14.1 |
| 16.0 |
| 17.7 |
|
| Total residential and commercial | 69.9 |
| 63.8 |
| 58.3 |
| 71.5 |
| 69.0 |
|
| Interruptible | 46.2 |
| 55 |
| 61.5 |
| 47.1 |
| 10.5 |
|
| Total system | 116.1 |
| 118.8 |
| 119.8 |
| 118.6 |
| 79.5 |
|
| BGSS incentive programs | 150.2 |
| 178.4 |
| 216.7 |
| 222.4 |
| 180.8 |
|
| Total throughput | 266.3 |
| 297.2 |
| 336.5 |
| 341.0 |
| 260.3 |
|
| Customers at year-end | | | | | |
| Residential | 474,495 |
| 460,013 |
| 448,273 |
| 437,979 |
| 422,742 |
|
| Commercial, industrial and other | 28,037 |
| 26,947 |
| 26,218 |
| 25,541 |
| 24,684 |
|
| Firm transportation | 36,126 |
| 42,790 |
| 46,608 |
| 48,673 |
| 56,777 |
|
| Total residential and commercial | 538,658 |
| 529,750 |
| 521,099 |
| 512,193 |
| 504,203 |
|
| Interruptible | 31 |
| 33 |
| 34 |
| 35 |
| 37 |
|
| BGSS incentive programs | 28 |
| 27 |
| 30 |
| 24 |
| 34 |
|
| Total customers at year-end | 538,717 |
| 529,810 |
| 521,163 |
| 512,252 |
| 504,274 |
|
Interest coverage ratio (1) | 6.35 |
| 7.96 |
| 8.97 |
| 9.57 |
| 10.24 |
|
| Average therm use per customer | | | | | |
| Residential | 959 |
| 885 |
| 824 |
| 1,049 |
| 1,020 |
|
| Commercial, industrial and other | 10,992 |
| 11,183 |
| 11,378 |
| 9,799 |
| 4,466 |
|
| Degree days | 4,537 |
| 4,129 |
| 3,867 |
| 5,015 |
| 5,080 |
|
Weather as a percent of normal (2) | 99.5 | % | 90.0 | % | 82.5 | % | 108.3 | % | 109.6 | % |
| Number of employees | 686 |
| 680 |
| 670 |
| 649 |
| 626 |
|
| |
| (1) | NJNG’s income from operations divided by interest expense. |
| |
| (2) | Normal heating degree days are based on a 20-year average, calculated based upon three reference areas representative of NJNG’s service territory. |
New Jersey Resources Corporation
Part II
NJR is an energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in the United States and Canada. In addition, we invest in clean energy projects, midstream assets and provide various repair, sales and installations services. A more detailed description of our organizational structure can be found in ITEM 7. MANAGEMENTItem 1. Business.’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
Critical Accounting Policies
We have four primaryprepare 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 segmentsperiod. We regularly evaluate our estimates, including those related to the calculation of the fair value of derivative instruments, regulatory assets, income taxes, pension and postemployment benefits other than pensions and contingencies related to environmental matters and litigation. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.
Regulatory Accounting
NJNG maintains its accounts in accordance with the FERC Uniform System of Accounts as presentedprescribed by the BPU and recognizes the impact of regulatory decisions on its financial statements. As a result of the ratemaking process, NJNG is required to apply the accounting principles in ASC 980, Regulated Operations, which differ in certain respects from those applied by unregulated businesses. Specifically, NJNG records regulatory assets when it is probable that certain operating costs will be recoverable from customers in future periods and records regulatory liabilities associated with probable future obligations to customers.
NJNG’s BGSS requires it to project its annual natural gas costs and provides the ability, subject to BPU approval, to recover or refund the difference, if any, of such actual costs compared with the projected costs included in prices through a BGSS charge to customers. Any underrecovery or overrecovery is recorded as a regulatory asset or liability on the Consolidated Balance Sheets and reflected in the chart below:BGSS charge to customers in subsequent years.
Impairment of Long-lived assets
Property, plant and equipment and intangible assets are reviewed periodically 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. When an impairment indicator is present, the Company determines if the carrying value of the asset is recoverable by comparing it to the expected undiscounted future cash flows. If 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.
Equity method investments are reviewed periodically when changes in facts and circumstances indicate that the current fair value may be less than the asset’s carrying amount and record an impairment charge in an amount equal to the excess of the carrying value of the asset over its fair value if the decline is other than temporary.
Derivative Instruments
We record our derivative instruments held as assets and liabilities at fair value on the Consolidated Balance Sheets. In addition, since we choose not to designate any of our physical and financial natural gas commodity derivatives as accounting hedges, changes in the fair value of Energy Services’ commodity derivatives are recognized in earnings, as they occur, as a component of operating revenues or gas purchases on the Consolidated Statements of Operations. Changes in the fair value of foreign exchange contracts are recognized in 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 and/or a combination of those items. Energy Services’ portfolio is valued using the most current and reasonable market information. If the price underlying a physical commodity transaction does not represent a visible and liquid market, Energy Services may utilize additional published pipeline tariff information and/or other services to determine an equivalent market price. As of September 30, 2018, fair value of its derivative assets and liabilities reported on the Consolidated Balance Sheets that is based on such pricing is considered immaterial.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
In additionShould there be a significant change in the underlying market prices or pricing assumptions, Energy Services may experience a significant impact on its financial position, results of operations and cash flows. Refer to Item 7A. Quantitative and Qualitative Disclosures About Market Risks for a sensitivity analysis related to the impact to derivative fair values resulting from changes in commodity prices. The valuation methods we use to determine fair values remained consistent for fiscal 2018, 2017 and 2016. We apply a discount to our four reporting segments, we have non-utility operations that either provide corporate support services or do not meetderivative assets to factor in an adjustment associated with the criteriacredit risk of its physical natural gas counterparties and to be treated as a separate reporting segment. These operations, which comprise Home Services and Other, include: appliance repair services, sales and installations at NJRHS; and commercial real estate holdings at CR&R.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.
A summaryGains 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 our consolidated results in net incomethese derivatives is recorded as either a regulatory asset or liability on the Consolidated Balance Sheets.
Clean Energy Ventures hedges certain of its expected production of SRECs through forward and assets by reporting segmentfutures contracts. Clean Energy Ventures intends to physically deliver all SRECs it sells and operations forrecognizes SREC revenue as operating revenue on the fiscal years endedConsolidated 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, is as follows:
|
| | | | | | | | | | | | | | | | | | |
| ($ in thousands) | 2017 | 2016 | 2015 |
| | Net Income | Assets | Net Income | Assets | Net Income | Assets |
| Natural Gas Distribution | $ | 86,930 |
| $ | 2,519,578 |
| $ | 76,104 |
| $ | 2,517,401 |
| $ | 76,287 |
| $ | 2,305,293 |
|
| Clean Energy Ventures | 24,873 |
| 771,340 |
| 28,393 |
| 665,696 |
| 20,101 |
| 504,885 |
|
| Energy Services | 476 |
| 398,277 |
| 14,265 |
| 327,626 |
| 72,044 |
| 260,021 |
|
| Midstream | 12,857 |
| 232,806 |
| 9,406 |
| 186,259 |
| 9,780 |
| 182,007 |
|
| Home Services and Other | 6,811 |
| 114,801 |
| 2,882 |
| 109,487 |
| 3,420 |
| 88,880 |
|
Intercompany (1) | 118 |
| (108,295 | ) | 622 |
| (87,899 | ) | (672 | ) | (56,729 | ) |
| Total | $ | 132,065 |
| $ | 3,928,507 |
| $ | 131,672 |
| $ | 3,718,570 |
| $ | 180,960 |
| $ | 3,284,357 |
|
| |
(1) | Consists of transactions between subsidiaries that are eliminated in consolidation. |
Net Income2018 and 2017.
The primary drivers of the changes noted above, which are described in more detail in the individual segment discussions, are discussed below.Income Taxes and Credits
The increasedetermination of our provision for income taxes requires the use of estimates and the interpretation and application of tax laws. Judgment is required in netassessing the deductibility and recoverability of certain taxable items. We use the asset and liability method to determine and record deferred tax assets, representing future tax benefits, and deferred tax liabilities, representing future taxes payable, resulting from the differences between the financial reporting amount and the corresponding tax basis of the assets and liabilities using the enacted rates expected to be in effect at the time the differences are settled. An offsetting valuation allowance is recorded when it is more likely than not that some or all of the deferred income of $393,000 during fiscal 2017, compared with fiscal 2016, was primarily driven by increased gross margin at our Natural Gas Distribution segment due primarily to increased base rates which were effective October 1, 2016, increased other income at Home Services and Other duetax assets won’t be realized. Any significant changes to the saleestimates and judgments with respect to the interpretations, timing or deductibility could result in a material change to earnings and cash flows. For a more detailed description of availableIncome Taxes see Note 12. Income Taxes in the accompanying Consolidated Financial Statements.
For state income tax and other taxes, estimates and judgments are required with respect to the apportionment among the various jurisdictions. In addition, we operate within multiple tax jurisdictions and are subject to audits in these jurisdictions. These audits can involve complex issues, which may require an extended period of time to resolve. We maintain a liability for sale securitiesthe estimate of potential income tax exposure and, increased equity 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 of affiliates at Midstream.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 increases were partially offset by decreased operating income at Energy Services due primarily to a decrease of $16.4 million relatedchanges may include but are not limited to changes in the valuetax rates and/or the treatment of financial hedgescertain items of income or expense. Accounting guidance requires that the Company reflect the effect of tax laws or tax rates at the date of enactment. Additionally, the Company is required to re-measure its deferred tax assets and liabilities as of the date of enactment. For non-regulated entities, the effect of changes in tax rates and/or tax laws are required to be included in income from continuing operations for the period that includes the enactment date. For regulated entities, if as the result of an action by a decrease at Clean Energy Ventures due primarily to increased depreciation, operating and interest expenses, partially offset by increased revenues and increased PTCs.
Theregulator it is probable that the future increase or decrease in net income of $49.3 million during fiscal 2016, compared with fiscal 2015, was primarily driven by a decrease at Energy Services related to lower operating income due primarily to a decrease of $59.7 million related totaxes payable for items such as changes in tax law or rates will be recovered from or returned to customers through future rates, an asset or liability shall be recognized for that probable increase or decrease in future revenue. Additionally, accounting guidance also requires that regulatory liabilities/assets be considered a temporary difference for which a deferred tax asset/liability shall be recognized. As a result, NJNG grossed up its regulatory liability to reflect the value of financial hedges. The decrease was partially offset by an increase of $8.3 million at Clean Energy Ventures due primarily to operating revenue related to higher SREC and electricity sales, partially offset by increased costs related to depreciation, O&M and interest expense.
Assets
The increase in assets during fiscal 2017, compared with fiscal 2016, was due primarily to additional solar expenditures at Clean Energy Ventures,required accounting for the acquisition of Talen's wholesale and retail energy contract assets at Energy Services, increased PennEast capital contributions and an increase in the market value of our DM Common Units at Midstream, along with additional utility plant expenditures at our Natural Gas Distribution segment. The increase in assets during fiscal 2016, compared with fiscal 2015, was due primarily to additional utility plant expenditures at Natural Gas Distribution and additional solar expenditures at Clean Energy Ventures, as well as increased broker margin and gas in storage at Energy Services.
Non-GAAP Financial Measures
Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. Energy Services economically hedges its natural gas inventory with financial derivative instruments. NFE is a measure of the earnings based on eliminating timing differences surrounding the recognition of certain gains or losses, to effectively match the earningstax effects of the economic hedgesrevaluation.
Concurrent with the physical saleenactment of gas and, therefore, eliminates the impact of volatilitycurrent tax reform legislation, the SEC issued Staff Accounting Bulletin No. 118, which lays out an approach that a registrant may follow to GAAP earnings associatedcomply with the derivative instruments. Toenactment period accounting requirements. Accordingly, registrants can have up to 12 months from the extent we utilize forwards, futures,enactment date to complete the accounting for some or other derivativesall of the income tax effects triggered by the enactment of the new law. Registrants need to hedge forecasted SREC production, unrealized gainsdetermine and losses are also eliminateduse “reasonable estimates” for NFE purposes.
some or all of the expected effects beginning with the one-year measurement period. The accounting must be finalized no later than 12 months from the enactment date. If reasonable estimates cannot be determined, the accounting should continue to be based on the old law until reasonable estimates can be determined in a subsequent period. As of September 30, 2018, our accounting for the income tax effects of the Tax Act is considered complete.
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 areAccounting 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. We have no reason to believe that we have any future obligations associated with unrecognized tax benefits; therefore, as of September 30, 2018 and 2017, we have not recorded any liabilities related to uncertain tax positions. 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.
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 or an alternative to, GAAP and should be considered in addition to, and notregulatory treatment. For our unregulated subsidiaries, we recognize ITCs as a substitutereduction to income tax expense when the property is placed in service.
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.
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 orinvestigation 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 replacementliability 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 comparable GAAP measurerange. Since we believe that recovery of these expenditures, as well as related litigation costs, is possible through the regulatory process, we have recorded a regulatory asset corresponding to the related accrued liability. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Consolidated Balance Sheets, which is based on the most likely amount.
The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations and the ultimate ability of other responsible parties to pay, as well as the potential impact of any litigation and any insurance recoveries. Previously incurred remediation costs, net of recoveries from customers and insurance proceeds received are included in regulatory assets on the Consolidated Balance Sheets.
If there are changes in the regulatory position surrounding these costs, or should actual expenditures vary significantly from estimates in that these costs are disallowed for recovery by the BPU, such costs would be readcharged to income in conjunctionthe period of such determination. See the Legal Proceedings section in Note 13. Commitments and Contingent Liabilities for more details.
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 impacted by actual employee demographics including age, compensation levels and employment periods, the level of contributions made to the plans, changes in long-term interest rates and the return on plan assets. Changes made to the provisions of the plans or healthcare legislation may also impact current and future postemployment employee benefit costs. Postemployment employee benefit costs may also be significantly affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets, changes in mortality tables, health care cost trends and discount rates used in determining the PBO. In determining the PBO and cost amounts, assumptions can change from period to period and could result in material changes to net postemployment employee benefit periodic costs and the related liability recognized by us.
Our postemployment employee benefit plan assets consist primarily of U.S. equity securities, international equity securities and fixed-income investments, with those GAAP results. a targeted allocation of 34 percent, 17 percent and 41 percent, respectively. Fluctuations in actual market returns, as well as changes in interest rates, may result in increased or decreased postemployment employee benefit costs in future periods. Postemployment employee benefit expenses are included in O&M expense on the Consolidated Statements of Operations.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The following is a reconciliationsummary of consolidated net income, the most directly comparable GAAP measure, to NFE:a sensitivity analysis for each actuarial assumption:
|
| | | | | | | | | |
| (Thousands) | 2017 | 2016 | 2015 |
| Net income | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
|
| Add: | | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (11,241 | ) | 46,883 |
| (38,681 | ) |
| Tax effect | 4,062 |
| (17,018 | ) | 14,391 |
|
Effects of economic hedging related to natural gas inventory (1) | 38,470 |
| (36,816 | ) | (8,225 | ) |
| Tax effect | (13,964 | ) | 13,364 |
| 3,058 |
|
| Net financial earnings | $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
|
| | | | |
| Basic earnings per share | $ | 1.53 |
| $ | 1.53 |
| $ | 2.12 |
|
| Add: | | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (0.13 | ) | 0.55 |
| (0.45 | ) |
| Tax effect | 0.05 |
| (0.20 | ) | 0.17 |
|
Effects of economic hedging related to natural gas inventory (1) | 0.45 |
| (0.43 | ) | (0.10 | ) |
| Tax effect | (0.17 | ) | 0.16 |
| 0.04 |
|
| Basic net financial earnings per share | $ | 1.73 |
| $ | 1.61 |
| $ | 1.78 |
|
|
| | | | | | | | | | | | | |
| Pension Plans | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (37,153 | ) | | | $ | (4,095 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 46,432 |
| | | $ | 4,756 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (2,619 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 2,619 |
| |
| |
(1) | Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period. |
NFE by reporting segment and other operations for the fiscal years ended September 30, discussed in more detail within the operating results sections of each segment, is summarized as follows:
|
| | | | | | | | | | | | | | | | | |
| (Thousands) | 2017 | | 2016 | | 2015 |
| Natural Gas Distribution | $ | 86,930 |
| 58 | % | | $ | 76,104 |
| 55 | % | | $ | 76,287 |
| 51 | % |
| Clean Energy Ventures | 24,873 |
| 17 |
| | 28,393 |
| 20 |
| | 20,101 |
| 13 |
|
| Energy Services | 18,554 |
| 12 |
| | 21,934 |
| 16 |
| | 42,122 |
| 28 |
|
| Midstream | 12,857 |
| 9 |
| | 9,406 |
| 7 |
| | 9,780 |
| 6 |
|
| Home Services and Other | 6,811 |
| 4 |
| | 2,882 |
| 2 |
| | 3,420 |
| 2 |
|
Eliminations (1) | (633 | ) | — |
| | (634 | ) | — |
| | (207 | ) | — |
|
| Total | $ | 149,392 |
| 100 | % | | $ | 138,085 |
| 100 | % | | $ | 151,503 |
| 100 | % |
|
| | | | | | | | | | | | | |
| Other Postemployment Benefits | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (28,595 | ) | | | $ | (2,728 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 36,736 |
| | | $ | 3,406 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (713 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 714 |
| |
| | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Health care cost trend rate | 1.00 |
| % | | $ | 36,260 |
| | | $ | 3,838 |
| |
| Health care cost trend rate | (1.00 | ) | % | | $ | (28,743 | ) | | | $ | (2,991 | ) | |
| |
(1) | Consists of transactions between subsidiaries that are eliminated in consolidation.
|
The increaseOn October 1, 2016, we changed our approach used to measure the service and interest cost components of our net periodic benefit costs. Previously, we estimated service cost and interest cost based on a single weighted-average discount rate from the yield curve used to measure our projected benefit obligation. We determine our service and interest cost based upon duration-specific spot rates that are aligned to each year’s future benefit payments. Under the new approach, net periodic benefit costs will be lower during periods of low interest rates and upward-sloping yield curves. Conversely, in NFE during fiscal 2017, compared with fiscal 2016, was due primarilya downward-sloping yield curve environment, costs could increase. Refer to increases atNote 10. Employee Benefit Plans in the accompanying Consolidated Financial Statements for further discussion of our Natural Gas Distribution segment, Midstream and Home Services and Other, as previously discussed, partially offset by lower financial margin at Energy Services due primarily to lower sales volumes and fewer market opportunities and the decrease at Clean Energy Ventures, as previously discussed.change in method.
The decrease in NFE during fiscal 2016, compared with fiscal 2015, was driven primarily by decreased financial margin at Energy Services due primarily to lower volatility and narrower price spreads resulting from the record warm winter weather primarily across the eastern United States, partially offset by lower taxes and O&M, partially offset by higher NFE at Clean Energy Ventures due primarily to increase in SREC and energy sales.
Natural Gas Distribution Segment
NJNG owns approximately 7,252 miles of distribution main, 7,525 miles of service main, 227 miles of transmission main and 557,000 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.
NJNG owns four service centers located in Rockaway Township, Morris County; Atlantic Highlands and Wall Township, Monmouth County; and Lakewood, Ocean County. These service centers house storerooms, garages, gas distribution and administrative offices. NJNG leases its headquarters and customer service facilities in Wall Township, Monmouth County; a customer service office in Asbury Park, Monmouth County; and a service center in Manahawkin, Ocean County. These customer service offices support customer contact, marketing, economic development and other functions.
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 $672 million as of September 30, 2018. In addition, under the terms of the Mortgage Indenture, NJNG could have issued up to $1 billion of additional first mortgage bonds as of September 30, 2018.
Clean Energy Ventures Segment
Clean Energy Ventures 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. In addition to the lease agreements and easements, Clean Energy Ventures owns solar panels with a total of 231.3 MW of capacity throughout New Jersey and owns 79.5 acres of land in Vineland, New Jersey.
Clean Energy Ventures is also party to various land lease agreements and easements, which allow for the installation, operation and maintenance of wind turbines, associated electric collection facilities, substations, operation and maintenance buildings and access to the various properties. Clean Energy Ventures has a total of 116.9 MW of wind capacity and owns wind projects in Carroll County, Iowa, Rush County, Kansas, Carbon County, Wyoming and Somerset County, Pennsylvania. In addition to the lease agreements and easements, Clean Energy Ventures owns 1.8 acres and 7.1 acres of land for its Carroll County and Rush County wind projects, respectively. Clean Energy Ventures also owns a building on .16 acres in Rush County, Kansas that is used for operation and maintenance purposes.
Clean Energy Ventures leases office space in Wall Township, New Jersey.
Energy Services Segment
As of September 30, 2018, Energy Services leases office space in Wall Township, New Jersey, Houston, Texas, Charlotte, North Carolina and Allentown, Pennsylvania.
Midstream Segment
As of September 30, 2018, Steckman Ridge owned and/or leased storage rights on approximately 6,300 acres of land in Bedford County, Pennsylvania, with a FERC-regulated natural gas storage facility with up to 12 Bcf of working gas capacity. Equipment on the property includes a compressor station, gathering pipelines and pipeline interconnections. As of September 30, 2018, PennEast owned 74 acres of land in Carbon County, Pennsylvania and 58.7 acres of land in Mercer County, New Jersey.
New Jersey Resources Corporation
Part I
ITEM 2. PROPERTIES (Continued)
All Other Business Operations
As of September 30, 2018, CR&R’s real estate portfolio consisted of 35 acres of undeveloped land in Atlantic County, New Jersey with a net book value of $1.4 million.
NJRHS leases service centers in Dover, New Jersey and Wall Township, New Jersey.
Capital Expenditure Program
See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of anticipated fiscal 2019 and 2020 capital expenditures, as applicable to our reporting segments and business operations.
ITEM 3. LEGAL PROCEEDINGS
Manufactured Gas Plant Remediation
NJNG is responsible for the remedial cleanup of five 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 Administrative Consent Orders or a Memoranda of Agreement with the NJDEP.
NJNG may recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. NJNG recovered approximately $9.4 million annually through its SBC RAC. On July 25, 2018, the BPU approved NJNG’s annual SBC application requesting a reduction in the RAC, which decreased the annual recovery to $7 million, effective September 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, and an increase in the RAC, which will result in an annual increase of approximately $1.4 million, effective April 1, 2019. As of September 30, 2018, $33 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Consolidated Balance Sheets.
NJNG periodically, and at least annually, performs an environmental review of MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester and Toms River, 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 to remediate and monitor the 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 $117.7 million to $204.1 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of September 30, 2018, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $130.8 million on the Consolidated Balance Sheets, based on the most likely amount. This was reduced from $149 million in fiscal 2017, due to the completion of remediation work at certain sites and a reduction to the remediation scope at another site. 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 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
We are 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 connection with the conduct of business, certain of which litigation matters are described in Note 13. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements. 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, we 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.
New Jersey Resources Corporation
Part I
ITEM 3. LEGAL PROCEEDINGS (Continued)
In accordance with applicable accounting guidance, we establish reserves 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. Based upon currently available information, we believe that the results of litigation that is currently pending, taken together, will not have a materially adverse effect on our financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts reserved.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable
ITEM 4A. EXECUTIVE OFFICERS OF THE COMPANY
The Company’s Executive Officers and their age, position and business experience during the past five years are set forth below.
|
| | | |
| Name | Age | Officer since | Office held during last five years |
| Laurence M. Downes | 61 | 1986 | Chairman of the Board (September 1996 - present)
Chief Executive Officer (July 1995 - present)
President (July 1995 - September 2018) |
| Patrick J. Migliaccio | 44 | 2013 | Senior Vice President and Chief Financial Officer (January 2016 - present)
Vice President, Finance and Accounting (November 2014 - December 2015)
Treasurer (August 2013 - May 2015) |
| Stephen D. Westhoven | 50 | 2004 | President and Chief Operating Officer (October 2018 - present)
Executive Vice President and Chief Operating Officer (November 2017 - September 2018)
Senior Vice President and Chief Operating Officer, NJRES and NJRCEV (October 2016 -
October 2017)
Senior Vice President, NJRES (May 2010 - September 2016) |
| Glenn C. Lockwood | 57 | 1990 | Executive Vice President (January 2011 - present)
Chief Financial Officer (September 1995 - December 2015) |
| Amanda E. Mullan | 52 | 2015 | Senior Vice President and Chief Human Resources Officer (January 2017 - present)
Vice President and Chief Human Resources Officer (April 2015 - December 2016)
Senior Vice President of HR, N. America, Willis Group Holdings, a risk management and
insurance intermediary (April 2012 - April 2015) |
| Jacqueline K. Shea | 54 | 2016 | Vice President and Chief Information Officer (June 2016 - present)
Chief Information Officer, Godiva Chocolatier, a manufacturer of premium fine chocolates and
related products (March 2011 - May 2016) |
| Nancy A. Washington | 54 | 2017 | Senior Vice President and General Counsel (March 2017 - present)
Senior Vice President and Chief Litigation Counsel, CIT Group Inc., a Livingston, NJ-based
financial services firm (September 2010 - March 2017)
|
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 September 30, 2018, NJR had 52,673 holders of record of its common stock.
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. 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 earlier terminated 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, 2018:
|
| | | | | | | | |
| 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 |
| 7/01/18 - 7/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 8/01/18 - 8/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 9/01/18 - 9/30/18 | — | $ | — |
| — |
| | 2,431,053 |
| Total | — | $ | — |
| — |
| | 2,431,053 |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA
CONSOLIDATED FINANCIAL STATISTICS
|
| | | | | | | | | | | | | | | |
| (Thousands, except per share data) | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
| SELECTED FINANCIAL DATA | | | | | |
| Operating revenues | $ | 2,915,109 |
| $ | 2,268,617 |
| $ | 1,880,905 |
| $ | 2,733,987 |
| $ | 3,738,145 |
|
| Gas purchases | $ | 2,275,342 |
| $ | 1,703,767 |
| $ | 1,352,686 |
| $ | 2,085,645 |
| $ | 3,139,525 |
|
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Total assets | $ | 4,143,664 |
| $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 3,284,357 |
| $ | 3,125,388 |
|
| Common stock equity | $ | 1,418,978 |
| $ | 1,236,643 |
| $ | 1,166,591 |
| $ | 1,106,956 |
| $ | 966,166 |
|
Long-term debt (1) (2) | $ | 1,180,619 |
| $ | 997,080 |
| $ | 1,055,038 |
| $ | 843,595 |
| $ | 598,209 |
|
| | | | | | |
| COMMON STOCK DATA | | | | | |
| Earnings per share-basic | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Earnings per share-diluted | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Dividends declared per share | $1.11 | $1.038 | $0.975 | $0.915 | $0.855 |
| | | | | | |
| NON-GAAP RECONCILIATION | | | | | |
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,770 |
| (11,241 | ) | 46,883 |
| (38,681 | ) | 28,534 |
|
| Tax effect | (4,512 | ) | 4,062 |
| (17,018 | ) | 14,391 |
| (10,492 | ) |
| Effects of economic hedging related to natural gas inventory | (22,570 | ) | 38,470 |
| (36,816 | ) | (8,225 | ) | 26,639 |
|
| Tax effect | 7,362 |
| (13,964 | ) | 13,364 |
| 3,058 |
| (9,794 | ) |
Net financial earnings (3) | $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 176,857 |
|
| | | | | | |
| Basic earnings per share | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.31 |
| (0.13 | ) | 0.55 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.13 | ) |
| Effects of economic hedging related to natural gas inventory | (0.26 | ) | 0.45 |
| (0.43 | ) | (0.10 | ) | 0.32 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.16 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-basic (3) | $2.74 | $1.73 | $1.61 | $1.78 | $2.10 |
| | | | | | |
| Diluted earnings per share | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.30 |
| (0.13 | ) | 0.54 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.12 | ) |
| Effects of economic hedging related to natural gas inventory | (0.25 | ) | 0.44 |
| (0.42 | ) | (0.10 | ) | 0.31 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.15 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-diluted (3) | $2.72 | $1.71 | $1.59 | $1.76 | $2.08 |
| |
| (1) | Includes long-term capital leases of $26.4 million, $28.9 million, $30.7 million, $35.7 million and $40.4 million, respectively. |
| |
| (2) | Includes long-term solar asset financing obligation of $89.8 million and $28.2 million in fiscal 2018 and 2017, respectively. |
| |
| (3) | NFE is a non-GAAP financial measure that eliminates the timing differences surrounding the recognition of certain derivative gains or losses, to effectively match the earnings effects of economic hedges associated with the physical sale or purchase of gas and, therefore, eliminate the impact of volatility to GAAP earnings associated with the related derivative instruments. For further discussion of this financial measure, see the Energy Services segment in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA (Continued)
NJNG OPERATING STATISTICS
|
| | | | | | | | | | | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
Operating revenues ($ in thousands) | | | | | |
| Residential | $ | 441,486 |
| $ | 395,315 |
| $ | 345,597 |
| $ | 466,464 |
| $ | 469,831 |
|
| Commercial, industrial and other | 95,351 |
| 98,777 |
| 80,994 |
| 106,505 |
| 110,740 |
|
| Firm transportation | 65,256 |
| 73,206 |
| 69,696 |
| 77,974 |
| 86,131 |
|
| Total residential and commercial | 602,093 |
| 567,298 |
| 496,287 |
| 650,943 |
| 666,702 |
|
| Interruptible | 7,522 |
| 7,970 |
| 8,867 |
| 10,049 |
| 9,384 |
|
| Total system | 609,615 |
| 575,268 |
| 505,154 |
| 660,992 |
| 676,086 |
|
| BGSS incentive programs | 122,250 |
| 120,369 |
| 89,192 |
| 120,978 |
| 143,329 |
|
| Total operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 819,415 |
|
| Throughput (Bcf) | | | | | |
| Residential | 45.5 |
| 40.7 |
| 36.9 |
| 45.9 |
| 43.1 |
|
| Commercial, industrial and other | 8.9 |
| 8.7 |
| 7.3 |
| 9.6 |
| 8.2 |
|
| Firm transportation | 15.5 |
| 14.4 |
| 14.1 |
| 16.0 |
| 17.7 |
|
| Total residential and commercial | 69.9 |
| 63.8 |
| 58.3 |
| 71.5 |
| 69.0 |
|
| Interruptible | 46.2 |
| 55 |
| 61.5 |
| 47.1 |
| 10.5 |
|
| Total system | 116.1 |
| 118.8 |
| 119.8 |
| 118.6 |
| 79.5 |
|
| BGSS incentive programs | 150.2 |
| 178.4 |
| 216.7 |
| 222.4 |
| 180.8 |
|
| Total throughput | 266.3 |
| 297.2 |
| 336.5 |
| 341.0 |
| 260.3 |
|
| Customers at year-end | | | | | |
| Residential | 474,495 |
| 460,013 |
| 448,273 |
| 437,979 |
| 422,742 |
|
| Commercial, industrial and other | 28,037 |
| 26,947 |
| 26,218 |
| 25,541 |
| 24,684 |
|
| Firm transportation | 36,126 |
| 42,790 |
| 46,608 |
| 48,673 |
| 56,777 |
|
| Total residential and commercial | 538,658 |
| 529,750 |
| 521,099 |
| 512,193 |
| 504,203 |
|
| Interruptible | 31 |
| 33 |
| 34 |
| 35 |
| 37 |
|
| BGSS incentive programs | 28 |
| 27 |
| 30 |
| 24 |
| 34 |
|
| Total customers at year-end | 538,717 |
| 529,810 |
| 521,163 |
| 512,252 |
| 504,274 |
|
Interest coverage ratio (1) | 6.35 |
| 7.96 |
| 8.97 |
| 9.57 |
| 10.24 |
|
| Average therm use per customer | | | | | |
| Residential | 959 |
| 885 |
| 824 |
| 1,049 |
| 1,020 |
|
| Commercial, industrial and other | 10,992 |
| 11,183 |
| 11,378 |
| 9,799 |
| 4,466 |
|
| Degree days | 4,537 |
| 4,129 |
| 3,867 |
| 5,015 |
| 5,080 |
|
Weather as a percent of normal (2) | 99.5 | % | 90.0 | % | 82.5 | % | 108.3 | % | 109.6 | % |
| Number of employees | 686 |
| 680 |
| 670 |
| 649 |
| 626 |
|
| |
| (1) | NJNG’s income from operations divided by interest expense. |
| |
| (2) | Normal heating degree days are based on a 20-year average, calculated based upon three reference areas representative of NJNG’s service territory. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
Critical Accounting Policies
We prepare our financial statements in accordance with GAAP. Application of these accounting principles requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingencies during the reporting period. We regularly evaluate our estimates, including those related to the calculation of the fair value of derivative instruments, regulatory assets, income taxes, pension and postemployment benefits other than pensions and contingencies related to environmental matters and litigation. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.
Regulatory Accounting
NJNG maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and recognizes the impact of regulatory decisions on its financial statements. As a result of the ratemaking process, NJNG is required to apply the accounting principles in ASC 980, Regulated Operations, which differ in certain respects from those applied by unregulated businesses. Specifically, NJNG records regulatory assets when it is probable that certain operating costs will be recoverable from customers in future periods and records regulatory liabilities associated with probable future obligations to customers.
NJNG’s BGSS requires it to project its annual natural gas costs and provides the ability, subject to BPU approval, to recover or refund the difference, if any, of such actual costs compared with the projected costs included in prices through a BGSS charge to customers. Any underrecovery or overrecovery is recorded as a regulatory asset or liability on the Consolidated Balance Sheets and reflected in the BGSS charge to customers in subsequent years.
As recovery of regulatory assets is subject to BPU approval, if there are any changes in future regulatory positions, which indicate that recovery of all or a portion of a regulatory asset is not probable, the related cost would be charged to income in the period of such determination.
Impairment of Long-lived assets
Property, plant and equipment and intangible assets are reviewed periodically 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. When an impairment indicator is present, the Company determines if the carrying value of the asset is recoverable by comparing it to the expected undiscounted future cash flows. If 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.
Equity method investments are reviewed periodically when changes in facts and circumstances indicate that the current fair value may be less than the asset’s carrying amount and record an impairment charge in an amount equal to the excess of the carrying value of the asset over its fair value if the decline is other than temporary.
Derivative Instruments
We record our derivative instruments held as assets and liabilities at fair value on the Consolidated Balance Sheets. In addition, since we choose not to designate any of our physical and financial natural gas commodity derivatives as accounting hedges, changes in the fair value of Energy Services’ commodity derivatives are recognized in earnings, as they occur, as a component of operating revenues or gas purchases on the Consolidated Statements of Operations. Changes in the fair value of foreign exchange contracts are recognized in 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 and/or a combination of those items. Energy Services’ portfolio is valued using the most current and reasonable market information. If the price underlying a physical commodity transaction does not represent a visible and liquid market, Energy Services may utilize additional published pipeline tariff information and/or other services to determine an equivalent market price. As of September 30, 2018, fair value of its derivative assets and liabilities reported on the Consolidated Balance Sheets that is based on such pricing is considered immaterial.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Should there be a significant change in the underlying market prices or pricing assumptions, Energy Services may experience a significant impact on its financial position, results of operations and cash flows. Refer to Item 7A. Quantitative and Qualitative Disclosures About Market Risks for a sensitivity analysis related to the impact to derivative fair values resulting from changes in commodity prices. The valuation methods we use to determine fair values remained consistent for fiscal 2018, 2017 and 2016. 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.
Clean Energy Ventures hedges certain of its expected production of SRECs through forward and futures contracts. Clean Energy Ventures intends to physically deliver all SRECs it sells and recognizes SREC revenue as operating revenue on the Consolidated Statements of Operations upon delivery of the underlying SREC.
We have not designated any derivatives as fair value or cash flow hedges as of September 30, 2018 and 2017.
Income Taxes and Credits
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 taxable items. We use the asset and liability method to determine and record deferred tax assets, representing future tax benefits, and deferred tax liabilities, representing future taxes payable, resulting from the differences between the financial reporting amount and the corresponding tax basis of the assets and liabilities using the enacted rates expected to be in effect at the time the differences are settled. An offsetting valuation allowance is recorded when it is more likely than not that some or all of the deferred income tax assets won’t be realized. Any significant changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a material change to earnings and cash flows. For a more detailed description of Income Taxes see Note 12. Income Taxes in the accompanying Consolidated Financial Statements.
For state income tax and other taxes, estimates and judgments are required with respect to the apportionment among the various jurisdictions. In addition, we operate within multiple tax jurisdictions and are subject to audits in these jurisdictions. These audits can involve complex issues, which may require an extended period of time to resolve. We maintain a liability for the estimate of potential income tax exposure and, in our opinion, adequate provisions for income taxes have been made for all years reported. Any significant changes to the estimates and judgments with respect to the apportionment factor could result in a material change to earnings and cash flows.
Occasionally, the federal and state taxing authorities determine that it is necessary to make certain changes to the income tax laws. These changes may include but are not limited to changes in the tax rates and/or the treatment of certain items of income or expense. Accounting guidance requires that the Company reflect the effect of tax laws or tax rates at the date of enactment. Additionally, the Company is required to re-measure its deferred tax assets and liabilities as of the date of enactment. For non-regulated entities, the effect of changes in tax rates and/or tax laws are required to be included in income from continuing operations for the period that includes the enactment date. For regulated entities, if as the result of an action by a regulator it is probable that the future increase or decrease in taxes payable for items such as changes in tax law or rates will be recovered from or returned to customers through future rates, an asset or liability shall be recognized for that probable increase or decrease in future revenue. Additionally, accounting guidance also requires that regulatory liabilities/assets be considered a temporary difference for which a deferred tax asset/liability shall be recognized. As a result, NJNG grossed up its regulatory liability to reflect the required accounting for the tax effects of the revaluation.
Concurrent with the enactment of the current tax reform legislation, the SEC issued Staff Accounting Bulletin No. 118, which lays out an approach that a registrant may follow to comply with the enactment period accounting requirements. Accordingly, registrants can have up to 12 months from the enactment date to complete the accounting for some or all of the income tax effects triggered by the enactment of the new law. Registrants need to determine and use “reasonable estimates” for some or all of the expected effects beginning with the one-year measurement period. The accounting must be finalized no later than 12 months from the enactment date. If reasonable estimates cannot be determined, the accounting should continue to be based on the old law until reasonable estimates can be determined in a subsequent period. As of September 30, 2018, our accounting for the income tax effects of the Tax Act is considered complete.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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. We have no reason to believe that we have any future obligations associated with unrecognized tax benefits; therefore, as of September 30, 2018 and 2017, we have not recorded any liabilities related to uncertain tax positions. 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.
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. For our unregulated subsidiaries, we recognize ITCs as a reduction to income tax expense when the property is placed in service.
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.
Environmental Costs
At the end of each fiscal year, NJNG, with the assistance of an independent consulting firm, updates the environmental review of its MGP sites, including its potential liability for investigation and remedial action. From this review, NJNG estimates expenditures necessary to remediate and monitor these MGP sites. NJNG’s estimate of these liabilities is developed from then-currently available facts, existing technology and current laws and regulations.
In accordance with accounting standards for contingencies, NJNG’s policy is to record a liability when it is probable that the cost will be incurred and can be reasonably estimated. NJNG will determine a range of liabilities and will record the most likely amount. If no point within the range is more likely than any other, NJNG will accrue the lower end of the range. Since we believe that recovery of these expenditures, as well as related litigation costs, is possible through the regulatory process, we have recorded a regulatory asset corresponding to the related accrued liability. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Consolidated Balance Sheets, which is based on the most likely amount.
The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations and the ultimate ability of other responsible parties to pay, as well as the potential impact of any litigation and any insurance recoveries. Previously incurred remediation costs, net of recoveries from customers and insurance proceeds received are included in regulatory assets on the Consolidated Balance Sheets.
If there are changes in the regulatory position surrounding these costs, or should actual expenditures vary significantly from estimates in that these costs are disallowed for recovery by the BPU, such costs would be charged to income in the period of such determination. See the Legal Proceedings section in Note 13. Commitments and Contingent Liabilities for more details.
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 impacted by actual employee demographics including age, compensation levels and employment periods, the level of contributions made to the plans, changes in long-term interest rates and the return on plan assets. Changes made to the provisions of the plans or healthcare legislation may also impact current and future postemployment employee benefit costs. Postemployment employee benefit costs may also be significantly affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets, changes in mortality tables, health care cost trends and discount rates used in determining the PBO. In determining the PBO and cost amounts, assumptions can change from period to period and could result in material changes to net postemployment employee benefit periodic costs and the related liability recognized by us.
Our postemployment employee benefit plan assets consist primarily of U.S. equity securities, international equity securities and fixed-income investments, with a targeted allocation of 34 percent, 17 percent and 41 percent, respectively. Fluctuations in actual market returns, as well as changes in interest rates, may result in increased or decreased postemployment employee benefit costs in future periods. Postemployment employee benefit expenses are included in O&M expense on the Consolidated Statements of Operations.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The following is a summary of a sensitivity analysis for each actuarial assumption:
|
| | | | | | | | | | | | | |
| Pension Plans | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (37,153 | ) | | | $ | (4,095 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 46,432 |
| | | $ | 4,756 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (2,619 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 2,619 |
| |
|
| | | | | | | | | | | | | |
| Other Postemployment Benefits | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (28,595 | ) | | | $ | (2,728 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 36,736 |
| | | $ | 3,406 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (713 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 714 |
| |
| | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Health care cost trend rate | 1.00 |
| % | | $ | 36,260 |
| | | $ | 3,838 |
| |
| Health care cost trend rate | (1.00 | ) | % | | $ | (28,743 | ) | | | $ | (2,991 | ) | |
On October 1, 2016, we changed our approach used to measure the service and interest cost components of our net periodic benefit costs. Previously, we estimated service cost and interest cost based on a single weighted-average discount rate from the yield curve used to measure our projected benefit obligation. We determine our service and interest cost based upon duration-specific spot rates that are aligned to each year’s future benefit payments. Under the new approach, net periodic benefit costs will be lower during periods of low interest rates and upward-sloping yield curves. Conversely, in a downward-sloping yield curve environment, costs could increase. Refer to Note 10. Employee Benefit Plans in the accompanying Consolidated Financial Statements for further discussion of our change in method.
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 an energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in the United States and Canada. In addition, we invest in clean energy projects and midstream assets and provide various repair, sales and installations services. A more detailed description of our organizational structure can be found in Item 1. Business.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Reporting Segments
We have four primary reporting segments as presented in the chart below:
In addition to our four reporting segments, we have non-utility operations that either provide corporate support services or do not meet the criteria to be treated as a separate reporting segment. These operations, which comprise Home Services and Other, include: appliance repair services, sales and installations at NJRHS and commercial real estate holdings at CR&R.
The Tax Act
On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. Since our fiscal year end is September 30, it is required by the Internal Revenue Code to calculate a statutory rate based upon the federal tax rates in effect before and after the effective date of the change in the taxable year that includes the effective date. Accordingly, we applied a federal statutory tax rate of 24.5 percent during fiscal 2018 and the enacted rate of 21 percent beginning in fiscal 2019.
As a result of the Tax Act, we revalued our deferred tax assets and liabilities at the enactment date to reflect the rates expected to be in effect when the deferred tax assets and liabilities are realized or settled. As of September 30, 2018, NJNG had a regulatory liability that included excess deferred income taxes of $205.4 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles. During fiscal 2018, we recognized an income tax benefit of approximately $17 million for NJNG and approximately $59.6 million for the remaining entities on the Consolidated Statements of Operations. See Note 12. Income Taxes for a more detailed discussion on the Tax Act.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
A summary of our consolidated results in net income and assets by reporting segment and operations for the fiscal years ended September 30, is as follows:
|
| | | | | | | | | | | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| | Net Income | Assets | Net Income | Assets | Net Income | Assets |
| Natural Gas Distribution | $ | 84,048 |
| $ | 2,663,054 |
| $ | 86,930 |
| $ | 2,519,578 |
| $ | 76,104 |
| $ | 2,517,401 |
|
| Clean Energy Ventures | 75,849 |
| 865,018 |
| 24,873 |
| 771,340 |
| 28,393 |
| 665,696 |
|
| Energy Services | 53,139 |
| 396,852 |
| 476 |
| 398,277 |
| 14,265 |
| 327,626 |
|
| Midstream | 24,367 |
| 242,069 |
| 12,857 |
| 232,806 |
| 9,406 |
| 186,259 |
|
| Home Services and Other | (3,555 | ) | 114,732 |
| 6,811 |
| 114,801 |
| 2,882 |
| 109,487 |
|
Intercompany (1) | (412 | ) | (138,061 | ) | 118 |
| (108,295 | ) | 622 |
| (87,899 | ) |
| Total | $ | 233,436 |
| $ | 4,143,664 |
| $ | 132,065 |
| $ | 3,928,507 |
| $ | 131,672 |
| $ | 3,718,570 |
|
| |
| (1) | Consists of transactions between subsidiaries that are eliminated in consolidation. |
Net Income
The primary drivers of the changes noted above, which are described in more detail in the individual segment discussions, are discussed below.
The increase in net income of $101.4 million during fiscal 2018, compared with fiscal 2017, was primarily driven by increased operating income at Energy Services related to colder weather, resulting in increased storage withdrawals due to higher demand coupled with higher volatility resulting in an increase in natural gas price spreads. Net income also increased due to impacts from the Tax Act, including a net income tax benefit of $59.6 million and a decrease in tax expense due to the lower tax rate, which was partially offset by increased O&M expense.
The increase in net income of $393,000 during fiscal 2017, compared with fiscal 2016, was primarily driven by increased margin at our Natural Gas Distribution segment due primarily to increased base rates which were effective October 1, 2016, increased other income at Home Services and Other due to the sale of available for sale securities, increased equity in earnings of affiliates at Midstream and increased revenues and PTCs at Clean Energy Ventures. These increases were partially offset by decreased operating income at Energy Services due primarily to a decrease of $16.4 million related to changes in the value of financial hedges and a decrease at Clean Energy Ventures due primarily to increased depreciation, operating and interest expenses.
Assets
The increase in assets during fiscal 2018, compared with fiscal 2017, was due primarily to additional utility plant at our Natural Gas Distribution segment and an advance payment of $10 million for the IEC acquisition, partially offset by a decrease in regulatory assets at our Natural Gas Distribution segment, as well as a decrease in the market value of the DM Common Units at Midstream.
The increase in assets during fiscal 2017, compared with fiscal 2016, was due primarily to additional solar expenditures at Clean Energy Ventures, the acquisition of Talen's wholesale and retail energy contract assets at Energy Services, increased PennEast capital contributions and an increase in the market value of our DM Common Units at Midstream, along with additional utility plant expenditures at our Natural Gas Distribution segment.
Non-GAAP Financial Measures
Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. Energy Services economically hedges its natural gas inventory with financial derivative instruments and calculates the related tax effect based on the statutory rate. 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 gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. To the extent we utilize forwards or futures to hedge forecasted SREC production, unrealized gains and losses are also eliminated for NFE purposes.
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 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. 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, except per share data) | 2018 | 2017 | 2016 |
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| Add: | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,770 |
| (11,241 | ) | 46,883 |
|
| Tax effect | (4,512 | ) | 4,062 |
| (17,018 | ) |
Effects of economic hedging related to natural gas inventory (1) | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Tax effect | 7,362 |
| (13,964 | ) | 13,364 |
|
| Net financial earnings | $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
|
| | | | |
| Basic earnings per share | $ | 2.66 |
| $ | 1.53 |
| $ | 1.53 |
|
| Add: | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.31 |
| (0.13 | ) | 0.55 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) |
Effects of economic hedging related to natural gas inventory (1) | (0.26 | ) | 0.45 |
| (0.43 | ) |
| Tax effect | 0.08 |
| (0.17 | ) | 0.16 |
|
| Basic net financial earnings per share | $ | 2.74 |
| $ | 1.73 |
| $ | 1.61 |
|
| |
| (1) | Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period. |
NFE by reporting segment and other operations for the fiscal years ended September 30, discussed in more detail within the operating results sections of each segment, is summarized as follows:
|
| | | | | | | | | | | | | | | | | |
| (Thousands) | 2018 | | 2017 | | 2016 |
| Natural Gas Distribution | $ | 84,048 |
| 35 | % | | $ | 86,930 |
| 58 | % | | $ | 76,104 |
| 55 | % |
| Clean Energy Ventures | 75,849 |
| 32 |
| | 24,873 |
| 17 |
| | 28,393 |
| 20 |
|
| Energy Services | 60,378 |
| 25 |
| | 18,554 |
| 12 |
| | 21,934 |
| 16 |
|
| Midstream | 24,367 |
| 10 |
| | 12,857 |
| 9 |
| | 9,406 |
| 7 |
|
| Home Services and Other | (3,829 | ) | (2 | ) | | 6,811 |
| 4 |
| | 2,882 |
| 2 |
|
Eliminations (1) | (327 | ) | — |
| | (633 | ) | — |
| | (634 | ) | — |
|
| Total | $ | 240,486 |
| 100 | % | | $ | 149,392 |
| 100 | % | | $ | 138,085 |
| 100 | % |
| |
| (1) | Consists of transactions between subsidiaries that are eliminated in consolidation. |
The increase in NFE during fiscal 2018, compared with fiscal 2017, was driven primarily by higher financial margin generated at Energy Services due primarily to colder weather, resulting in increased storage withdrawals due to higher demand coupled with higher volatility, allowing Energy Services to capture additional margin from natural gas price spreads. The increase in NFE also included a net income tax benefit of $59.6 million associated with the Tax Act, as previously discussed.
The increase in NFE during fiscal 2017, compared with fiscal 2016, was driven primarily by increases at our Natural Gas Distribution segment, Midstream and Home Services and Other, as previously discussed, partially offset by lower financial margin at Energy Services due primarily to lower sales volumes and fewer market opportunities and the decrease at Clean Energy Ventures, as previously discussed.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Natural Gas Distribution Segment
Overview
Our Natural Gas Distribution segment is comprised of NJNG, a natural gas utility that provides regulated retail natural gas service in central and northern New Jersey to approximately 529,800538,700 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 can negatively impact customer growth, operating and financing costs, fluctuations in commodity prices and customer conservation efforts. These risks include, but are not limited to, adverse economic conditions, customer usage, 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.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
In addition, NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered to customers on an annual basis. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG receives most of its natural gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the year.
As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 4.3. Regulation in the accompanying Consolidated Financial Statements for a more detailed discussion on regulatory actions, including filings related to programs and associated expenditures, as well as rate requests related to recovery of capital investments and operating costs.
NJNG’s operations are managed with the goal of providing safe and reliable service, growing its customer base, diversifying its gross margin, promoting clean energy programs and mitigating the risks discussed above through several key initiatives, including:
earning a reasonable rate of return on the investments in its natural gas distribution and transmission businesses, as well as timely recovery of all prudently incurred costs to provide safe and reliable service throughout NJNG’s territory;
continuing to invest in the safety and integrity of its infrastructure;
| |
�� | managing its customer growth rate, which NJNG expects will be approximately 1.7 percent annually through fiscal 2019; |
managing its customer growth rate, which NJNG expects will be approximately 1.8 percent annually through fiscal 2021;
maintaining a collaborative relationship with the BPU on regulatory initiatives, including:
- planning and authorization of infrastructure investments;
- pursuing rate and regulatory strategies to stabilize and decouple margin, including CIP;
- utilizing BGSS incentive programs through BPU-approved mechanisms to reduce gas costs and generate margin; and
- administering and promoting NJNG’s BPU-approved SAVEGREEN Project;
managing the volatility of wholesale natural gas prices through a hedging program designed to keep customers’ BGSS rates as stable as possible; and
working with the NJDEP and BPU to manage its financial obligations related to remediation activities associated with its former MGP sites.
Base Rate Case
In September 2016, the BPU approved NJNG's base rate case, effective October 2016, which included the following:
an increase in base rates in the amount of $45 million. The base rate increase includes a return on common equity of 9.75 percent, a common equity ratio of 52.5 percent and an increase in the overalla depreciation rate from 2.34 percent toof 2.4 percent;
the recovery of SAFE I capital investments andpercent. The approval also included the rate mechanism and five-year extension of SAFE II. The estimated cost for SAFE II, extension, excluding AFUDC, is approximately $200 million and related costs to be recovered on an accelerated basis are approximately $157.5 million. As a condition of the extension approval, NJNG is required to file a base rate case no later than November 2019;
rate recovery of NJ RISE capital investment costs through June 30, 2016, and the filing for recovery of future NJ RISE capital investment costs to be recovered, will occur in conjunction with SAFE II, commencing with the rate recovery filing submitted in March 2017;
recovery of NJNG’s NGVSAFE I, Natural Gas Vehicle Refueling Stations and LNG plant investments;capital investments and
recovery of other costs previously deferred in regulatory assets over seven years.
assets.
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 and estimates for expected investments over the next two fiscal years:
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.
SAFE and NJ RISE
NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability and integrity of NJNG’s gas distribution system.
The BPU approved recovery of SAFE I capital investments through September 30, 2016, and approved the rate mechanism and extension of SAFE II for an additional five years to replace the remaining unprotected steel mains and services from itsNJNG’s natural gas distribution system at an estimated cost of approximately $200 million, excluding AFUDC. The accelerated cost recovery methodology for the $157.5 million associated with the extension of SAFE II was approved in NJNG’s new base rates. The remaining $42.5 million in capital expenditures will be requested for recovery in a future base rate case.cases.
The BPU approved the recovery of NJNG'sNJNG’s NJ RISE capital infrastructure program, which consists of six capital investment projects estimated to cost $102.5 million, excluding AFUDC, for 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 that live in the most storm pronestorm-prone areas of NJNG'sNJNG’s service territory. Recovery of NJ RISE investments through June 30, 2016, is included in NJNG’s base rates.
On March 30,In July 2017, NJNG filed itsthe BPU approved NJNG’s annual petition with the BPU requesting a base rate$4.1 million increase for the recoveryin recoveries of NJ RISE and SAFE II capital investment costs, with a weighted cost of capital of 6.9 percent including a return on equity of 9.75 percent, related to the period ending June 30, 2017, based on estimates, pursuant to the September 2016 base rate case. On July 20,effective October 2017.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
2017, NJNG filed an update to this petition with actuals, requesting a $4.1 million annual increase in recoveries, which was approved by the BPU, effective October 1, 2017.
NGV Advantage
In June 2012,On September 17, 2018, the BPU approved NJNG’s annual petition requesting a pilot programbase rate increase of $6.8 million for NJNG to invest up to $10 million to build NGV refueling stations. The NGV program was authorized by the BPU to earn an overallrecovery of SAFE II and NJ RISE capital investment costs, with a weighted average cost of capital of 7.16.9 percent including a return on equity of 10.3 percent. A portion of9.75 percent, related to the proceeds from the utilization of the compressed12-months ended June 30, 2018, effective October 1, 2018.
Natural Gas Vehicle Refueling Stations
NJNG has three natural gas equipment, along with any available federal and state incentives, will be credited back to customers to offset a portion of the cost of the NGV investment. All three of the NGVvehicle refueling stations are open to the publicpublic. Costs for these stations were approximately $10 million and NJNG is recovering its costsare being recovered through NJNG’s base rates, effective October 2016.
Liquefaction/LNG
In June 2016, NJNG’s Liquefaction facility became operational and allows NJNG to convert natural gas into LNG to fill its existing LNG storage tanks. Costs for this projectfacility along with other plant upgrades were approximately $36.5 million and are being recovered through NJNG’s new base rates effective October 2016.
Southern Reliability Link
The SRL is an approximateapproximately 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG’s service territory, estimated to cost between $180 million and $200$215 million. In January 2016, the BPU issued an order approving NJNG’s modified, proposed SRL pipeline installation, operation and route selection. In March 2016, the BPU issued an order designating the SRL route and exempting the SRL from municipal land use ordinances, regulations, permits and license requirements. In February 2017, the New Jersey Department of Environmental Protection issued a permit authorizing construction of the SRL within the jurisdiction of the Coastal Area Facility Review Act, as well as a Freshwater Wetlands permit. OnIn September 14, 2017, the NJ Pinelands Commission approved construction of the SRL as being compliant with the Commission'sCommission’s Comprehensive Management Plan. All approvals issued by state agencies are under appeal and permits have been appealed by third parties. Once the final road openingcertain road-opening permits and easements are secured, constructionin the process of being secured. Construction is expected to begin in fiscal 2019, with an estimated in-service date during the first quarter of fiscalin 2019.
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:
| | | | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Firm customers | | |
| Residential | 460,013 |
| 448,273 |
| 437,979 |
| 474,495 |
| 460,013 |
| 448,273 |
|
| Commercial, industrial & other | 26,947 |
| 26,218 |
| 25,541 |
| 28,037 |
| 26,947 |
| 26,218 |
|
| Residential transport | 32,653 |
| 36,292 |
| 38,424 |
| 26,490 |
| 32,653 |
| 36,292 |
|
| Commercial transport | 10,137 |
| 10,316 |
| 10,249 |
| 9,636 |
| 10,137 |
| 10,316 |
|
| Total firm customers | 529,750 |
| 521,099 |
| 512,193 |
| 538,658 |
| 529,750 |
| 521,099 |
|
| Other | 60 |
| 64 |
| 59 |
| 59 |
| 60 |
| 64 |
|
| Total customers | 529,810 |
| 521,163 |
| 512,252 |
| 538,717 |
| 529,810 |
| 521,163 |
|
During fiscal 2017,2018, NJNG added 9,1269,596 new customers, which represents a new customer growth rate of approximately 1.71.8 percent. During that same time period, NJNG converted 662613 existing customers to natural gas heat and other services. This customer growth, as well as commercial customers who switched from interruptible to firm natural gas service, will contribute approximately $5.5 million, on an annualized basis, to utility gross margin. NJNG also added 8,1709,126 and 7,8588,170 new customers and converted 644
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
662 and 636644 existing customers to natural gas heat and other services during the fiscal years ended September 30, 2017 and 2016, and 2015, respectively.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
In addition, NJNG currently expects to add approximately 26,00028,000 to 28,00030,000 new customers during the three-year period of fiscal 20182019 to 2020. NJNG's2021. NJNG’s estimates are based on information from municipalities and developers, as well as external industry analysts and management’s experience. NJNG estimates that approximately 6068 percent of the growth will come from new construction markets and 4032 percent from customer conversions to natural gas from other fuel sources. This new customer and conversion growth would increase utility gross margin under NJNG’s base rates by approximately $5.3$5.5 million annually, as calculated under NJNG’s CIP tariff. See the Natural Gas Distribution Segment Operating Results section that follows for a definition and further discussion of utility gross margin.
SAVEGREENEnergy Efficiency Programs
SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives, which are designed to encourage the installation of high efficiencyhigh-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 twotwo- to 10-year period through a tariff rider mechanism. In June 2016, the BPU approved NJNG’s extension of SAVEGREEN through December 31, 2018. On September 17, 2018, the BPU approved the continuation of existing SAVEGREEN programs and the addition of new programs with investments of $135 million through December 2021.
On October 20, 2017, the BPU approved NJNG’s filing to decrease its EE recovery rate, which resulted in an annual decrease of $3.9 million, effective November 1, 2017. On May 25, 2018, NJNG filed a petition with the BPU to decrease its EE recovery rate. On October 16, 2018, NJNG updated this information through September 30, 2018, which will result in an annual decrease of $8.8 million, anticipated to be effective January 1, 2019.
Since inception, $149.7$162 million in grants, rebates and loans hashave been provided to customers, with a total annual recovery of approximately $20$16.1 million. In June 2016, the BPU approved NJNG's extension of SAVEGREEN through December 31, 2018. In October 2016, the BPU approved NJNG’s filing to maintain the existing SAVEGREEN recovery rate. On October 20, 2017, the BPU approved NJNG's filing to decrease its EE recovery rate, which would result in an annual decrease of $3.9 million, effective November 1, 2017. The recovery includes a weighted average cost of capital that ranges from 6.69 percent to 7.76 percent, with a return on equity of 9.75 percent to 10.3 percent.
Conservation Incentive Program
The CIP facilitates normalizing NJNG’s utility gross margin for variances not only due to weather but also for other factors affecting customer usage, such as conservation and energy efficiency. Recovery of utility gross margin for the non-weather variance through the CIP is limited to the amount of certain gas supply cost savings achieved and is subject to a variable margin review test. Additionally, recovery of the CIP utility gross margin is subject to an annual earnings test. An annual review of the CIP must be filed by June 1, coincident with NJNG’s annual BGSS filing, during which NJNG can request rate changes to the CIP. In May 2014, the BPU approved the continuation of the CIP program with no expiration date. Refer to Note 4.3. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements, for a discussion of CIP rate actions.
NJNG’s total utility firm gross margin includes the following adjustments related to the CIP mechanism:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
Weather (1) | $ | 19,261 |
| $ | 27,547 |
| $ | (9,268 | ) | $ | 205 |
| $ | 19,261 |
| $ | 27,547 |
|
| Usage | (2,309 | ) | 10,420 |
| 3,132 |
| (1,629 | ) | (2,309 | ) | 10,420 |
|
| Total | $ | 16,952 |
| $ | 37,967 |
| $ | (6,136 | ) | $ | (1,424 | ) | $ | 16,952 |
| $ | 37,967 |
|
| |
| (1) | Compared with the CIP 20-year average, weather was 0.5 percent, 10 percent and 17.5 percent warmer-than-normal during fiscal 2018, 2017 and 2016, respectively, and 8.3 percent colder-than-normal during 20152016., respectively. |
As of September 30, 2017 and 2016, NJNG has $17.7 million and $37 million, respectively, in regulatory assets related to CIP to be collected from customers in future periods on the Consolidated Balance Sheets.
Commodity prices
Our Natural Gas Distribution segment is affected by the price of natural gas, which can have a significant impact on our cash flows, short-term financing costs, the price of natural gas charged to our customers through the BGSS clause, our ability to collect accounts receivable, which impacts our bad debt expense, and our ability to maintain a competitive advantage over other fuel sources.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Natural gas commodity prices may experience high volatility as shown in the graph below, which illustrates the daily natural gas prices(1) in the Northeast market region, also known as Tetco M-3.
(1) Data sourceMidpoint daily gas price sourced from Platts, a division of McGraw Hill Financial.
The maximum daily price per MMBtu was $94.93, $8.71 $4.74 and $21.09$4.74 and the minimum daily price was $0.53, $0.36 $0.67 and $0.77$0.67 for the fiscal years ended September 30, 2018, 2017 2016 and 2015,2016, respectively. A more detailed discussion of the impacts of the price of natural gas on operating revenues, gas purchases and cash flows can be found in the Results of Operations and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
BGSS
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 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.
On September 22, 2017,March 26, 2018, the BPU provisionally approved maintaining NJNG's petition to maintain its BGSS rate for residential and small commercial customers and an increase to its balancing charge rate, which will resultresulted in a $3.7 million increase to the annual revenues credited to BGSS, effective October 2017. 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. During fiscal 2017, and 2016, NJNG issued bill credits of $42 million and $61.6 million, respectively, as a result of a decline in the wholesale price of natural gas. ReferThere were no bill credits issued during fiscal 2018, related to Note 4. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements, for a further discussion of NJNG’s periodic BGSS rate adjustments and bill credits.prices.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On September 17, 2018, the BPU provisionally approved NJNG’s annual petition to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well changes to the CIP rates, which will result in a $30.9 million annual recovery decrease, effective October 1, 2018. Refer to Note 3. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements for a further discussion of NJNG’s periodic BGSS rate adjustments and bill credits.
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'sNJNG’s natural gas supply, transportation and storage assets. Depending on the program, NJNG shares 80 or 85 percent of utility gross margin generated by these programs with firm customers. Should performance of the existing incentives or market conditions warrant, NJNG is permitted to propose a process to re-evaluate and discuss alternative incentive programs annually. Utility gross margin from incentive programs was $12.5 million, $13.7 million $15 million and $17.7$15 million during the fiscal years ended September 30, 2018, 2017 2016 and 2015,2016, respectively. A more detailed discussion of the impacts to utility gross margin can be found in the Natural Gas Distribution Segment Operating Results section that follows.
Hedging
In order to provide relative price stability to its natural gas supply portfolio, NJNG employs a hedging strategy with the goal of having at least 75 percent of the Company’sits projected winter periodic BGSS gas sales volumes hedged by each November 1 and at least 25 percent of the projected BGSS gas sales hedged for the following April through MarchApril-through-March period. This is accomplished with the use of various financial instruments including futures, swaps and options used in conjunction with commodity and/or weather-related hedging activity.
Due to the capital-intensive nature of NJNG’s operations and the seasonal nature of its working capital requirements, significant changes in interest rates can impact NJNG’s results. In an April 2014 BPU Order, NJNG received regulatory approval to enter into interest rate risk management transactions related to long-term debt securities. On June 1, 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with the forecasted-year,a $125 million debt issuance expectedthat was finalized in May 2018. This forecastedThe debt issuance coincidescoincided with the maturity of NJNG’s existingNJNG's $125 million, 5.6 percent notes that came due on May 15, 2018. The fair value of NJNG’sThis treasury lock agreementwas settled on March 13, 2018, which coincided with the pricing of the new debt being issued. Settlement of the interest rate contract resulted in a $2.6 million loss, which is recorded as a component of regulatory assets or liabilities on the Consolidated Balance Sheets since the Company believes that the market value upon settlement will be reflected in future rates. Upon settlement, any gain or lossand will be amortized into earnings over the life30-year term of the future debt issuance.$125 million note issued on May 11, 2018.
A more detailed discussion of NJNG’s debt can be found in the Liquidity and Capital Resources and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Societal Benefits Charge
USF
NJNG'sNJNG’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. InOn September 2016,17, 2018, the BPU approved NJNG'sNJNG’s annual USF compliance filing proposing to increase the statewide USF rate, resultingwhich will result in a $1.3$1 million annual increase, in USF recoveries, effective October 2016.1, 2018. Refer to Note 4.3. Regulation - Societal Benefits Clause in the accompanying Consolidated Financial Statements for a further discussion of NJNG'sNJNG’s USF rates.
Environmental Remediation
NJNG is responsible for the environmental remediation of five 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 $149$130.8 million as of September 30, 2017,2018, a decrease of $23$18.2 million, compared with the prior fiscal period. The reduction was due to the completion of remediation work at certain sites and a reduction to the remediation scope of work at another site.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Other
In May 2016, NJNG included a proposal in its base rate case to recover certain capital costs and incremental operation and maintenance costs related to a March 2016 BPU Order regarding new cybersecurity requirements. This proposal was updated in July 2016, and the associated costs were approved for recovery through NJNG’s new base rates, effective October 2016.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Interest Rate Risk
Due to the capital-intensive nature of NJNG’s operations and the seasonal nature of its working capital requirements, significant changes in interest rates can impact NJNG’s results. A more detailed discussion can be found in the Liquidity and Capital Resources and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Other regulatory filings and a more detailed discussion of the filings in this section can be found in Note 4.3. Regulation in the accompanying Consolidated Financial Statements.
Commodity Service to Customers
The EDECA, which was enacted in 1999, provides the framework for New Jersey’s retail energy markets, which are open to competition from other electric and natural gas suppliers. 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 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 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,utilities; however, customers who purchase natural gas from another supplier continue to use NJNG for transportation service.
Operating Results
NJNG’s operating results for the fiscal years ended September 30, are as follows:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Operating revenues | $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Operating expenses | | |
Gas purchases (1) (2) | 269,480 |
| 215,849 |
| 355,779 |
| 333,208 |
| 269,480 |
| 215,849 |
|
| Operation and maintenance | 142,509 |
| 130,575 |
| 129,774 |
| 161,723 |
| 142,509 |
| 130,575 |
|
Regulatory rider expense (3) | 40,243 |
| 39,300 |
| 75,779 |
| 38,969 |
| 40,243 |
| 39,300 |
|
| Depreciation and amortization | 49,347 |
| 47,828 |
| 43,085 |
| 53,208 |
| 49,347 |
| 47,828 |
|
Energy and other taxes (4) | 42,417 |
| 34,561 |
| 47,506 |
| 44,184 |
| 42,417 |
| 34,561 |
|
| Total operating expenses | 543,996 |
| 468,113 |
| 651,923 |
| 631,292 |
| 543,996 |
| 468,113 |
|
| Operating income | 151,641 |
| 126,233 |
| 130,047 |
| 100,573 |
| 151,641 |
| 126,233 |
|
| Other income, net | 4,592 |
| 4,752 |
| 4,318 |
| 6,864 |
| 4,592 |
| 4,752 |
|
| Interest expense, net of capitalized interest | 25,818 |
| 19,930 |
| 18,534 |
| 25,299 |
| 25,818 |
| 19,930 |
|
| Income tax provision | 43,485 |
| 34,951 |
| 39,544 |
| |
| Income tax (benefit) provision | | (1,910 | ) | 43,485 |
| 34,951 |
|
| Net income | $ | 86,930 |
| $ | 76,104 |
| $ | 76,287 |
| $ | 84,048 |
| $ | 86,930 |
| $ | 76,104 |
|
| |
| (1) | Includes the purchased cost of the natural gas, fees paid to pipelines and storage facilities, adjustments as a result of BGSS incentive programs and hedging transactions. These expenses are passed through to customers and are offset by corresponding revenues. |
| |
| (2) | Includes related party transactions of approximately $10.8$57.2 million, $10.8 million and $50.8$10.8 million during fiscal 2018, 2017 2016 and 2015,2016, respectively, a portion of which are eliminated in consolidation. |
| |
| (3) | Consists of expenses associated with state-mandated programs, the RAC and energy efficiency programs, and are calculated on a per-therm basis. These expenses are passed through to customers and offset by corresponding revenues. |
| |
| (4) | Consists primarily of sales tax, which is passed through to customers and offset by corresponding revenues. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Revenues and Gas Purchases
Operating revenues increased 5.2 percent during fiscal 2018 and increased 17 percent during fiscal 2017 and decreased 242017. Gas purchases increased 23.6 percent during fiscal 2016. Gas purchases2018 and increased 24.8 percent during fiscal 2017 and decreased 39.3 percent during fiscal 2016.2017. The factors contributing to the increases (decreases) in operating revenues and gas purchases during fiscal 20172018 and 2016,2017, are as follows:
|
| | | | | | | | | | | | | |
| | 2017 v. 2016 | | 2016 v. 2015 |
| (Millions) | Operating revenue | Gas purchases | | Operating revenue | Gas purchases |
| Firm sales | $ | 44.4 |
| $ | 21.6 |
| | $ | (116.1 | ) | $ | (50.4 | ) |
Rate impact (1) | 37.4 |
| — |
| | — |
| — |
|
Bill credits (2) | 19.6 |
| 18.3 |
| | (61.6 | ) | (57.6 | ) |
| Off-system sales | 29.2 |
| 29.1 |
| | (32.1 | ) | (31.8 | ) |
Average BGSS rates (3) | (17.9 | ) | (16.5 | ) | | (2.7 | ) | (2.5 | ) |
| CIP adjustments | (21.0 | ) | — |
| | 44.1 |
| — |
|
Other (4) | 9.6 |
| 1.1 |
| | (19.2 | ) | 2.4 |
|
| Total increase (decrease) | $ | 101.3 |
| $ | 53.6 |
| | $ | (187.6 | ) | $ | (139.9 | ) |
|
| | | | | | | | | | | | | |
| | 2018 v. 2017 | | 2017 v. 2016 |
| (Thousands) | Operating revenue | Gas purchases | | Operating revenue | Gas purchases |
| Firm sales | $ | 49,414 |
| $ | 19,779 |
| | $ | 44,397 |
| $ | 21,634 |
|
Bill credits (1) | 41,971 |
| 39,260 |
| | 19,588 |
| 18,265 |
|
Average BGSS rates (2) | 1,147 |
| 1,413 |
| | (17,874 | ) | (16,544 | ) |
| Off-system sales | 677 |
| 221 |
| | 29,156 |
| 29,117 |
|
| Tax Act impact | (35,910 | ) | — |
| | — |
| — |
|
| CIP adjustments | (18,375 | ) | — |
| | (21,015 | ) | — |
|
Rate impact (3) | — |
| — |
| | 37,436 |
| — |
|
Other (4) | (2,696 | ) | 3,055 |
| | 9,603 |
| 1,159 |
|
| Total increase | $ | 36,228 |
| $ | 63,728 |
| | $ | 101,291 |
| $ | 53,631 |
|
| |
| (1) | Operating revenues include changes in sales tax of $2.7 million and $1.3 million during fiscal 2018 and 2017, respectively. |
| |
| (2) | Operating revenues include changes in sales tax of $266,000 and $1.4 million during fiscal 2018 and 2017, respectively. |
| |
| (3) | Includes rate adjustments for the base rate case, CIP and demand charges. |
| |
(2) | Operating revenues include changes in sales tax of $1.3 million and $4 million during during fiscal 2017 and 2016, respectively.
|
| |
(3) | Operating revenues include changes in sales tax of $1.4 million and $200,000 during fiscal 2017 and 2016, respectively. |
| |
| (4) | Other includes changes infor NJ RISE/SAFE II and rider rates, including those related to EE, NJCEP and other programs. |
Fiscal 2018 compared with fiscal 2017
The changes in operating revenues and gas purchases during fiscal 2018 were due primarily to:
increased firm sales due primarily to customer growth and higher usage related to weather being 9.9 percent colder than fiscal 2017;
bill credits issued to residential and small commercial customers during fiscal 2017 that did not occur in fiscal 2018; partially offset by
the Tax Act impact, which is comprised of customer credits related to the initial revaluation of excess deferred income taxes and the overcollection of taxes from customers during the second quarter of fiscal 2018, including related interest and sales tax, as well as the effects from the reduction in base rates related to the Tax Act implemented during the third quarter;
a decrease in CIP due primarily to normal weather during fiscal 2018, compared with warmer-than-normal weather during fiscal 2017; and
higher off-system sales due primarily to an increase of 19.7 percent in the average price of natural gas sold, partially offset by a reduction in volumes of 15.9 percent.
Fiscal 2017 compared with fiscal 2016
The changes in operating revenues and gas purchases during fiscal 2017 were due primarily to:
increased firm sales due primarily to customer growth and higher usage, related to weather being 6.8 percent colder;
increased base rates resulting from the settlement of the base rate case;
higher off-system sales due primarily to a 49.8 percent increase in the average price of natural gas sold, partially offset by a 12.2 percent reduction in volumes;
volumes;
a decrease in bill credits issued to residential and small commercial customers during the months of November 2016 through February 2017 compared with the same period lastin the prior year; partially offset by
a decrease in CIP due primarily to weather, partially offset by changes in the CIP as a result of the settlement of the base rate case.
Fiscal 2016 compared with fiscal 2015
The decreases in operating revenues and gas purchases during fiscal 2016 were due primarily to:
decreased firm sales due primarily to lower usage related to weather being 22.9 percent warmer;
bill credits issued to residential and small commercial customers effective November 1, 2015, which were not issued during fiscal 2015;
lower off-system sales due primarily to a 38.3 percent decrease in the average price of gas sold, partially offset by a 18.4 percent increase in volumes;
a decrease in rider revenues, categorized in other, due primarily to a 36.3 percent decrease in rates and a 18.5 percent decrease in usage; partially offset by
an increase in CIP adjustments of $36.8 millionrelated to weather and $7.3 millionrelated to usage.
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 utility gross margin, a non-GAAP financial measure, when evaluating the operating results of NJNG. NJNG’s utility gross margin is defined as natural gas revenues less natural gas purchases, sales tax and regulatory rider expenses, and may not be comparable to the definition of gross margin used by others in the natural gas distribution business and other industries. Management believes that utility gross margin provides a meaningful basis for evaluating utility operations since natural gas costs, sales tax and regulatory rider expenses are included in operating revenue and passed through to customers and, therefore, have no effect on utility gross margin. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.
Utility Gross Margin
A reconciliation of operating revenues, the closest GAAP financial measure to NJNG’s utility gross margin, is as follows for the fiscal years ended September 30:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Operating revenues | $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Less: | | |
| Gas purchases | 269,480 |
| 215,849 |
| 355,779 |
| 333,208 |
| 269,480 |
| 215,849 |
|
| Energy taxes | 37,917 |
| 29,832 |
| 42,929 |
| 39,426 |
| 37,917 |
| 29,832 |
|
| Regulatory rider expense | 40,243 |
| 39,300 |
| 75,779 |
| 38,969 |
| 40,243 |
| 39,300 |
|
| Utility gross margin | $ | 347,997 |
| $ | 309,365 |
| $ | 307,483 |
| $ | 320,262 |
| $ | 347,997 |
| $ | 309,365 |
|
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:
|
| | | | | | | | | | | | | | | | | |
| | 2017 | | 2016 | | 2015 |
| ($ in thousands) | Margin | Bcf | | Margin | Bcf | | Margin | Bcf |
| Utility gross margin/throughput | | | | | | | | |
| Residential | $ | 218,093 |
| 40.7 |
| | $ | 187,762 |
| 36.9 |
| | $ | 182,407 |
| 45.9 |
|
| Commercial, industrial and other | 51,510 |
| 8.7 |
| | 46,878 |
| 7.3 |
| | 47,162 |
| 9.6 |
|
| Firm transportation | 58,172 |
| 14.4 |
| | 54,841 |
| 14.1 |
| | 55,614 |
| 16.0 |
|
| Total utility firm gross margin/throughput | 327,775 |
| 63.8 |
| | 289,481 |
| 58.3 |
| | 285,183 |
| 71.5 |
|
| BGSS incentive programs | 13,724 |
| 178.4 |
| | 14,978 |
| 216.7 |
| | 17,707 |
| 222.4 |
|
| Interruptible/off-tariff agreements | 6,498 |
| 55.0 |
| | 4,906 |
| 61.5 |
| | 4,593 |
| 47.1 |
|
| Total utility gross margin/throughput | $ | 347,997 |
| 297.2 |
| | $ | 309,365 |
| 336.5 |
| | $ | 307,483 |
| 341.0 |
|
Utility Firm Gross Margin
A description of the factors contributing to the increases in utility firm gross margin during fiscal 2017 and 2016, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2017 v. 2016 | 2016 v. 2015 |
| Rate impact | | $ | 35,019 |
| | | $ | — |
| |
| Customer growth | | 3,619 |
| | | 3,436 |
| |
| SAVEGREEN | | (345 | ) | | | 862 |
| |
| Total increase | | $ | 38,293 |
| | | $ | 4,298 |
| |
|
| | | | | | | | | | | | | | | | | |
| | 2018 | | 2017 | | 2016 |
| ($ in thousands) | Margin | Bcf | | Margin | Bcf | | Margin | Bcf |
| Utility gross margin/throughput | | | | | | | | |
| Residential | $ | 203,195 |
| 45.5 |
| | $ | 218,093 |
| 40.7 |
| | $ | 187,762 |
| 36.9 |
|
| Commercial, industrial and other | 46,636 |
| 8.9 |
| | 51,510 |
| 8.7 |
| | 46,878 |
| 7.3 |
|
| Firm transportation | 51,880 |
| 15.5 |
| | 58,172 |
| 14.4 |
| | 54,841 |
| 14.1 |
|
| Total utility firm gross margin/throughput | 301,711 |
| 69.9 |
| | 327,775 |
| 63.8 |
| | 289,481 |
| 58.3 |
|
| BGSS incentive programs | 12,482 |
| 150.2 |
| | 13,724 |
| 178.4 |
| | 14,978 |
| 216.7 |
|
| Interruptible/off-tariff agreements | 6,069 |
| 46.2 |
| | 6,498 |
| 55 |
| | 4,906 |
| 61.5 |
|
| Total utility gross margin/throughput | $ | 320,262 |
| 266.3 |
| | $ | 347,997 |
| 297.2 |
| | $ | 309,365 |
| 336.5 |
|
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Utility Firm Gross Margin
A description of the factors contributing to the (decreases) increases in utility firm gross margin during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2018 v. 2017 | 2017 v. 2016 |
| Tax Act impact | | $ | (33,657 | ) | | | $ | — |
| |
| SAVEGREEN | | (977 | ) | | | (345 | ) | |
| NJ RISE/SAFE II | | 4,334 |
| | | — |
| |
| Customer growth | | 4,236 |
| | | 3,619 |
| |
| Rate impact | | — |
| | | 35,019 |
| |
| Total (decrease) increase | | $ | (26,064 | ) | | | $ | 38,293 |
| |
BGSS Incentive Programs
A description of the factors contributing to the (decreases) increases in utility gross margin generated by NJNG’s BGSS incentive programs during fiscal 20172018 and 2016,2017, are as follows:
| | | (Thousands) | 2017 v. 2016 | 2016 v. 2015 | 2018 v. 2017 | 2017 v. 2016 |
| Storage | | | $ | (954 | ) | | $ | 378 |
| |
| Capacity release | | $ | (1,672 | ) | | $ | (758 | ) | | | (745 | ) | | (1,672 | ) | |
| Storage | | 378 |
| | (1,184 | ) | | |
| Off-system sales | | 39 |
| | (278 | ) | | | 457 |
| | 39 |
| |
| FRM | | — |
| | (509 | ) | | |
| Total (decrease) increase | | $ | (1,255 | ) | | $ | (2,729 | ) | | |
| Total decrease | | | $ | (1,242 | ) | | $ | (1,255 | ) | |
Fiscal 2018 compared with fiscal 2017
The decrease in utility gross margin was due primarily to the Tax Act impact, as previously discussed, a decrease in value in the storage incentive program and a decrease in capacity release due to less volume and lower values, partially offset by increased margins for off-system sales.
Fiscal 2017 compared with fiscal 2016
The increase in utility gross margin was due primarily to the base rate increase and customer growth, along with an increase in interruptible/off-tariff agreements, partially offset by decreased margins related to capacity release due to lower volumes and lower value of capacity.
Fiscal 2016 compared with fiscal 2015
The increase in utility gross margin was due primarily to customer growth, partially offset by decreased BGSS incentives. BGSS incentives were lower due primarily to decreases in the storage incentive program due primarily to higher cost at injection point, as well as decreases in capacity release and off system sales due primarily to the lower capacity value. The decrease in off-system sales was also driven by a decrease in the average price of gas sold, partially offset by an increase in volumes. The FRM program was terminated effective November 2015.
Operation and Maintenance Expense
A summary and description of the factors contributing to the increases (decreases) in O&M expense during fiscal 20172018 and 2016,2017, are as follows:
| | | (Thousands) | 2017 v. 2016 | 2016 v. 2015 | 2018 v. 2017 | 2017 v. 2016 |
| Shared corporate costs | | | $ | 5,991 |
| | $ | 3,061 |
| |
| Compensation and benefits | | $ | 5,412 |
| | $ | 898 |
| | | 5,767 |
| | 5,412 |
| |
| Base rate amortization of regulatory assets | | 3,264 |
| | — |
| | |
| Shared corporate costs | | 3,061 |
| | 2,378 |
| | |
| Consulting | | | 5,184 |
| | 512 |
| |
| Other | | 197 |
| | (2,475 | ) | | | 2,272 |
| | 2,949 |
| |
| Total increase | | $ | 11,934 |
| | $ | 801 |
| | | $ | 19,214 |
| | $ | 11,934 |
| |
Fiscal 2018 compared with fiscal 2017
The increase in O&M expense during fiscal 2018 was due primarily to:
increased shared corporate costs due primarily to increased headcount and incentives, along with additional expenses related to a voluntary early retirement program;
increased compensation and benefits as a result of voluntary early retirement program costs; and
increased consulting expenses due primarily to technology improvements.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Fiscal 2017 compared with fiscal 2016
The increase in O&M expense during fiscal 2017 was due primarily to:
increased compensation costs due primarily to increases in headcount, incentives, healthcare premiums, lower capitalized labor and increased pension/OPEB benefit costs related to changes in actuarial assumptions, partially offset by implementation of the spot rate method to measure interest and service cost components;
additional amortization of regulatory assets in other that are being recovered as a result of the settlement of the base rate case; and
increased shared corporate costs resulting primarily from increased software maintenance, incentives, postemployment costs and healthcare premiums.
Fiscal 2016 compared with fiscal 2015
The increase in O&M expense during fiscal 2016 was due primarily to:
increased shared corporate costs resulting primarily from increased head count and healthcare premiums, as well as increased temporary staffing and consulting services;
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
increased compensation costs at NJNG due primarily to increased head count and healthcare premiums, partially offset by reduced pension expense due to an increase in expected return on assets associated with a $30 million discretionary contribution in November 2015; partially offset by
lower consulting costs due primarily to reduced software maintenance and tax audit expenses, lower bad debt expense due primarily to a decrease in write-offs of customer receivables and lower maintenance and repairs due primarily to the much warmer winter weather in fiscal 2016.
Depreciation Expense
Depreciation expense increased $3.9 million in fiscal 2018, compared with fiscal 2017, as a result of additional utility plant being placed into service. Depreciation expense increased $1.5 million in fiscal 2017, compared with fiscal 2016, as a result of additional utility plant being placed into service, as well as an increase in the overall depreciation rate from 2.34 percent to 2.4 percent resulting from the settlement of the base rate case. Depreciation expense increased $4.7 million in fiscal 2016, compared with fiscal 2015, as a result of additional utility plant being placed into service.
Operating Income
Operating income decreased $51.1 million, or 33.7 percent, in fiscal 2018, compared with fiscal 2017, due primarily to the decrease in total utility gross margin of $27.7 million, as well as the increase in O&M and depreciation, as previously discussed. Operating income increased $25.4 million, or 20.1 percent, in fiscal 2017, compared with fiscal 2016, due primarily to theincrease the increase in total utility gross margin of $38.6 million, partially offset by the increase in O&M,as previously discussed. Operating income decreased $3.8 million, or 2.9 percent, in fiscal 2016, compared with fiscal 2015, due primarily to theincrease in depreciation, partially offset by the increase in total utility gross margin of $1.9 million, as previously discussed.
Income Tax Provision
Income tax provision decreased $45.4 million during fiscal 2018, compared with fiscal 2017, due primarily to the impacts of the change in the federal corporate tax rate resulting from the Tax Act. Income tax provision increased $8.5 million during fiscal 2017, compared with fiscal 2016, due primarily to an increase in pre-tax income, partially offset by increased costs associated with the removal of distribution main that was placed in service before 1981, for which the tax benefit is passed on to customers in base rates.
Net Income tax provision
Net income decreased $4.6$2.9 million duringto $84 million in fiscal 2016,2018, compared with fiscal 2015,2017, due primarily to:
ato decreased utility gross margin and increased O&M and depreciation, partially offset by the decrease in pre-tax income;
the revaluation of the deferred tax liability in fiscal 2015;
a change in the method of accounting for equity compensation due to the adoption of ASU 2016-09, which resulted in the recognition of excessincome tax benefits related to vested stock compensation for which the tax deduction exceeded the associated expense. See provision as previously discussed.Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the Accounting Standards Codification in the accompanying Consolidated Financial Statements for a more detailed discussion; and
an increase in costs of retiring assets placed into service prior to 1981.
Net Income
Net income increased $10.8 million to $86.9 million in fiscal 2017, compared with fiscal 2016, due primarily to an increase in operating income as discussed above, partially offset by an increase in the income tax provision as discussed above and interest expense associated with debt issued in June 2016.
Net income decreased $183,000 to $76.1 million in fiscal 2016, compared with fiscal 2015, due primarily to a decrease in operating income as discussed above, an increase in interest expense associated with higher long-term debt outstanding, partially offset by a decrease in the income tax provision as discussed above and an increase in other income related to AFUDC interest earned on infrastructure projects.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Clean Energy Ventures Segment
Overview
Our Clean Energy Ventures segment actively pursues opportunities in the cleanrenewable energy markets, including solar and onshore wind.markets. Clean Energy Ventures has entered into various agreements to install solar net-metered systems for residential and commercial customers, as well as large commercial grid-connected projects. In addition, Clean Energy Ventures has entered into various long-term agreements, including PPAs, to supply energy from wind and solar projects.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Solar
Since its inception, Clean Energy Ventures has constructed a total of 189.1 MW of solar capacitySolar projects placed in service and has an additional 11.2 MW under construction.
Solarrelated expenditures for the fiscal years ended September 30, are as follows:
| | | ($ in Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Placed in service | Projects | MW | Costs | Projects | MW | Costs | Projects | MW | Costs | Projects | MW | Costs | Projects | MW | Costs | Projects | MW | Costs |
Grid-connected (1) | 2 |
| 20.0 |
| $ | 62,700 |
| 5 |
| 21.8 |
| $ | 51,240 |
| 4 |
| 26.1 |
| $ | 66,424 |
| 3 |
| 33.7 |
| $ | 70,216 |
| 2 |
| 20.0 |
| $ | 62,700 |
| 5 |
| 21.8 |
| $ | 51,240 |
|
| Net-metered: | | | | | | | | | | | | |
Commercial (1) | 3 |
| 7.1 |
| 19,714 |
| — |
| — |
| 3 |
| 1 |
| 0.4 |
| 1,382 |
| — |
| — |
| 74 |
| 3 |
| 7.1 |
| 19,714 |
| — |
| — |
| 3 |
|
| Residential | 1,300 |
| 12.4 |
| 37,901 |
| 1,123 |
| 10.4 |
| 34,318 |
| 829 |
| 7.8 |
| 24,973 |
| 910 |
| 8.5 |
| 27,342 |
| 1,300 |
| 12.4 |
| 37,901 |
| 1,123 |
| 10.4 |
| 34,318 |
|
| Total placed in service | 1,305 |
| 39.5 |
| $ | 120,315 |
| 1,128 |
| 32.2 |
| $ | 85,561 |
| 834 |
| 34.3 |
| $ | 92,779 |
| 913 |
| 42.2 |
| $ | 97,632 |
| 1,305 |
| 39.5 |
| $ | 120,315 |
| 1,128 |
| 32.2 |
| $ | 85,561 |
|
| |
| (1) | Includes projects subject to sale-leaseback arrangements. |
During fiscal 2017,Since its inception, Clean Energy Ventures enteredhas constructed a total of 231.3 MW of solar capacity and has an additional 19.6 MW under construction. Projects that are placed in service through December 31, 2019, qualify for a 30 percent federal ITC. The credit will decline to 26 percent for property under construction during 2020 and to 22 percent for property under construction during 2021. The ITC will be reduced to 10 percent for any property that is under construction before 2022, but not placed in service before 2024.
Clean Energy Ventures may enter into sale-leaseback arrangements for twotransactions to sell certain of its commercial solar projects,assets concurrent with agreements to lease the assets back over a period of six to 15 years. The Company will continue to operate the solar assets and are responsible for whichrelated expenses and entitled to retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects werehave been transferred to the buyer. Duringbuyer; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. As of September 30, 2018, Clean Energy Ventures has entered into five sale-leaseback transactions, three during fiscal 2018 with costs of $70.2 million and two during fiscal 2017 excluding those costwith costs of $31.1 million. Clean Energy Ventures did not enter into sale-leasebacks during fiscal 2016.
Excluding the project costs related to the commercial solar projects of $31.1 million that were included in the sale-leaseback transactions, the Company had $27.4 million, $89.2 million and $85.6 million of solar-related capital expenditures were ITC eligible. During fiscal 2016 and 2015, all solar-related capital expenditures were ITC eligible. We estimate total solar-related capital expenditures for ITC eligible projectsITC-eligible during fiscal 2018, to be between $132 million2017 and $140 million.2016, respectively, which were recognized in income tax (benefit) provision on the Consolidated Statements of Operations when the assets were placed in service.
As part of its solar investment portfolio, Clean Energy Ventures operates a residential solar program, The Sunlight Advantage®, thatwhich provides qualifying homeowners the opportunity to have a solar system installed at their home with no installation or maintenance expenses. Clean Energy Ventures owns, operates and maintains the system over the life of the contract in exchange for monthly lease payments.
Once a solar installation has received the proper certifications and commences operations, each MWh of electricity produced creates an SREC that represents the renewable energy attribute of the solar-electricity generated that can be sold to third parties, predominantly load-serving entities that are required to comply with the solar requirements under New Jersey’s renewable portfolio standard. In addition, under
SREC activity for the recently updated federal tax guidelines, projects that are placed in service through December 31, 2019, qualify for afiscal years ended September 30, is as follows:
|
| | | | | | |
| | 2018 | 2017 | 2016 |
| Inventory balance as of October 1, | 48,357 |
| 24,135 |
| 33,203 |
|
| SRECs generated | 245,147 |
| 197,521 |
| 160,009 |
|
| SRECs delivered | (188,312 | ) | (173,299 | ) | (169,077 | ) |
| Inventory balance as of September 30, | 105,192 |
| 48,357 |
| 24,135 |
|
SRECs generated increased 24.1 percent federal ITC. The credit will decline to 26and 23.4 percent for property under construction during 2020the fiscal years ended September 30, 2018 and to 22 percent for property under construction during 2021.2017, respectively, compared with the previous fiscal years. The ITC will be reduced to 10 percent for any property that is under construction before 2022, but not placedaverage SREC sales price was $217 in service before 2024.fiscal 2018, $233 in fiscal 2017 and $214 in fiscal 2016.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Clean Energy Ventures hedges a portion of its expected SREC production through the use of forward sales contracts. The following table reflects the hedged percentage of SREC inventory and projected SREC production related to its in-service commercial and residential assets as of September 30, 2018:
|
| |
Energy Year (1) | Percent of SRECs Hedged |
| 2019 | 91% |
| 2020 | 86% |
| 2021 | 58% |
| |
| (1) | Energy years are compliance periods for New Jersey’s renewable portfolio standard that run from June 1 to May 31. |
There are no direct costs associated with the production of SRECs by our solar assets. All related costs are included as a component of O&M expenses on the Consolidated Statements of Operations, including such expenses as facility maintenance and various fees.
Onshore WindEnergy Services Segment
As of September 30, 2018, Energy Services leases office space in Wall Township, New Jersey, Houston, Texas, Charlotte, North Carolina and Allentown, Pennsylvania.
Midstream Segment
As of September 30, 2018, Steckman Ridge owned and/or leased storage rights on approximately 6,300 acres of land in Bedford County, Pennsylvania, with a FERC-regulated natural gas storage facility with up to 12 Bcf of working gas capacity. Equipment on the property includes a compressor station, gathering pipelines and pipeline interconnections. As of September 30, 2018, PennEast owned 74 acres of land in Carbon County, Pennsylvania and 58.7 acres of land in Mercer County, New Jersey.
New Jersey Resources Corporation
Part I
ITEM 2. PROPERTIES (Continued)
All Other Business Operations
As of September 30, 2018, CR&R’s real estate portfolio consisted of 35 acres of undeveloped land in Atlantic County, New Jersey with a net book value of $1.4 million.
NJRHS leases service centers in Dover, New Jersey and Wall Township, New Jersey.
Capital Expenditure Program
Clean Energy Ventures investsSee Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of anticipated fiscal 2019 and 2020 capital expenditures, as applicable to our reporting segments and business operations.
ITEM 3. LEGAL PROCEEDINGS
Manufactured Gas Plant Remediation
NJNG is responsible for the remedial cleanup of five MGP sites, dating back to gas operations in smallthe 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 mid-size onshore wind projectsdetermine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action, where warranted, under Administrative Consent Orders or a Memoranda of Agreement with the NJDEP.
NJNG may recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. NJNG recovered approximately $9.4 million annually through its SBC RAC. On July 25, 2018, the BPU approved NJNG’s annual SBC application requesting a reduction in the RAC, which decreased the annual recovery to $7 million, effective September 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, and an increase in the RAC, which will result in an annual increase of approximately $1.4 million, effective April 1, 2019. As of September 30, 2018, $33 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Consolidated Balance Sheets.
NJNG periodically, and at least annually, performs an environmental review of MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester and Toms River, including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that fit its investment profiletotal future expenditures to remediate and hasmonitor the 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 $117.7 million to $204.1 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a totalrange of 126.6 MWpossible 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 wind capacitythe range. Accordingly, as of September 30, 2017.2018, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $130.8 million on the Consolidated Balance Sheets, based on the most likely amount. This was reduced from $149 million in fiscal 2017, due to the completion of remediation work at certain sites and a reduction to the remediation scope at another site. The wind projectsactual 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 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
We are 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 connection with the conduct of business, certain of which litigation matters are described in Note 13. Commitments and Contingent Liabilities eligiblein the accompanying Consolidated Financial Statements. 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, we 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.
New Jersey Resources Corporation
Part I
ITEM 3. LEGAL PROCEEDINGS (Continued)
In accordance with applicable accounting guidance, we establish reserves for PTCs litigation for those matters that present loss contingencies as to which it is both probable that a 10-year period following commencementloss will be incurred and the amount of such loss can be reasonably estimated. Based upon currently available information, we believe that the results of litigation that is currently pending, taken together, will not have a materially adverse effect on our financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts reserved.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable
ITEM 4A. EXECUTIVE OFFICERS OF THE COMPANY
The Company’s Executive Officers and have PPAstheir age, position and business experience during the past five years are set forth below.
|
| | | |
| Name | Age | Officer since | Office held during last five years |
| Laurence M. Downes | 61 | 1986 | Chairman of the Board (September 1996 - present)
Chief Executive Officer (July 1995 - present)
President (July 1995 - September 2018) |
| Patrick J. Migliaccio | 44 | 2013 | Senior Vice President and Chief Financial Officer (January 2016 - present)
Vice President, Finance and Accounting (November 2014 - December 2015)
Treasurer (August 2013 - May 2015) |
| Stephen D. Westhoven | 50 | 2004 | President and Chief Operating Officer (October 2018 - present)
Executive Vice President and Chief Operating Officer (November 2017 - September 2018)
Senior Vice President and Chief Operating Officer, NJRES and NJRCEV (October 2016 -
October 2017)
Senior Vice President, NJRES (May 2010 - September 2016) |
| Glenn C. Lockwood | 57 | 1990 | Executive Vice President (January 2011 - present)
Chief Financial Officer (September 1995 - December 2015) |
| Amanda E. Mullan | 52 | 2015 | Senior Vice President and Chief Human Resources Officer (January 2017 - present)
Vice President and Chief Human Resources Officer (April 2015 - December 2016)
Senior Vice President of HR, N. America, Willis Group Holdings, a risk management and
insurance intermediary (April 2012 - April 2015) |
| Jacqueline K. Shea | 54 | 2016 | Vice President and Chief Information Officer (June 2016 - present)
Chief Information Officer, Godiva Chocolatier, a manufacturer of premium fine chocolates and
related products (March 2011 - May 2016) |
| Nancy A. Washington | 54 | 2017 | Senior Vice President and General Counsel (March 2017 - present)
Senior Vice President and Chief Litigation Counsel, CIT Group Inc., a Livingston, NJ-based
financial services firm (September 2010 - March 2017)
|
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 various terms in place, which typically govern the saleSeptember 30, 2018, NJR had 52,673 holders of energy, capacity and/or renewable energy credits. An $89 million, 39.9 MW wind project in Somerset County, Pennsylvania was completed in December 2016.record of its common stock.
Clean Energy Ventures’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. 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 earlier terminated 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, 2018:
|
| | | | | | | | |
| 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 |
| 7/01/18 - 7/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 8/01/18 - 8/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 9/01/18 - 9/30/18 | — | $ | — |
| — |
| | 2,431,053 |
| Total | — | $ | — |
| — |
| | 2,431,053 |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA
CONSOLIDATED FINANCIAL STATISTICS
|
| | | | | | | | | | | | | | | |
| (Thousands, except per share data) | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
| SELECTED FINANCIAL DATA | | | | | |
| Operating revenues | $ | 2,915,109 |
| $ | 2,268,617 |
| $ | 1,880,905 |
| $ | 2,733,987 |
| $ | 3,738,145 |
|
| Gas purchases | $ | 2,275,342 |
| $ | 1,703,767 |
| $ | 1,352,686 |
| $ | 2,085,645 |
| $ | 3,139,525 |
|
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Total assets | $ | 4,143,664 |
| $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 3,284,357 |
| $ | 3,125,388 |
|
| Common stock equity | $ | 1,418,978 |
| $ | 1,236,643 |
| $ | 1,166,591 |
| $ | 1,106,956 |
| $ | 966,166 |
|
Long-term debt (1) (2) | $ | 1,180,619 |
| $ | 997,080 |
| $ | 1,055,038 |
| $ | 843,595 |
| $ | 598,209 |
|
| | | | | | |
| COMMON STOCK DATA | | | | | |
| Earnings per share-basic | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Earnings per share-diluted | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Dividends declared per share | $1.11 | $1.038 | $0.975 | $0.915 | $0.855 |
| | | | | | |
| NON-GAAP RECONCILIATION | | | | | |
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,770 |
| (11,241 | ) | 46,883 |
| (38,681 | ) | 28,534 |
|
| Tax effect | (4,512 | ) | 4,062 |
| (17,018 | ) | 14,391 |
| (10,492 | ) |
| Effects of economic hedging related to natural gas inventory | (22,570 | ) | 38,470 |
| (36,816 | ) | (8,225 | ) | 26,639 |
|
| Tax effect | 7,362 |
| (13,964 | ) | 13,364 |
| 3,058 |
| (9,794 | ) |
Net financial earnings (3) | $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 176,857 |
|
| | | | | | |
| Basic earnings per share | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.31 |
| (0.13 | ) | 0.55 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.13 | ) |
| Effects of economic hedging related to natural gas inventory | (0.26 | ) | 0.45 |
| (0.43 | ) | (0.10 | ) | 0.32 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.16 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-basic (3) | $2.74 | $1.73 | $1.61 | $1.78 | $2.10 |
| | | | | | |
| Diluted earnings per share | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.30 |
| (0.13 | ) | 0.54 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.12 | ) |
| Effects of economic hedging related to natural gas inventory | (0.25 | ) | 0.44 |
| (0.42 | ) | (0.10 | ) | 0.31 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.15 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-diluted (3) | $2.72 | $1.71 | $1.59 | $1.76 | $2.08 |
| |
| (1) | Includes long-term capital leases of $26.4 million, $28.9 million, $30.7 million, $35.7 million and $40.4 million, respectively. |
| |
| (2) | Includes long-term solar asset financing obligation of $89.8 million and $28.2 million in fiscal 2018 and 2017, respectively. |
| |
| (3) | NFE is a non-GAAP financial measure that eliminates the timing differences surrounding the recognition of certain derivative gains or losses, to effectively match the earnings effects of economic hedges associated with the physical sale or purchase of gas and, therefore, eliminate the impact of volatility to GAAP earnings associated with the related derivative instruments. For further discussion of this financial measure, see the Energy Services segment in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA (Continued)
NJNG OPERATING STATISTICS
|
| | | | | | | | | | | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
Operating revenues ($ in thousands) | | | | | |
| Residential | $ | 441,486 |
| $ | 395,315 |
| $ | 345,597 |
| $ | 466,464 |
| $ | 469,831 |
|
| Commercial, industrial and other | 95,351 |
| 98,777 |
| 80,994 |
| 106,505 |
| 110,740 |
|
| Firm transportation | 65,256 |
| 73,206 |
| 69,696 |
| 77,974 |
| 86,131 |
|
| Total residential and commercial | 602,093 |
| 567,298 |
| 496,287 |
| 650,943 |
| 666,702 |
|
| Interruptible | 7,522 |
| 7,970 |
| 8,867 |
| 10,049 |
| 9,384 |
|
| Total system | 609,615 |
| 575,268 |
| 505,154 |
| 660,992 |
| 676,086 |
|
| BGSS incentive programs | 122,250 |
| 120,369 |
| 89,192 |
| 120,978 |
| 143,329 |
|
| Total operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 819,415 |
|
| Throughput (Bcf) | | | | | |
| Residential | 45.5 |
| 40.7 |
| 36.9 |
| 45.9 |
| 43.1 |
|
| Commercial, industrial and other | 8.9 |
| 8.7 |
| 7.3 |
| 9.6 |
| 8.2 |
|
| Firm transportation | 15.5 |
| 14.4 |
| 14.1 |
| 16.0 |
| 17.7 |
|
| Total residential and commercial | 69.9 |
| 63.8 |
| 58.3 |
| 71.5 |
| 69.0 |
|
| Interruptible | 46.2 |
| 55 |
| 61.5 |
| 47.1 |
| 10.5 |
|
| Total system | 116.1 |
| 118.8 |
| 119.8 |
| 118.6 |
| 79.5 |
|
| BGSS incentive programs | 150.2 |
| 178.4 |
| 216.7 |
| 222.4 |
| 180.8 |
|
| Total throughput | 266.3 |
| 297.2 |
| 336.5 |
| 341.0 |
| 260.3 |
|
| Customers at year-end | | | | | |
| Residential | 474,495 |
| 460,013 |
| 448,273 |
| 437,979 |
| 422,742 |
|
| Commercial, industrial and other | 28,037 |
| 26,947 |
| 26,218 |
| 25,541 |
| 24,684 |
|
| Firm transportation | 36,126 |
| 42,790 |
| 46,608 |
| 48,673 |
| 56,777 |
|
| Total residential and commercial | 538,658 |
| 529,750 |
| 521,099 |
| 512,193 |
| 504,203 |
|
| Interruptible | 31 |
| 33 |
| 34 |
| 35 |
| 37 |
|
| BGSS incentive programs | 28 |
| 27 |
| 30 |
| 24 |
| 34 |
|
| Total customers at year-end | 538,717 |
| 529,810 |
| 521,163 |
| 512,252 |
| 504,274 |
|
Interest coverage ratio (1) | 6.35 |
| 7.96 |
| 8.97 |
| 9.57 |
| 10.24 |
|
| Average therm use per customer | | | | | |
| Residential | 959 |
| 885 |
| 824 |
| 1,049 |
| 1,020 |
|
| Commercial, industrial and other | 10,992 |
| 11,183 |
| 11,378 |
| 9,799 |
| 4,466 |
|
| Degree days | 4,537 |
| 4,129 |
| 3,867 |
| 5,015 |
| 5,080 |
|
Weather as a percent of normal (2) | 99.5 | % | 90.0 | % | 82.5 | % | 108.3 | % | 109.6 | % |
| Number of employees | 686 |
| 680 |
| 670 |
| 649 |
| 626 |
|
| |
| (1) | NJNG’s income from operations divided by interest expense. |
| |
| (2) | Normal heating degree days are based on a 20-year average, calculated based upon three reference areas representative of NJNG’s service territory. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
Critical Accounting Policies
We prepare our financial statements in accordance with GAAP. Application of these accounting principles requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingencies during the reporting period. We regularly evaluate our estimates, including those related to the calculation of the fair value of derivative instruments, regulatory assets, income taxes, pension and postemployment benefits other than pensions and contingencies related to environmental matters and litigation. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.
Regulatory Accounting
NJNG maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and recognizes the impact of regulatory decisions on its financial statements. As a result of the ratemaking process, NJNG is required to apply the accounting principles in ASC 980, Regulated Operations, which differ in certain respects from those applied by unregulated businesses. Specifically, NJNG records regulatory assets when it is probable that certain operating costs will be recoverable from customers in future periods and records regulatory liabilities associated with probable future obligations to customers.
NJNG’s BGSS requires it to project its annual natural gas costs and provides the ability, subject to BPU approval, to recover or refund the difference, if any, of such actual costs compared with the projected costs included in prices through a BGSS charge to customers. Any underrecovery or overrecovery is recorded as a regulatory asset or liability on the Consolidated Balance Sheets and reflected in the BGSS charge to customers in subsequent years.
As recovery of regulatory assets is subject to BPU approval, if there are any changes in future regulatory positions, which indicate that recovery of all or a portion of a regulatory asset is not probable, the related cost would be charged to income in the period of such determination.
Impairment of Long-lived assets
Property, plant and equipment and intangible assets are reviewed periodically 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. When an impairment indicator is present, the Company determines if the carrying value of the asset is recoverable by comparing it to the expected undiscounted future cash flows. If 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.
Equity method investments are subject to a variety of factors, such as timing of construction schedules, permittingreviewed periodically when changes in facts and regulatory processes, volatility of energy prices,circumstances indicate that the ability to secure PPAs, delays related to electric grid interconnection, which can affect our ability to commence operations on a timely basis or at all, economic trends,current fair value may be less than the ability to access capital or allocation of capital to other investments or business opportunitiesasset’s carrying amount and other unforeseen events. Solar projects not placedrecord an impairment charge in service, as originally planned prioran amount equal to the endexcess of a reporting period, may result in a failurethe carrying value of the asset over its fair value if the decline is other than temporary.
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 qualify for ITCs. Further,designate any of our physical and financial natural gas commodity derivatives as accounting hedges, changes in the fair value of Energy Services’ commodity derivatives are recognized in earnings, as they occur, as a component of operating revenues or gas purchases on the Consolidated Statements of Operations. Changes in the fair value of foreign exchange contracts are recognized in 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 and/or a combination of those items. Energy Services’ portfolio is valued using the most current and reasonable market information. If the price underlying a physical commodity transaction does not represent a visible and liquid market, Energy Services may utilize additional published pipeline tariff information and/or other services to determine an equivalent market price. As of September 30, 2018, fair value of its derivative assets and liabilities reported on the Consolidated Balance Sheets that is based on such pricing is considered immaterial.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
on the unhedged portion of SREC production could haveShould there be a significant adversechange in the underlying market prices or pricing assumptions, Energy Services may experience a significant impact on earnings with some offset expected from higher wind energy market prices dueits financial position, results of operations and cash flows. Refer to the PTC phase out and/or improved efficiencies from lower costsItem 7A. Quantitative and Qualitative Disclosures About Market Risks for related turbine technology.
Wind projects for which construction of a facility begins after December 31, 2016 through December 31, 2019, will be subject to reduced PTCs and could have a significant adverse impact on 10 years of forward earnings. PTCs will be phased out from 100 percent in 2016 to 80 percent in 2017, 60 percent in 2018, 40 percent in 2019 and zero thereafter. In addition, since the primary contributors toward the value of qualifying clean energy projects are tax incentives and SRECs, changes in the federal statutessensitivity analysis related to the ITC or PTC orimpact to derivative fair values resulting from changes in commodity prices. The valuation methods we use to determine fair values remained consistent for fiscal 2018, 2017 and 2016. We apply a discount to our derivative assets to factor in an adjustment associated with the marketplace and/or relevant legislation surrounding renewable clean energy credits, could significantly affect earnings.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.
Operating ResultsGains 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.
Clean Energy Ventures’Ventures hedges certain of its expected production of SRECs through forward and futures contracts. Clean Energy Ventures intends to physically deliver all SRECs it sells and recognizes SREC revenue as operating revenue on the Consolidated Statements of Operations upon delivery of the underlying SREC.
We have not designated any derivatives as fair value or cash flow hedges as of September 30, 2018 and 2017.
Income Taxes and Credits
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 taxable items. We use the asset and liability method to determine and record deferred tax assets, representing future tax benefits, and deferred tax liabilities, representing future taxes payable, resulting from the differences between the financial resultsreporting amount and the corresponding tax basis of the assets and liabilities using the enacted rates expected to be in effect at the time the differences are settled. An offsetting valuation allowance is recorded when it is more likely than not that some or all of the deferred income tax assets won’t be realized. Any significant changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a material change to earnings and cash flows. For a more detailed description of Income Taxes see Note 12. Income Taxes in the accompanying Consolidated Financial Statements.
For state income tax and other taxes, estimates and judgments are required with respect to the apportionment among the various jurisdictions. In addition, we operate within multiple tax jurisdictions and are subject to audits in these jurisdictions. These audits can involve complex issues, which may require an extended period of time to resolve. We maintain a liability for the fiscalestimate of potential income tax exposure and, in our opinion, adequate provisions for income taxes have been made for all years ended September 30, are summarized as follows:
|
| | | | | | | | | |
| (Thousands) | 2017 | 2016 | 2015 |
| Operating revenues | $ | 64,394 |
| $ | 53,540 |
| $ | 32,513 |
|
| Operating expenses | | | |
| Operation and maintenance | 23,448 |
| 18,897 |
| 15,248 |
|
| Depreciation and amortization | 31,834 |
| 23,971 |
| 17,297 |
|
| Other taxes | 1,209 |
| 900 |
| 726 |
|
| Total operating expenses | 56,491 |
| 43,768 |
| 33,271 |
|
| Operating income (loss) | 7,903 |
| 9,772 |
| (758 | ) |
| Other income, net | 2,072 |
| 2,333 |
| 1,526 |
|
| Interest expense, net | 16,263 |
| 10,304 |
| 7,635 |
|
| Income tax (benefit) | (31,161 | ) | (26,592 | ) | (26,968 | ) |
| Net income | $ | 24,873 |
| $ | 28,393 |
| $ | 20,101 |
|
Operating RevenuesOccasionally, the federal and state taxing authorities determine that it is necessary to make certain changes to the income tax laws. These changes may include but are not limited to changes in the tax rates and/or the treatment of certain items of income or expense. Accounting guidance requires that the Company reflect the effect of tax laws or tax rates at the date of enactment. Additionally, the Company is required to re-measure its deferred tax assets and liabilities as of the date of enactment. For non-regulated entities, the effect of changes in tax rates and/or tax laws are required to be included in income from continuing operations for the period that includes the enactment date. For regulated entities, if as the result of an action by a regulator it is probable that the future increase or decrease in taxes payable for items such as changes in tax law or rates will be recovered from or returned to customers through future rates, an asset or liability shall be recognized for that probable increase or decrease in future revenue. Additionally, accounting guidance also requires that regulatory liabilities/assets be considered a temporary difference for which a deferred tax asset/liability shall be recognized. As a result, NJNG grossed up its regulatory liability to reflect the required accounting for the tax effects of the revaluation.
Operating revenues increased $10.9 million and $21 million during fiscal 2017 and 2016, respectively, comparedConcurrent with the previous fiscal years, and is comprisedenactment of the following:
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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. We have no reason to believe that we have any future obligations associated with unrecognized tax benefits; therefore, as of September 30, 2018 and 2017, we have not recorded any liabilities related to uncertain tax positions. 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.
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. For our unregulated subsidiaries, we recognize ITCs as a reduction to income tax expense when the property is placed in service.
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.
Environmental Costs
At the end of each fiscal year, NJNG, with the assistance of an independent consulting firm, updates the environmental review of its MGP sites, including its potential liability for investigation and remedial action. From this review, NJNG estimates expenditures necessary to remediate and monitor these MGP sites. NJNG’s estimate of these liabilities is developed from then-currently available facts, existing technology and current laws and regulations.
In accordance with accounting standards for contingencies, NJNG’s policy is to record a liability when it is probable that the cost will be incurred and can be reasonably estimated. NJNG will determine a range of liabilities and will record the most likely amount. If no point within the range is more likely than any other, NJNG will accrue the lower end of the range. Since we believe that recovery of these expenditures, as well as related litigation costs, is possible through the regulatory process, we have recorded a regulatory asset corresponding to the related accrued liability. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Consolidated Balance Sheets, which is based on the most likely amount.
The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations and the ultimate ability of other responsible parties to pay, as well as the potential impact of any litigation and any insurance recoveries. Previously incurred remediation costs, net of recoveries from customers and insurance proceeds received are included in regulatory assets on the Consolidated Balance Sheets.
If there are changes in the regulatory position surrounding these costs, or should actual expenditures vary significantly from estimates in that these costs are disallowed for recovery by the BPU, such costs would be charged to income in the period of such determination. See the Legal Proceedings section in Note 13. Commitments and Contingent Liabilities for more details.
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 impacted by actual employee demographics including age, compensation levels and employment periods, the level of contributions made to the plans, changes in long-term interest rates and the return on plan assets. Changes made to the provisions of the plans or healthcare legislation may also impact current and future postemployment employee benefit costs. Postemployment employee benefit costs may also be significantly affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets, changes in mortality tables, health care cost trends and discount rates used in determining the PBO. In determining the PBO and cost amounts, assumptions can change from period to period and could result in material changes to net postemployment employee benefit periodic costs and the related liability recognized by us.
Our postemployment employee benefit plan assets consist primarily of U.S. equity securities, international equity securities and fixed-income investments, with a targeted allocation of 34 percent, 17 percent and 41 percent, respectively. Fluctuations in actual market returns, as well as changes in interest rates, may result in increased or decreased postemployment employee benefit costs in future periods. Postemployment employee benefit expenses are included in O&M expense on the Consolidated Statements of Operations.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The following is a summary of a sensitivity analysis for each actuarial assumption:
|
| | | | | | | | | | | | | |
| Pension Plans | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (37,153 | ) | | | $ | (4,095 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 46,432 |
| | | $ | 4,756 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (2,619 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 2,619 |
| |
|
| | | | | | | | | | | | | |
| Other Postemployment Benefits | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (28,595 | ) | | | $ | (2,728 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 36,736 |
| | | $ | 3,406 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (713 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 714 |
| |
| | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Health care cost trend rate | 1.00 |
| % | | $ | 36,260 |
| | | $ | 3,838 |
| |
| Health care cost trend rate | (1.00 | ) | % | | $ | (28,743 | ) | | | $ | (2,991 | ) | |
On October 1, 2016, we changed our approach used to measure the service and interest cost components of our net periodic benefit costs. Previously, we estimated service cost and interest cost based on a single weighted-average discount rate from the yield curve used to measure our projected benefit obligation. We determine our service and interest cost based upon duration-specific spot rates that are aligned to each year’s future benefit payments. Under the new approach, net periodic benefit costs will be lower during periods of low interest rates and upward-sloping yield curves. Conversely, in a downward-sloping yield curve environment, costs could increase. Refer to Note 10. Employee Benefit Plans in the accompanying Consolidated Financial Statements for further discussion of our change in method.
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 an energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in the United States and Canada. In addition, we invest in clean energy projects and midstream assets and provide various repair, sales and installations services. A more detailed description of our organizational structure can be found in Item 1. Business.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Reporting Segments
We have four primary reporting segments as presented in the chart below:
In addition to our four reporting segments, we have non-utility operations that either provide corporate support services or do not meet the criteria to be treated as a separate reporting segment. These operations, which comprise Home Services and Other, include: appliance repair services, sales and installations at NJRHS and commercial real estate holdings at CR&R.
The Tax Act
On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. Since our fiscal year end is September 30, it is required by the Internal Revenue Code to calculate a statutory rate based upon the federal tax rates in effect before and after the effective date of the change in the taxable year that includes the effective date. Accordingly, we applied a federal statutory tax rate of 24.5 percent during fiscal 2018 and the enacted rate of 21 percent beginning in fiscal 2019.
As a result of the Tax Act, we revalued our deferred tax assets and liabilities at the enactment date to reflect the rates expected to be in effect when the deferred tax assets and liabilities are realized or settled. As of September 30, 2018, NJNG had a regulatory liability that included excess deferred income taxes of $205.4 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles. During fiscal 2018, we recognized an income tax benefit of approximately $17 million for NJNG and approximately $59.6 million for the remaining entities on the Consolidated Statements of Operations. See Note 12. Income Taxes for a more detailed discussion on the Tax Act.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
A summary of our consolidated results in net income and assets by reporting segment and operations for the fiscal years ended September 30, is as follows:
|
| | | | | | | | | | | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| | Net Income | Assets | Net Income | Assets | Net Income | Assets |
| Natural Gas Distribution | $ | 84,048 |
| $ | 2,663,054 |
| $ | 86,930 |
| $ | 2,519,578 |
| $ | 76,104 |
| $ | 2,517,401 |
|
| Clean Energy Ventures | 75,849 |
| 865,018 |
| 24,873 |
| 771,340 |
| 28,393 |
| 665,696 |
|
| Energy Services | 53,139 |
| 396,852 |
| 476 |
| 398,277 |
| 14,265 |
| 327,626 |
|
| Midstream | 24,367 |
| 242,069 |
| 12,857 |
| 232,806 |
| 9,406 |
| 186,259 |
|
| Home Services and Other | (3,555 | ) | 114,732 |
| 6,811 |
| 114,801 |
| 2,882 |
| 109,487 |
|
Intercompany (1) | (412 | ) | (138,061 | ) | 118 |
| (108,295 | ) | 622 |
| (87,899 | ) |
| Total | $ | 233,436 |
| $ | 4,143,664 |
| $ | 132,065 |
| $ | 3,928,507 |
| $ | 131,672 |
| $ | 3,718,570 |
|
| |
| (1) | Consists of transactions between subsidiaries that are eliminated in consolidation. |
Net Income
The primary drivers of the changes noted above, which are described in more detail in the individual segment discussions, are discussed below.
The increase in net income of $101.4 million during fiscal 2018, compared with fiscal 2017, was primarily driven by increased operating income at Energy Services related to colder weather, resulting in increased storage withdrawals due to higher demand coupled with higher volatility resulting in an increase in natural gas price spreads. Net income also increased due to impacts from the Tax Act, including a net income tax benefit of $59.6 million and a decrease in tax expense due to the lower tax rate, which was partially offset by increased O&M expense.
The increase in net income of $393,000 during fiscal 2017, compared with fiscal 2016, was primarily driven by increased margin at our Natural Gas Distribution segment due primarily to increased base rates which were effective October 1, 2016, increased other income at Home Services and Other due to the sale of available for sale securities, increased equity in earnings of affiliates at Midstream and increased revenues and PTCs at Clean Energy Ventures. These increases were partially offset by decreased operating income at Energy Services due primarily to a decrease of $16.4 million related to changes in the value of financial hedges and a decrease at Clean Energy Ventures due primarily to increased depreciation, operating and interest expenses.
Assets
The increase in assets during fiscal 2018, compared with fiscal 2017, was due primarily to additional utility plant at our Natural Gas Distribution segment and an advance payment of $10 million for the IEC acquisition, partially offset by a decrease in regulatory assets at our Natural Gas Distribution segment, as well as a decrease in the market value of the DM Common Units at Midstream.
The increase in assets during fiscal 2017, compared with fiscal 2016, was due primarily to additional solar expenditures at Clean Energy Ventures, the acquisition of Talen's wholesale and retail energy contract assets at Energy Services, increased PennEast capital contributions and an increase in the market value of our DM Common Units at Midstream, along with additional utility plant expenditures at our Natural Gas Distribution segment.
Non-GAAP Financial Measures
Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. Energy Services economically hedges its natural gas inventory with financial derivative instruments and calculates the related tax effect based on the statutory rate. 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 gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. To the extent we utilize forwards or futures to hedge forecasted SREC production, unrealized gains and losses are also eliminated for NFE purposes.
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 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. 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, except per share data) | 2018 | 2017 | 2016 |
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| Add: | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,770 |
| (11,241 | ) | 46,883 |
|
| Tax effect | (4,512 | ) | 4,062 |
| (17,018 | ) |
Effects of economic hedging related to natural gas inventory (1) | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Tax effect | 7,362 |
| (13,964 | ) | 13,364 |
|
| Net financial earnings | $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
|
| | | | |
| Basic earnings per share | $ | 2.66 |
| $ | 1.53 |
| $ | 1.53 |
|
| Add: | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.31 |
| (0.13 | ) | 0.55 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) |
Effects of economic hedging related to natural gas inventory (1) | (0.26 | ) | 0.45 |
| (0.43 | ) |
| Tax effect | 0.08 |
| (0.17 | ) | 0.16 |
|
| Basic net financial earnings per share | $ | 2.74 |
| $ | 1.73 |
| $ | 1.61 |
|
| |
| (1) | Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period. |
NFE by reporting segment and other operations for the fiscal years ended September 30, discussed in more detail within the operating results sections of each segment, is summarized as follows:
|
| | | | | | | | | | | | | | | | | |
| (Thousands) | 2018 | | 2017 | | 2016 |
| Natural Gas Distribution | $ | 84,048 |
| 35 | % | | $ | 86,930 |
| 58 | % | | $ | 76,104 |
| 55 | % |
| Clean Energy Ventures | 75,849 |
| 32 |
| | 24,873 |
| 17 |
| | 28,393 |
| 20 |
|
| Energy Services | 60,378 |
| 25 |
| | 18,554 |
| 12 |
| | 21,934 |
| 16 |
|
| Midstream | 24,367 |
| 10 |
| | 12,857 |
| 9 |
| | 9,406 |
| 7 |
|
| Home Services and Other | (3,829 | ) | (2 | ) | | 6,811 |
| 4 |
| | 2,882 |
| 2 |
|
Eliminations (1) | (327 | ) | — |
| | (633 | ) | — |
| | (634 | ) | — |
|
| Total | $ | 240,486 |
| 100 | % | | $ | 149,392 |
| 100 | % | | $ | 138,085 |
| 100 | % |
| |
| (1) | Consists of transactions between subsidiaries that are eliminated in consolidation. |
The increase in NFE during fiscal 2018, compared with fiscal 2017, was driven primarily by higher financial margin generated at Energy Services due primarily to colder weather, resulting in increased storage withdrawals due to higher demand coupled with higher volatility, allowing Energy Services to capture additional margin from natural gas price spreads. The increase in NFE also included a net income tax benefit of $59.6 million associated with the Tax Act, as previously discussed.
The increase in NFE during fiscal 2017, compared with fiscal 2016, was driven primarily by increases at our Natural Gas Distribution segment, Midstream and Home Services and Other, as previously discussed, partially offset by lower financial margin at Energy Services due primarily to lower sales volumes and fewer market opportunities and the decrease at Clean Energy Ventures, as previously discussed.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Natural Gas Distribution Segment
Overview
Our Natural Gas Distribution segment is comprised of NJNG, a natural gas utility that provides regulated retail natural gas service in central and northern New Jersey to approximately 538,700 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 can negatively impact customer growth, operating and financing costs, fluctuations in commodity prices and customer conservation efforts. These risks include, but are not limited to, adverse economic conditions, customer usage, 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.
In addition, NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered to customers on an annual basis. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG receives most of its natural gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the year.
As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 3. Regulation in the accompanying Consolidated Financial Statements for a more detailed discussion on regulatory actions, including filings related to programs and associated expenditures, as well as rate requests related to recovery of capital investments and operating costs.
NJNG’s operations are managed with the goal of providing safe and reliable service, growing its customer base, diversifying its margin, promoting clean energy programs and mitigating the risks discussed above through several key initiatives, including:
earning a reasonable rate of return on the investments in its natural gas distribution and transmission businesses, as well as timely recovery of all prudently incurred costs to provide safe and reliable service throughout NJNG’s territory;
continuing to invest in the safety and integrity of its infrastructure;
managing its customer growth rate, which NJNG expects will be approximately 1.8 percent annually through fiscal 2021;
maintaining a collaborative relationship with the BPU on regulatory initiatives, including:
- planning and authorization of infrastructure investments;
- pursuing rate and regulatory strategies to stabilize and decouple margin, including CIP;
- utilizing BGSS incentive programs through BPU-approved mechanisms to reduce gas costs and generate margin; and
- administering and promoting NJNG’s BPU-approved SAVEGREEN Project;
managing the volatility of wholesale natural gas prices through a hedging program designed to keep customers’ BGSS rates as stable as possible; and
working with the NJDEP and BPU to manage its financial obligations related to remediation activities associated with its former MGP sites.
Base Rate Case
In September 2016, the BPU approved NJNG's base rate case, effective October 2016, which included an increase in base rates in the amount of $45 million. The base rate increase includes a return on common equity of 9.75 percent, a common equity ratio of 52.5 percent and a depreciation rate of 2.4 percent. The approval also included the rate mechanism and five-year extension of SAFE II, rate recovery of NJ RISE capital investment costs through June 30, 2016, recovery of NJNG’s SAFE I, Natural Gas Vehicle Refueling Stations and LNG capital investments and recovery of other costs previously deferred in regulatory assets.
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 and estimates for expected investments over the next two fiscal years:
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.
SAFE and NJ RISE
NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability and integrity of NJNG’s gas distribution system.
The BPU approved recovery of SAFE I capital investments through September 30, 2016, and approved the rate mechanism and extension of SAFE II for an additional five years to replace the remaining unprotected steel mains and services from NJNG’s natural gas distribution system at an estimated cost of approximately $200 million, excluding AFUDC. The accelerated cost recovery methodology for the $157.5 million associated with the extension of SAFE II was approved in NJNG’s new base rates. The remaining $42.5 million in capital expenditures will be requested for recovery in future base rate cases.
The BPU approved NJNG’s NJ RISE capital infrastructure program, which consists of six capital investment projects estimated to cost $102.5 million, excluding AFUDC, for 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 July 2017, the BPU approved NJNG’s annual petition requesting a $4.1 million increase in recoveries of NJ RISE and SAFE II capital investment costs, with a weighted cost of capital of 6.9 percent including a return on equity of 9.75 percent, related to the period ending June 30, 2017, effective October 2017.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On September 17, 2018, the BPU approved NJNG’s annual petition requesting a base rate increase of $6.8 million for the recovery of SAFE II and NJ RISE capital investment costs, with a weighted cost of capital of 6.9 percent including a return on equity of 9.75 percent, related to the 12-months ended June 30, 2018, effective October 1, 2018.
Natural Gas Vehicle Refueling Stations
NJNG has three natural gas vehicle refueling stations open to the public. Costs for these stations were approximately $10 million and are being recovered through NJNG’s base rates, effective October 2016.
Liquefaction/LNG
NJNG’s Liquefaction facility allows NJNG to convert natural gas into LNG to fill its existing LNG storage tanks. Costs for this facility along with other plant upgrades were approximately $36.5 million and are being recovered through NJNG’s base rates effective October 2016.
Southern Reliability Link
The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG’s service territory, estimated to cost between $180 million and $215 million. In January 2016, the BPU issued an order approving NJNG’s modified, proposed SRL pipeline installation, operation and route selection. In March 2016, the BPU issued an order designating the SRL route and exempting the SRL from municipal land use ordinances, regulations, permits and license requirements. In February 2017, the New Jersey Department of Environmental Protection issued a permit authorizing construction of the SRL within the jurisdiction of the Coastal Area Facility Review Act, as well as a Freshwater Wetlands permit. In September 2017, the NJ Pinelands Commission approved construction of the SRL as being compliant with the Commission’s Comprehensive Management Plan. All approvals issued by state agencies are under appeal and certain road-opening permits and easements are in the process of being secured. Construction is expected to begin in fiscal 2019, with an estimated in-service date in 2019.
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:
|
| | | | | | |
| | 2018 | 2017 | 2016 |
| Firm customers | | | |
| Residential | 474,495 |
| 460,013 |
| 448,273 |
|
| Commercial, industrial & other | 28,037 |
| 26,947 |
| 26,218 |
|
| Residential transport | 26,490 |
| 32,653 |
| 36,292 |
|
| Commercial transport | 9,636 |
| 10,137 |
| 10,316 |
|
| Total firm customers | 538,658 |
| 529,750 |
| 521,099 |
|
| Other | 59 |
| 60 |
| 64 |
|
| Total customers | 538,717 |
| 529,810 |
| 521,163 |
|
During fiscal 2018, NJNG added 9,596 new customers, which represents a new customer growth rate of approximately 1.8 percent. During that same time period, NJNG converted 613 existing customers to natural gas heat and other services. This customer growth, as well as commercial customers who switched from interruptible to firm natural gas service, will contribute approximately $5.5 million, on an annualized basis, to utility gross margin. NJNG also added 9,126 and 8,170 new customers and converted 662 and 644 existing customers to natural gas heat and other services during the fiscal years ended September 30, 2017 and 2016, respectively.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
In addition, NJNG currently expects to add approximately 28,000 to 30,000 new customers during the three-year period of fiscal 2019 to 2021. NJNG’s estimates are based on information from municipalities and developers, as well as external industry analysts and management’s experience. NJNG estimates that approximately 68 percent of the growth will come from new construction markets and 32 percent from customer conversions to natural gas from other fuel sources. This new customer and conversion growth would increase utility gross margin under NJNG’s base rates by approximately $5.5 million annually, as calculated under NJNG’s CIP tariff. See the Natural Gas Distribution Segment Operating Results section that follows for a definition and further discussion of utility gross margin.
Energy Efficiency Programs
SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives, which are 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 June 2016, the BPU approved NJNG’s extension of SAVEGREEN through December 31, 2018. On September 17, 2018, the BPU approved the continuation of existing SAVEGREEN programs and the addition of new programs with investments of $135 million through December 2021.
On October 20, 2017, the BPU approved NJNG’s filing to decrease its EE recovery rate, which resulted in an annual decrease of $3.9 million, effective November 1, 2017. On May 25, 2018, NJNG filed a petition with the BPU to decrease its EE recovery rate. On October 16, 2018, NJNG updated this information through September 30, 2018, which will result in an annual decrease of $8.8 million, anticipated to be effective January 1, 2019.
Since inception, $162 million in grants, rebates and loans have been provided to customers, with a total annual recovery of approximately $16.1 million. The recovery includes a weighted average cost of capital that ranges from 6.69 percent to 7.76 percent, with a return on equity of 9.75 percent to 10.3 percent.
Conservation Incentive Program
The CIP facilitates normalizing NJNG’s utility gross margin for variances not only due to weather but also for other factors affecting customer usage, such as conservation and energy efficiency. Recovery of utility gross margin for the non-weather variance through the CIP is limited to the amount of certain gas supply cost savings achieved and is subject to a variable margin review test. Additionally, recovery of the CIP utility gross margin is subject to an annual earnings test. An annual review of the CIP must be filed by June 1, coincident with NJNG’s annual BGSS filing, during which NJNG can request rate changes to the CIP. In May 2014, the BPU approved the continuation of the CIP program with no expiration date. Refer to Note 3. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements, for a discussion of CIP rate actions.
NJNG’s total utility firm gross margin includes the following adjustments related to the CIP mechanism:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
Weather (1) | $ | 205 |
| $ | 19,261 |
| $ | 27,547 |
|
| Usage | (1,629 | ) | (2,309 | ) | 10,420 |
|
| Total | $ | (1,424 | ) | $ | 16,952 |
| $ | 37,967 |
|
| |
| (1) | Compared with the CIP 20-year average, weather was 0.5 percent, 10 percent and 17.5 percent warmer-than-normal during fiscal 2018, 2017 and 2016, respectively. |
Commodity prices
Our Natural Gas Distribution segment is affected by the price of natural gas, which can have a significant impact on our cash flows, short-term financing costs, the price of natural gas charged to our customers through the BGSS clause, our ability to collect accounts receivable, which impacts our bad debt expense, and our ability to maintain a competitive advantage over other fuel sources.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Natural gas commodity prices may experience high volatility as shown in the graph below, which illustrates the daily natural gas prices(1) in the Northeast market region, also known as Tetco M-3.
(1) Midpoint daily gas price sourced from Platts, a division of McGraw Hill Financial.
The maximum price per MMBtu was $94.93, $8.71 and $4.74 and the minimum price was $0.53, $0.36 and $0.67 for the fiscal years ended September 30, 2018, 2017 and 2016, respectively. A more detailed discussion of the impacts of the price of natural gas on operating revenues, gas purchases and cash flows can be found in the Results of Operations and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
BGSS
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 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.
On March 26, 2018, the BPU approved maintaining NJNG's BGSS rate for residential and small commercial customers and an increase to its balancing charge rate, which resulted in a $3.7 million increase to the annual revenues credited to BGSS, effective October 2017. 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. During fiscal 2017, NJNG issued bill credits of $42 million as a result of a decline in the wholesale price of natural gas. There were no bill credits issued during fiscal 2018, related to BGSS prices.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On September 17, 2018, the BPU provisionally approved NJNG’s annual petition to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well changes to the CIP rates, which will result in a $30.9 million annual recovery decrease, effective October 1, 2018. Refer to Note 3. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements for a further discussion of NJNG’s periodic BGSS rate adjustments and bill credits.
BGSS Incentive Programs
NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of utility gross margin-sharing programs that include off-system sales, capacity release and storage incentive programs. These programs are designed to encourage better utilization and hedging of NJNG’s natural gas supply, transportation and storage assets. Depending on the program, NJNG shares 80 or 85 percent of utility gross margin generated by these programs with firm customers. Should performance of the existing incentives or market conditions warrant, NJNG is permitted to propose a process to re-evaluate and discuss alternative incentive programs annually. Utility gross margin from incentive programs was $12.5 million, $13.7 million and $15 million during the fiscal years ended September 30, 2018, 2017 and 2016, respectively. A more detailed discussion of the impacts to utility gross margin can be found in the Natural Gas Distribution Segment Operating Results section that follows.
Hedging
In order to provide relative price stability to its natural gas supply portfolio, NJNG employs a hedging strategy with the goal of having at least 75 percent of its projected winter periodic BGSS gas sales volumes hedged by each November 1 and at least 25 percent of the projected BGSS gas sales hedged for the following April-through-March period. This is accomplished with the use of various financial instruments including futures, swaps and options used in conjunction with commodity and/or weather-related hedging activity.
Due to the capital-intensive nature of NJNG’s operations and the seasonal nature of its working capital requirements, significant changes in interest rates can impact NJNG’s results. In June 2015, NJNG entered into a transaction to fix a benchmark treasury rate of 3.26 percent associated with a $125 million debt issuance that was finalized in May 2018. The debt issuance coincided with the maturity of NJNG's $125 million, 5.6 percent notes that came due on May 15, 2018. This treasury lock was settled on March 13, 2018, which coincided with the pricing of the new debt being issued. Settlement of the interest rate contract resulted in a $2.6 million loss, which is recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized to earnings over the 30-year term of the $125 million note issued on May 11, 2018.
A more detailed discussion of NJNG’s debt can be found in the Liquidity and Capital Resources and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Societal Benefits Charge
USF
NJNG’s qualifying customers are eligible for the USF program, which is administered by the New Jersey Department of Community Affairs, to help make energy bills more affordable. On September 17, 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which will result in a $1 million annual increase, effective October 1, 2018. Refer to Note 3. Regulation - Societal Benefits Clause in the accompanying Consolidated Financial Statements for a further discussion of NJNG’s USF rates.
Environmental Remediation
NJNG is responsible for the environmental remediation of five 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 $130.8 million as of September 30, 2018, a decrease of $18.2 million, compared with the prior fiscal period.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Other
In May 2016, NJNG included a proposal in its base rate case to recover certain capital costs and incremental operation and maintenance costs related to a March 2016 BPU Order regarding new cybersecurity requirements. This proposal was updated in July 2016, and the associated costs were approved for recovery through NJNG’s new base rates, effective October 2016.
Interest Rate Risk
Due to the capital-intensive nature of NJNG’s operations and the seasonal nature of its working capital requirements, significant changes in interest rates can impact NJNG’s results. A more detailed discussion can be found in the Liquidity and Capital Resources and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Other regulatory filings and a more detailed discussion of the filings in this section can be found in Note 3. Regulation in the accompanying Consolidated Financial Statements.
Commodity Service to Customers
The EDECA, which was enacted in 1999, provides the framework for New Jersey’s retail energy markets, which are open to competition from other electric and natural gas suppliers. 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 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 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.
Operating Results
NJNG’s operating results for the fiscal years ended September 30, are as follows:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Operating expenses | | | |
Gas purchases (1) (2) | 333,208 |
| 269,480 |
| 215,849 |
|
| Operation and maintenance | 161,723 |
| 142,509 |
| 130,575 |
|
Regulatory rider expense (3) | 38,969 |
| 40,243 |
| 39,300 |
|
| Depreciation and amortization | 53,208 |
| 49,347 |
| 47,828 |
|
Energy and other taxes (4) | 44,184 |
| 42,417 |
| 34,561 |
|
| Total operating expenses | 631,292 |
| 543,996 |
| 468,113 |
|
| Operating income | 100,573 |
| 151,641 |
| 126,233 |
|
| Other income, net | 6,864 |
| 4,592 |
| 4,752 |
|
| Interest expense, net of capitalized interest | 25,299 |
| 25,818 |
| 19,930 |
|
| Income tax (benefit) provision | (1,910 | ) | 43,485 |
| 34,951 |
|
| Net income | $ | 84,048 |
| $ | 86,930 |
| $ | 76,104 |
|
| |
| (1) | Includes the purchased cost of the natural gas, fees paid to pipelines and storage facilities, adjustments as a result of BGSS incentive programs and hedging transactions. These expenses are passed through to customers and are offset by corresponding revenues. |
| |
| (2) | Includes related party transactions of approximately $57.2 million, $10.8 million and $10.8 million during fiscal 2018, 2017 and 2016, respectively, a portion of which are eliminated in consolidation. |
| |
| (3) | Consists of expenses associated with state-mandated programs, the RAC and energy efficiency programs, and are calculated on a per-therm basis. These expenses are passed through to customers and offset by corresponding revenues. |
| |
| (4) | Consists primarily of sales tax, which is passed through to customers and offset by corresponding revenues. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Revenues and Gas Purchases
Operating revenues increased 5.2 percent during fiscal 2018 and increased 17 percent during fiscal 2017. Gas purchases increased 23.6 percent during fiscal 2018 and increased 24.8 percent during fiscal 2017. The factors contributing to the increases (decreases) in operating revenues and gas purchases during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | | | | |
| | 2018 v. 2017 | | 2017 v. 2016 |
| (Thousands) | Operating revenue | Gas purchases | | Operating revenue | Gas purchases |
| Firm sales | $ | 49,414 |
| $ | 19,779 |
| | $ | 44,397 |
| $ | 21,634 |
|
Bill credits (1) | 41,971 |
| 39,260 |
| | 19,588 |
| 18,265 |
|
Average BGSS rates (2) | 1,147 |
| 1,413 |
| | (17,874 | ) | (16,544 | ) |
| Off-system sales | 677 |
| 221 |
| | 29,156 |
| 29,117 |
|
| Tax Act impact | (35,910 | ) | — |
| | — |
| — |
|
| CIP adjustments | (18,375 | ) | — |
| | (21,015 | ) | — |
|
Rate impact (3) | — |
| — |
| | 37,436 |
| — |
|
Other (4) | (2,696 | ) | 3,055 |
| | 9,603 |
| 1,159 |
|
| Total increase | $ | 36,228 |
| $ | 63,728 |
| | $ | 101,291 |
| $ | 53,631 |
|
| |
| (1) | Operating revenues include changes in sales tax of $2.7 million and $1.3 million during fiscal 2018 and 2017, respectively. |
| |
| (2) | Operating revenues include changes in sales tax of $266,000 and $1.4 million during fiscal 2018 and 2017, respectively. |
| |
| (3) | Includes rate adjustments for the base rate case, CIP and demand charges. |
| |
| (4) | Other includes changes for NJ RISE/SAFE II and rider rates, including those related to EE, NJCEP and other programs. |
Fiscal 2018 compared with fiscal 2017
The changes in operating revenues and gas purchases during fiscal 2018 were due primarily to:
increased firm sales due primarily to customer growth and higher usage related to weather being 9.9 percent colder than fiscal 2017;
bill credits issued to residential and small commercial customers during fiscal 2017 that did not occur in fiscal 2018; partially offset by
the Tax Act impact, which is comprised of customer credits related to the initial revaluation of excess deferred income taxes and the overcollection of taxes from customers during the second quarter of fiscal 2018, including related interest and sales tax, as well as the effects from the reduction in base rates related to the Tax Act implemented during the third quarter;
a decrease in CIP due primarily to normal weather during fiscal 2018, compared with warmer-than-normal weather during fiscal 2017; and
higher off-system sales due primarily to an increase of 19.7 percent in the average price of natural gas sold, partially offset by a reduction in volumes of 15.9 percent.
Fiscal 2017 compared with fiscal 2016
The changes in operating revenues and gas purchases during fiscal 2017 were due primarily to:
increased firm sales due primarily to customer growth and higher usage, related to weather being 6.8 percent colder;
increased base rates resulting from the settlement of the base rate case;
higher off-system sales due primarily to a 49.8 percent increase in the average price of natural gas sold, partially offset by a 12.2 percent reduction in volumes;
a decrease in bill credits issued to residential and small commercial customers during the months of November 2016 through February 2017 compared with the same period in the prior year; partially offset by
a decrease in CIP due primarily to weather, partially offset by changes in the CIP as a result of the settlement of the base rate case.
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 utility gross margin, a non-GAAP financial measure, when evaluating the operating results of NJNG. NJNG’s utility gross margin is defined as natural gas revenues less natural gas purchases, sales tax and regulatory rider expenses, and may not be comparable to the definition of gross margin used by others in the natural gas distribution business and other industries. Management believes that utility gross margin provides a meaningful basis for evaluating utility operations since natural gas costs, sales tax and regulatory rider expenses are included in operating revenue and passed through to customers and, therefore, have no effect on utility gross margin. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.
Utility Gross Margin
A reconciliation of operating revenues, the closest GAAP financial measure to NJNG’s utility gross margin, is as follows for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Less: | | | |
| Gas purchases | 333,208 |
| 269,480 |
| 215,849 |
|
| Energy taxes | 39,426 |
| 37,917 |
| 29,832 |
|
| Regulatory rider expense | 38,969 |
| 40,243 |
| 39,300 |
|
| Utility gross margin | $ | 320,262 |
| $ | 347,997 |
| $ | 309,365 |
|
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:
|
| | | | | | | | | | | | | | | | | |
| | 2018 | | 2017 | | 2016 |
| ($ in thousands) | Margin | Bcf | | Margin | Bcf | | Margin | Bcf |
| Utility gross margin/throughput | | | | | | | | |
| Residential | $ | 203,195 |
| 45.5 |
| | $ | 218,093 |
| 40.7 |
| | $ | 187,762 |
| 36.9 |
|
| Commercial, industrial and other | 46,636 |
| 8.9 |
| | 51,510 |
| 8.7 |
| | 46,878 |
| 7.3 |
|
| Firm transportation | 51,880 |
| 15.5 |
| | 58,172 |
| 14.4 |
| | 54,841 |
| 14.1 |
|
| Total utility firm gross margin/throughput | 301,711 |
| 69.9 |
| | 327,775 |
| 63.8 |
| | 289,481 |
| 58.3 |
|
| BGSS incentive programs | 12,482 |
| 150.2 |
| | 13,724 |
| 178.4 |
| | 14,978 |
| 216.7 |
|
| Interruptible/off-tariff agreements | 6,069 |
| 46.2 |
| | 6,498 |
| 55 |
| | 4,906 |
| 61.5 |
|
| Total utility gross margin/throughput | $ | 320,262 |
| 266.3 |
| | $ | 347,997 |
| 297.2 |
| | $ | 309,365 |
| 336.5 |
|
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Utility Firm Gross Margin
A description of the factors contributing to the (decreases) increases in utility firm gross margin during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2018 v. 2017 | 2017 v. 2016 |
| Tax Act impact | | $ | (33,657 | ) | | | $ | — |
| |
| SAVEGREEN | | (977 | ) | | | (345 | ) | |
| NJ RISE/SAFE II | | 4,334 |
| | | — |
| |
| Customer growth | | 4,236 |
| | | 3,619 |
| |
| Rate impact | | — |
| | | 35,019 |
| |
| Total (decrease) increase | | $ | (26,064 | ) | | | $ | 38,293 |
| |
BGSS Incentive Programs
A description of the factors contributing to the (decreases) increases in utility gross margin generated by NJNG’s BGSS incentive programs during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2018 v. 2017 | 2017 v. 2016 |
| Storage | | $ | (954 | ) | | | $ | 378 |
| |
| Capacity release | | (745 | ) | | | (1,672 | ) | |
| Off-system sales | | 457 |
| | | 39 |
| |
| Total decrease | | $ | (1,242 | ) | | | $ | (1,255 | ) | |
Fiscal 2018 compared with fiscal 2017
The decrease in utility gross margin was due primarily to the Tax Act impact, as previously discussed, a decrease in value in the storage incentive program and a decrease in capacity release due to less volume and lower values, partially offset by increased margins for off-system sales.
Fiscal 2017 compared with fiscal 2016
The increase in utility gross margin was due primarily to the base rate increase and customer growth, along with an increase in interruptible/off-tariff agreements, partially offset by decreased margins related to capacity release due to lower volumes and lower value of capacity.
Operation and Maintenance Expense
A summary and description of the factors contributing to the increases (decreases) in O&M expense during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2018 v. 2017 | 2017 v. 2016 |
| Shared corporate costs | | $ | 5,991 |
| | | $ | 3,061 |
| |
| Compensation and benefits | | 5,767 |
| | | 5,412 |
| |
| Consulting | | 5,184 |
| | | 512 |
| |
| Other | | 2,272 |
| | | 2,949 |
| |
| Total increase | | $ | 19,214 |
| | | $ | 11,934 |
| |
Fiscal 2018 compared with fiscal 2017
The increase in O&M expense during fiscal 2018 was due primarily to:
increased shared corporate costs due primarily to increased headcount and incentives, along with additional expenses related to a voluntary early retirement program;
increased compensation and benefits as a result of voluntary early retirement program costs; and
increased consulting expenses due primarily to technology improvements.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Fiscal 2017 compared with fiscal 2016
The increase in O&M expense during fiscal 2017 was due primarily to:
increased compensation costs due primarily to increases in headcount, incentives, healthcare premiums, lower capitalized labor and increased pension/OPEB benefit costs related to changes in actuarial assumptions, partially offset by implementation of the spot rate method to measure interest and service cost components;
additional amortization of regulatory assets in other that are being recovered as a result of the settlement of the base rate case; and
increased shared corporate costs resulting primarily from increased software maintenance, incentives, postemployment costs and healthcare premiums.
Depreciation Expense
Depreciation expense increased $3.9 million in fiscal 2018, compared with fiscal 2017, as a result of additional utility plant being placed into service. Depreciation expense increased $1.5 million in fiscal 2017, compared with fiscal 2016, as a result of additional utility plant being placed into service, as well as an increase in the overall depreciation rate from 2.34 percent to 2.4 percent resulting from the settlement of the base rate case.
Operating Income
Operating income decreased $51.1 million, or 33.7 percent, in fiscal 2018, compared with fiscal 2017, due primarily to the decrease in total utility gross margin of $27.7 million, as well as the increase in O&M and depreciation, as previously discussed. Operating income increased $25.4 million, or 20.1 percent, in fiscal 2017, compared with fiscal 2016, due primarily to theincrease in total utility gross margin of $38.6 million, partially offset by the increase in O&M, as previously discussed.
Income Tax Provision
Income tax provision decreased $45.4 million during fiscal 2018, compared with fiscal 2017, due primarily to the impacts of the change in the federal corporate tax rate resulting from the Tax Act. Income tax provision increased $8.5 million during fiscal 2017, compared with fiscal 2016, due primarily to an increase in pre-tax income, partially offset by increased costs associated with the removal of distribution main that was placed in service before 1981, for which the tax benefit is passed on to customers in base rates.
Net Income
Net income decreased $2.9 million to $84 million in fiscal 2018, compared with fiscal 2017, due primarily to decreased utility gross margin and increased O&M and depreciation, partially offset by the decrease in the income tax provision as previously discussed.
Net income increased $10.8 million to $86.9 million in fiscal 2017, compared with fiscal 2016, due primarily to an increase in operating income as discussed above, partially offset by an increase in the income tax provision as discussed above and interest expense associated with debt issued in June 2016.
Clean Energy Ventures Segment
Overview
Our Clean Energy Ventures segment actively pursues opportunities in the renewable energy markets. Clean Energy Ventures has entered into various agreements to install solar net-metered systems for residential and commercial customers, as well as large commercial grid-connected projects. In addition, Clean Energy Ventures has entered into various long-term agreements, including PPAs, to supply energy from wind and solar projects.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Solar
Solar projects placed in service and related expenditures for the fiscal years ended September 30, are as follows:
|
| | | | | | | | | | | | | | | | | | | | | |
| ($ in Thousands) | 2018 | 2017 | 2016 |
| Placed in service | Projects | MW | Costs | Projects | MW | Costs | Projects | MW | Costs |
Grid-connected (1) | 3 |
| 33.7 |
| $ | 70,216 |
| 2 |
| 20.0 |
| $ | 62,700 |
| 5 |
| 21.8 |
| $ | 51,240 |
|
| Net-metered: | | | | | | | | | |
Commercial (1) | — |
| — |
| 74 |
| 3 |
| 7.1 |
| 19,714 |
| — |
| — |
| 3 |
|
| Residential | 910 |
| 8.5 |
| 27,342 |
| 1,300 |
| 12.4 |
| 37,901 |
| 1,123 |
| 10.4 |
| 34,318 |
|
| Total placed in service | 913 |
| 42.2 |
| $ | 97,632 |
| 1,305 |
| 39.5 |
| $ | 120,315 |
| 1,128 |
| 32.2 |
| $ | 85,561 |
|
| |
| (1) | Includes projects subject to sale-leaseback arrangements. |
Since its inception, Clean Energy Ventures has constructed a total of 231.3 MW of solar capacity and has an additional 19.6 MW under construction. Projects that are placed in service through December 31, 2019, qualify for a 30 percent federal ITC. The credit will decline to 26 percent for property under construction during 2020 and to 22 percent for property under construction during 2021. The ITC will be reduced to 10 percent for any property that is under construction before 2022, but not placed in service before 2024.
Clean Energy Ventures may enter into transactions to sell certain of its commercial solar assets concurrent with agreements to lease the assets back over a period of six to 15 years. The Company will continue to operate the solar assets and are responsible for related expenses and entitled to retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects have been transferred to the buyer; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. As of September 30, 2018, Clean Energy Ventures has entered into five sale-leaseback transactions, three during fiscal 2018 with costs of $70.2 million and two during fiscal 2017 with costs of $31.1 million. Clean Energy Ventures did not enter into sale-leasebacks during fiscal 2016.
Excluding the project costs related to the commercial solar projects that were included in the sale-leaseback transactions, the Company had $27.4 million, $89.2 million and $85.6 million of solar-related capital expenditures were ITC-eligible during fiscal 2018, 2017 and 2016, respectively, which were recognized in income tax (benefit) provision on the Consolidated Statements of Operations when the assets were placed in service.
As part of its solar investment portfolio, Clean Energy Ventures operates a residential solar program, The Sunlight Advantage®, which provides qualifying homeowners the opportunity to have a solar system installed at their home with no installation or maintenance expenses. Clean Energy Ventures owns, operates and maintains the system over the life of the contract in exchange for monthly lease payments.
Once a solar installation has received the proper certifications and commences operations, each MWh of electricity produced creates an SREC that represents the renewable energy attribute of the solar-electricity generated that can be sold to third parties, predominantly load-serving entities that are required to comply with the solar requirements under New Jersey’s renewable portfolio standard.
SREC activity for the fiscal years ended September 30, is as follows:
| | | | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Inventory balance as of October 1, | 24,135 |
| 33,203 |
| 29,970 |
| 48,357 |
| 24,135 |
| 33,203 |
|
| SRECs generated | 197,521 |
| 160,009 |
| 126,133 |
| 245,147 |
| 197,521 |
| 160,009 |
|
| SRECs delivered | (173,299 | ) | (169,077 | ) | (122,900 | ) | (188,312 | ) | (173,299 | ) | (169,077 | ) |
| Inventory balance as of September 30, | 48,357 |
| 24,135 |
| 33,203 |
| 105,192 |
| 48,357 |
| 24,135 |
|
SRECs generated increased 23.424.1 percent and 26.923.4 percent for the fiscal years ended September 30, 20172018 and 2016,2017, respectively, compared with the previous fiscal years. The average SREC sales price was $217 in fiscal 2018, $233 in fiscal 2017 and $214 in fiscal 2016 and $183 in fiscal 2015.2016.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Clean Energy Ventures hedges a portion of its expected SREC production through the use of forward sales contracts. The following table reflects the hedged percentage of SREC inventory and projected SREC production related to its in-service commercial and residential assets:assets as of September 30, 2018:
| | Energy Year (1)
| Percent of SRECs Hedged | Percent of SRECs Hedged |
| 2018 | 90% | |
| 2019 | 70% | 91% |
| 2020 | 11% | 86% |
| 2021 | | 58% |
| |
| (1) | Energy years are compliance periods for New Jersey'sJersey’s renewable portfolio standard that run from June 1 to May 31. |
There are no direct costs associated with the production of SRECs/RECsSRECs by our solar and wind assets. All related costs are included as a component of O&M expenses on the Consolidated Statements of Operations, including such expenses as facility maintenance and various fees.
Operation and Maintenance Expense
O&M expense increased $4.6 million in fiscal 2017 and $3.6 million in fiscal 2016, due primarily to additional maintenance, leasing and administrative costs associated with wind and solar projects placed in service, as well as increased shared corporate costs.
Depreciation Expense
Depreciation expense increased $7.9 million in fiscal 2017 and $6.7 million in fiscal 2016, as a result of increases in wind and solar projects placed in service.
Income Tax (Benefit)
Income tax benefit during fiscal 2017, 2016 and 2015, includes $24.6 million, $25.7 million and $27.8 million respectively, of ITCs associated with solar projects, that were completed and placed into service during the corresponding fiscal year. Income tax benefit during fiscal 2017, 2016 and 2015 includes $9.9 million and $6.7 million, and $2 million respectively, of PTCs associated with wind projects. Clean Energy Ventures recognized $29.2 million, $27 million, and $24.1 million related to tax credits, net of deferred taxes, during fiscal 2017, 2016 and 2015, respectively.
Net Income
Net income in fiscal 2017 decreased $3.5 million, compared with fiscal 2016, due primarily to increased costs related to depreciation and O&M as previously discussed, as well as an increase in interest expense related to higher debt associated with capital expenditures, partially offset by an increase in operating revenues, as well as an increase in tax benefits recognized due primarily to an increase PTCs, as previously discussed.
Net income during fiscal 2016 increased $8.3 million, compared with fiscal 2015, due primarily to the factors described above, partially offset by an increase in interest expense due to higher debt associated with capital expenditures.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Energy Services Segment
OverviewAs of September 30, 2018, Energy Services leases office space in Wall Township, New Jersey, Houston, Texas, Charlotte, North Carolina and Allentown, Pennsylvania.
Energy Services markets and sells natural gas to wholesale and retail customers and managesMidstream Segment
As of September 30, 2018, Steckman Ridge owned and/or leased storage rights on approximately 6,300 acres of land in Bedford County, Pennsylvania, with a FERC-regulated natural gas storage facility with up to 12 Bcf of working gas capacity. Equipment on the property includes a compressor station, gathering pipelines and transportationpipeline interconnections. As of September 30, 2018, PennEast owned 74 acres of land in Carbon County, Pennsylvania and 58.7 acres of land in Mercer County, New Jersey.
New Jersey Resources Corporation
Part I
ITEM 2. PROPERTIES (Continued)
All Other Business Operations
As of September 30, 2018, CR&R’s real estate portfolio consisted of 35 acres of undeveloped land in Atlantic County, New Jersey with a net book value of $1.4 million.
NJRHS leases service centers in Dover, New Jersey and Wall Township, New Jersey.
Capital Expenditure Program
See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of anticipated fiscal 2019 and 2020 capital expenditures, as applicable to our reporting segments and business operations.
ITEM 3. LEGAL PROCEEDINGS
Manufactured Gas Plant Remediation
NJNG is responsible for the remedial cleanup of five 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 Administrative Consent Orders or a Memoranda of Agreement with the NJDEP.
NJNG may recover its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. NJNG recovered approximately $9.4 million annually through its SBC RAC. On July 25, 2018, the BPU approved NJNG’s annual SBC application requesting a reduction in the RAC, which decreased the annual recovery to $7 million, effective September 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, and an increase in the RAC, which will result in an annual increase of approximately $1.4 million, effective April 1, 2019. As of September 30, 2018, $33 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets throughout major market areas across North America. Energy Services maintainson the Consolidated Balance Sheets.
NJNG periodically, and at least annually, performs an environmental review of MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester and Toms River, including a strategic portfolioreview of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future expenditures to remediate and monitor the MGP sites for which it is responsible, including potential liabilities for natural gas storage and transportation contractsresource damages that it utilizes in conjunction with its market expertisemight be brought by the NJDEP for alleged injury to provide service and valuegroundwater or other natural resources concerning these sites, will range from approximately $117.7 million to its customers. Availability$204.1 million. NJNG’s estimate of these storageliabilities is based upon known facts, existing technology and transportation contracts allows Energy Servicesenacted 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 generate market opportunitiesestablish 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, 2018, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $130.8 million on the Consolidated Balance Sheets, based on the most likely amount. This was reduced from $149 million in fiscal 2017, due to the completion of remediation work at certain sites and a reduction to the remediation scope at another site. The actual costs to be incurred by capturing price differentials over specific time horizonsNJNG are dependent upon several factors, including final determination of remedial action, changing technologies and between geographic market locations.governmental regulations, the ultimate ability of other responsible parties to pay and insurance recoveries, if any.
Energy Services also provides managementNJNG will continue to seek recovery of storageMGP-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
We are involved, and transportation assets for natural gas producersfrom time to time in the future may be involved, in a number of pending and regulated utilities. These management transactions typically involvethreatened judicial, regulatory and arbitration proceedings relating to matters that arise in connection with the releaseconduct of producer/utility owned storage and/business, certain of which litigation matters are described in Note 13. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements. In view of the inherent difficulty of predicting the outcome of litigation matters, particularly when such matters are in their early stages or transportation capacity in combinationwhere the claimants seek indeterminate damages, we cannot state with either an obligationconfidence 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 purchase and/or deliver physical natural gas. In addition to the contractual purchase and/or sale of physical natural gas, Energy Services generates or pays fee-based margin in exchange for its active management and may provide the producer and/or utility with additional margin based on actual results.each pending matter will be, if any.
New Jersey Resources Corporation
Part I
ITEM 3. LEGAL PROCEEDINGS (Continued)
In conjunctionaccordance with applicable accounting guidance, we establish reserves for litigation for those matters that present loss contingencies as to which it is both probable that a loss will be incurred and the active managementamount of such loss can be reasonably estimated. Based upon currently available information, we believe that the results of litigation that is currently pending, taken together, will not have a materially adverse effect on our financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts reserved.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable
ITEM 4A. EXECUTIVE OFFICERS OF THE COMPANY
The Company’s Executive Officers and their age, position and business experience during the past five years are set forth below.
|
| | | |
| Name | Age | Officer since | Office held during last five years |
| Laurence M. Downes | 61 | 1986 | Chairman of the Board (September 1996 - present)
Chief Executive Officer (July 1995 - present)
President (July 1995 - September 2018) |
| Patrick J. Migliaccio | 44 | 2013 | Senior Vice President and Chief Financial Officer (January 2016 - present)
Vice President, Finance and Accounting (November 2014 - December 2015)
Treasurer (August 2013 - May 2015) |
| Stephen D. Westhoven | 50 | 2004 | President and Chief Operating Officer (October 2018 - present)
Executive Vice President and Chief Operating Officer (November 2017 - September 2018)
Senior Vice President and Chief Operating Officer, NJRES and NJRCEV (October 2016 -
October 2017)
Senior Vice President, NJRES (May 2010 - September 2016) |
| Glenn C. Lockwood | 57 | 1990 | Executive Vice President (January 2011 - present)
Chief Financial Officer (September 1995 - December 2015) |
| Amanda E. Mullan | 52 | 2015 | Senior Vice President and Chief Human Resources Officer (January 2017 - present)
Vice President and Chief Human Resources Officer (April 2015 - December 2016)
Senior Vice President of HR, N. America, Willis Group Holdings, a risk management and
insurance intermediary (April 2012 - April 2015) |
| Jacqueline K. Shea | 54 | 2016 | Vice President and Chief Information Officer (June 2016 - present)
Chief Information Officer, Godiva Chocolatier, a manufacturer of premium fine chocolates and
related products (March 2011 - May 2016) |
| Nancy A. Washington | 54 | 2017 | Senior Vice President and General Counsel (March 2017 - present)
Senior Vice President and Chief Litigation Counsel, CIT Group Inc., a Livingston, NJ-based
financial services firm (September 2010 - March 2017)
|
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 September 30, 2018, NJR had 52,673 holders of record of its common stock.
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. 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 earlier terminated 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, 2018:
|
| | | | | | | | |
| 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 |
| 7/01/18 - 7/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 8/01/18 - 8/31/18 | — | $ | — |
| — |
| | 2,431,053 |
| 9/01/18 - 9/30/18 | — | $ | — |
| — |
| | 2,431,053 |
| Total | — | $ | — |
| — |
| | 2,431,053 |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA
CONSOLIDATED FINANCIAL STATISTICS
|
| | | | | | | | | | | | | | | |
| (Thousands, except per share data) | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
| SELECTED FINANCIAL DATA | | | | | |
| Operating revenues | $ | 2,915,109 |
| $ | 2,268,617 |
| $ | 1,880,905 |
| $ | 2,733,987 |
| $ | 3,738,145 |
|
| Gas purchases | $ | 2,275,342 |
| $ | 1,703,767 |
| $ | 1,352,686 |
| $ | 2,085,645 |
| $ | 3,139,525 |
|
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Total assets | $ | 4,143,664 |
| $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 3,284,357 |
| $ | 3,125,388 |
|
| Common stock equity | $ | 1,418,978 |
| $ | 1,236,643 |
| $ | 1,166,591 |
| $ | 1,106,956 |
| $ | 966,166 |
|
Long-term debt (1) (2) | $ | 1,180,619 |
| $ | 997,080 |
| $ | 1,055,038 |
| $ | 843,595 |
| $ | 598,209 |
|
| | | | | | |
| COMMON STOCK DATA | | | | | |
| Earnings per share-basic | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Earnings per share-diluted | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Dividends declared per share | $1.11 | $1.038 | $0.975 | $0.915 | $0.855 |
| | | | | | |
| NON-GAAP RECONCILIATION | | | | | |
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 141,970 |
|
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,770 |
| (11,241 | ) | 46,883 |
| (38,681 | ) | 28,534 |
|
| Tax effect | (4,512 | ) | 4,062 |
| (17,018 | ) | 14,391 |
| (10,492 | ) |
| Effects of economic hedging related to natural gas inventory | (22,570 | ) | 38,470 |
| (36,816 | ) | (8,225 | ) | 26,639 |
|
| Tax effect | 7,362 |
| (13,964 | ) | 13,364 |
| 3,058 |
| (9,794 | ) |
Net financial earnings (3) | $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 176,857 |
|
| | | | | | |
| Basic earnings per share | $2.66 | $1.53 | $1.53 | $2.12 | $1.69 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.31 |
| (0.13 | ) | 0.55 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.13 | ) |
| Effects of economic hedging related to natural gas inventory | (0.26 | ) | 0.45 |
| (0.43 | ) | (0.10 | ) | 0.32 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.16 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-basic (3) | $2.74 | $1.73 | $1.61 | $1.78 | $2.10 |
| | | | | | |
| Diluted earnings per share | $2.64 | $1.52 | $1.52 | $2.10 | $1.67 |
| Add: | | | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.30 |
| (0.13 | ) | 0.54 |
| (0.45 | ) | 0.34 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) | 0.17 |
| (0.12 | ) |
| Effects of economic hedging related to natural gas inventory | (0.25 | ) | 0.44 |
| (0.42 | ) | (0.10 | ) | 0.31 |
|
| Tax effect | 0.08 |
| (0.17 | ) | 0.15 |
| 0.04 |
| (0.12 | ) |
Net financial earnings per share-diluted (3) | $2.72 | $1.71 | $1.59 | $1.76 | $2.08 |
| |
| (1) | Includes long-term capital leases of $26.4 million, $28.9 million, $30.7 million, $35.7 million and $40.4 million, respectively. |
| |
| (2) | Includes long-term solar asset financing obligation of $89.8 million and $28.2 million in fiscal 2018 and 2017, respectively. |
| |
| (3) | NFE is a non-GAAP financial measure that eliminates the timing differences surrounding the recognition of certain derivative gains or losses, to effectively match the earnings effects of economic hedges associated with the physical sale or purchase of gas and, therefore, eliminate the impact of volatility to GAAP earnings associated with the related derivative instruments. For further discussion of this financial measure, see the Energy Services segment in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. |
New Jersey Resources Corporation
Part II
ITEM 6. SELECTED FINANCIAL DATA (Continued)
NJNG OPERATING STATISTICS
|
| | | | | | | | | | | | | | | |
| Fiscal Years Ended September 30, | 2018 | 2017 | 2016 | 2015 | 2014 |
Operating revenues ($ in thousands) | | | | | |
| Residential | $ | 441,486 |
| $ | 395,315 |
| $ | 345,597 |
| $ | 466,464 |
| $ | 469,831 |
|
| Commercial, industrial and other | 95,351 |
| 98,777 |
| 80,994 |
| 106,505 |
| 110,740 |
|
| Firm transportation | 65,256 |
| 73,206 |
| 69,696 |
| 77,974 |
| 86,131 |
|
| Total residential and commercial | 602,093 |
| 567,298 |
| 496,287 |
| 650,943 |
| 666,702 |
|
| Interruptible | 7,522 |
| 7,970 |
| 8,867 |
| 10,049 |
| 9,384 |
|
| Total system | 609,615 |
| 575,268 |
| 505,154 |
| 660,992 |
| 676,086 |
|
| BGSS incentive programs | 122,250 |
| 120,369 |
| 89,192 |
| 120,978 |
| 143,329 |
|
| Total operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 819,415 |
|
| Throughput (Bcf) | | | | | |
| Residential | 45.5 |
| 40.7 |
| 36.9 |
| 45.9 |
| 43.1 |
|
| Commercial, industrial and other | 8.9 |
| 8.7 |
| 7.3 |
| 9.6 |
| 8.2 |
|
| Firm transportation | 15.5 |
| 14.4 |
| 14.1 |
| 16.0 |
| 17.7 |
|
| Total residential and commercial | 69.9 |
| 63.8 |
| 58.3 |
| 71.5 |
| 69.0 |
|
| Interruptible | 46.2 |
| 55 |
| 61.5 |
| 47.1 |
| 10.5 |
|
| Total system | 116.1 |
| 118.8 |
| 119.8 |
| 118.6 |
| 79.5 |
|
| BGSS incentive programs | 150.2 |
| 178.4 |
| 216.7 |
| 222.4 |
| 180.8 |
|
| Total throughput | 266.3 |
| 297.2 |
| 336.5 |
| 341.0 |
| 260.3 |
|
| Customers at year-end | | | | | |
| Residential | 474,495 |
| 460,013 |
| 448,273 |
| 437,979 |
| 422,742 |
|
| Commercial, industrial and other | 28,037 |
| 26,947 |
| 26,218 |
| 25,541 |
| 24,684 |
|
| Firm transportation | 36,126 |
| 42,790 |
| 46,608 |
| 48,673 |
| 56,777 |
|
| Total residential and commercial | 538,658 |
| 529,750 |
| 521,099 |
| 512,193 |
| 504,203 |
|
| Interruptible | 31 |
| 33 |
| 34 |
| 35 |
| 37 |
|
| BGSS incentive programs | 28 |
| 27 |
| 30 |
| 24 |
| 34 |
|
| Total customers at year-end | 538,717 |
| 529,810 |
| 521,163 |
| 512,252 |
| 504,274 |
|
Interest coverage ratio (1) | 6.35 |
| 7.96 |
| 8.97 |
| 9.57 |
| 10.24 |
|
| Average therm use per customer | | | | | |
| Residential | 959 |
| 885 |
| 824 |
| 1,049 |
| 1,020 |
|
| Commercial, industrial and other | 10,992 |
| 11,183 |
| 11,378 |
| 9,799 |
| 4,466 |
|
| Degree days | 4,537 |
| 4,129 |
| 3,867 |
| 5,015 |
| 5,080 |
|
Weather as a percent of normal (2) | 99.5 | % | 90.0 | % | 82.5 | % | 108.3 | % | 109.6 | % |
| Number of employees | 686 |
| 680 |
| 670 |
| 649 |
| 626 |
|
| |
| (1) | NJNG’s income from operations divided by interest expense. |
| |
| (2) | Normal heating degree days are based on a 20-year average, calculated based upon three reference areas representative of NJNG’s service territory. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
Critical Accounting Policies
We prepare our financial statements in accordance with GAAP. Application of these contracts, Energy Services generates financial margin by identifying market opportunities and simultaneously entering into natural gas purchase/sale, storage or transportation contracts and financial derivative contracts. In cases where storage is utilized to fulfill these contracts, these forecast sales and/or purchases are economically hedged throughaccounting principles requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingencies during the reporting period. We regularly evaluate our estimates, including those related to the calculation of the fair value of derivative instruments, regulatory assets, income taxes, pension and postemployment benefits other than pensions and contingencies related to environmental matters and litigation. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.
Regulatory Accounting
NJNG maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and recognizes the impact of regulatory decisions on its financial derivative contracts. The financial derivative contracts consist primarilystatements. As a result of exchange-traded futures, optionsthe ratemaking process, NJNG is required to apply the accounting principles in ASC 980, Regulated Operations, which differ in certain respects from those applied by unregulated businesses. Specifically, NJNG records regulatory assets when it is probable that certain operating costs will be recoverable from customers in future periods and swap contracts,records regulatory liabilities associated with probable future obligations to customers.
NJNG’s BGSS requires it to project its annual natural gas costs and provides the ability, subject to BPU approval, to recover or refund the difference, if any, of such actual costs compared with the projected costs included in prices through a BGSS charge to customers. Any underrecovery or overrecovery is recorded as a regulatory asset or liability on the Consolidated Balance Sheets and reflected in the BGSS charge to customers in subsequent years.
As recovery of regulatory assets is subject to BPU approval, if there are frequently usedany changes in future regulatory positions, which indicate that recovery of all or a portion of a regulatory asset is not probable, the related cost would be charged to lockincome in anticipated transactionalthe period of such determination.
Impairment of Long-lived assets
Property, plant and equipment and intangible assets are reviewed periodically 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. When an impairment indicator is present, the Company determines if the carrying value of the asset is recoverable by comparing it to the expected undiscounted future cash flows. If carrying value of the asset is greater than the expected undiscounted future cash flows andan impairment charge is recorded in an amount equal to help manage volatility in natural gas market prices. Generally, whenthe excess of the carrying value of the asset over its storage and transportation contracts are exposed to periods of increased market volatility, Energy Services is able to implement strategies that allow them to capture margin by improving the respective time or geographic spreads on a forward basis.fair value.
On July 27, 2017, we acquired certain retailEquity method investments are reviewed periodically when changes in facts and wholesale natural gas energy contract assets from Talen. The acquisition included sales agreements with large commercialcircumstances indicate that the current fair value may be less than the asset’s carrying amount and industrial retail customersrecord an impairment charge in Delaware, Maryland, New Jersey and Pennsylvania, pipeline and storage capacity agreements on various pipelines and various wholesale transportation contracts.an amount equal to the excess of the carrying value of the asset over its fair value if the decline is other than temporary.
Derivative Instruments
Energy Services accounts for its physical commodity contractsWe record our derivative instruments held as assets and its financial derivative instrumentsliabilities at fair value on the Consolidated Balance Sheets. ChangesIn 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 physicalEnergy Services’ commodity contracts and financial derivative instrumentsderivatives are includedrecognized in earnings, as they occur, as a component of operating revenuerevenues or gas purchases on the Consolidated Statements of Operations. Volatility in reported net income at Energy Services can occur over periods of time due to changesChanges 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 instrumentexchange contracts are recognized in earnings. However,gas purchases on the gainsConsolidated 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 and/or a combination of those items. Energy Services’ portfolio is valued using the most current and losses associated withreasonable market information. If the price underlying a physical natural gas arecommodity transaction does not recognized in earnings until the natural gas inventory is withdrawn from storagerepresent a visible and sold, at which timeliquid market, Energy Services realizes the entire marginmay utilize additional published pipeline tariff information and/or other services to determine an equivalent market price. As of September 30, 2018, fair value of its derivative assets and liabilities reported on the transaction.Consolidated Balance Sheets that is based on such pricing is considered immaterial.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating ResultsShould there be a significant change in the underlying market prices or pricing assumptions, Energy Services may experience a significant impact on its financial position, results of operations and cash flows. Refer to Item 7A. Quantitative and Qualitative Disclosures About Market Risks for a sensitivity analysis related to the impact to derivative fair values resulting from changes in commodity prices. The valuation methods we use to determine fair values remained consistent for fiscal 2018, 2017 and 2016. 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.
Energy Services’ financial results forGains and losses associated with derivatives utilized by NJNG to manage the fiscal years ended September 30,price risk inherent in its natural gas purchasing activities are summarizedrecoverable through its BGSS, subject to BPU approval. Accordingly, the offset to the change in fair value of these derivatives is recorded as follows:either a regulatory asset or liability on the Consolidated Balance Sheets.
|
| | | | | | | | | |
| (Thousands) | 2017 | 2016 | 2015 |
Operating revenues (1) | $ | 1,462,681 |
| $ | 1,197,253 |
| $ | 1,934,307 |
|
| Operating expenses | | | |
Gas purchases (including demand charges (2)(3)) | 1,441,310 |
| 1,153,911 |
| 1,795,719 |
|
| Operation and maintenance | 20,313 |
| 20,025 |
| 25,403 |
|
| Depreciation and amortization | 63 |
| 88 |
| 90 |
|
| Other taxes | 1,788 |
| 937 |
| 1,237 |
|
| Total operating expenses | 1,463,474 |
| 1,174,961 |
| 1,822,449 |
|
| Operating (loss) income | (793 | ) | 22,292 |
| 111,858 |
|
| Other income | 1 |
| 98 |
| 438 |
|
| Interest expense, net | 2,747 |
| 1,095 |
| 1,209 |
|
| Income tax (benefit) provision | (4,015 | ) | 7,030 |
| 39,043 |
|
| Net income | $ | 476 |
| $ | 14,265 |
| $ | 72,044 |
|
| |
(1) | Includes related party transactions of approximately $316,000, $9.5 million and $61.5 million during fiscal 2017, 2016 and 2015, respectively, which is eliminated in consolidation.
|
| |
(2) | Costs associated with pipeline and storage capacity that are expensed over the term of the related contracts, which generally varies from less than one year to 10 years. |
| |
(3) | Includes related party transactions of approximately $4.6 million, $14.6 million and $27.9 million during fiscal 2017, 2016 and 2015, respectively, a portion of which are eliminated in consolidation.
|
AsClean Energy Ventures hedges certain of its expected production of SRECs through forward and futures contracts. Clean Energy Ventures intends to physically deliver all SRECs it sells and recognizes SREC revenue as operating revenue on the Consolidated Statements of Operations upon delivery of the underlying SREC.
We have not designated any derivatives as fair value or cash flow hedges as of September 30, Energy Services’ portfolio of financial derivative instruments are composed of:
|
| | | | | | |
| (in Bcf) | 2017 |
| 2016 |
| 2015 |
|
| Net short futures contracts | 16.4 |
| 79.1 |
| 91.1 |
|
| Net long options | — |
| 1.2 |
| 1.2 |
|
Operating RevenuesIncome Taxes and Gas PurchasesCredits
During fiscal 2017, operating revenues increasedThe 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 taxable items. We use the asset and liability method to determine and record deferred tax assets, representing future tax benefits, and deferred tax liabilities, representing future taxes payable, resulting from the differences between the financial reporting amount and the corresponding tax basis of the assets and liabilities using the enacted rates expected to be in effect at the time the differences are settled. An offsetting valuation allowance is recorded when it is more likely than not that some or all of the deferred income tax assets won’t be realized. Any significant changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a material change to earnings and cash flows. For a more detailed description of Income Taxes see $265.4 million and gas purchases increased $287.4 million, Note 12. Income Taxesdue primarily to an approximate 36.8 percent increase in the average price of natural gas and the acquisition of Talen's sales, pipeline and storage capacity agreements, as well as various wholesale transactions, partially offset by a 5.4 percent decrease in wholesale volumes. Gas purchases also include a decrease due to the changes in the economic hedging of natural gas inventory of $75.3 million, partially offset by an increase of $63.4 million in unrealized gains on derivative instruments.accompanying Consolidated Financial Statements.
During fiscal 2016, operating revenues decreased $737.1 millionFor state income tax and gas purchases decreased $641.8 million due primarilyother 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 decreaseliability for the estimate of $59.7 million relatedpotential 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 valuetax rates and/or the treatment of financial hedges,certain items of income or expense. Accounting guidance requires that the Company reflect the effect of tax laws or tax rates at the date of enactment. Additionally, the Company is required to re-measure its deferred tax assets and liabilities as wellof the date of enactment. For non-regulated entities, the effect of changes in tax rates and/or tax laws are required to be included in income from continuing operations for the period that includes the enactment date. For regulated entities, if as the result of an action by a decrease of approximately 26.5 percent in average gas prices, as well as a 12.1 percentregulator it is probable that the future increase or decrease in sales volumes. The price decreases were relatedtaxes payable for items such as changes in tax law or rates will be recovered from or returned to customers through future rates, an asset or liability shall be recognized for that probable increase or decrease in future revenue. Additionally, accounting guidance also requires that regulatory liabilities/assets be considered a temporary difference for which a deferred tax asset/liability shall be recognized. As a result, NJNG grossed up its regulatory liability to reflect the warm winter weather, primarily acrossrequired accounting for the eastern United States, during fiscal 2016, compared with fiscal 2015.tax effects of the revaluation.
Future results at Energy Services are contingent upon natural gas market price volatility drivenConcurrent with the enactment of the current tax reform legislation, the SEC issued Staff Accounting Bulletin No. 118, which lays out an approach that a registrant may follow to comply with the enactment period accounting requirements. Accordingly, registrants can have up to 12 months from the enactment date to complete the accounting for some or all of the income tax effects triggered by variationsthe enactment of the new law. Registrants need to determine and use “reasonable estimates” for some or all of the expected effects beginning with the one-year measurement period. The accounting must be finalized no later than 12 months from the enactment date. If reasonable estimates cannot be determined, the accounting should continue to be based on the old law until reasonable estimates can be determined in botha subsequent period. As of September 30, 2018, our accounting for the supply and demand balances caused by weather and other factors. As a result, variations in weather patterns inincome tax effects of the key market areas served may affect earnings during the fiscal year. Changes in market fundamentals, such as an increase in supply and decrease in demand due to milder temperatures, and reduced volatility, can negatively impact Energy Services’ earnings. See Tax Act is considered complete.Item 7. Management’s Discussion and Analysisof Financial Condition and Results of Operations - Natural Gas Distribution Segment forTetco M-3 Daily Prices, which illustrates the daily natural gas prices in the Northeast market region.
Operation and Maintenance Expense
O&M expense remained relatively flat during fiscal 2017, compared with fiscal 2016. O&M expense decreased $5.4 million, or 21.2 percent, during fiscal 2016, compared with fiscal 2015, due primarily to decreases in incentive compensation, charitable donations and shared services costs.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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. We have no reason to believe that we have any future obligations associated with unrecognized tax benefits; therefore, as of September 30, 2018 and 2017, we have not recorded any liabilities related to uncertain tax positions. 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.
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. For our unregulated subsidiaries, we recognize ITCs as a reduction to income tax expense when the property is placed in service.
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.
Environmental Costs
At the end of each fiscal year, NJNG, with the assistance of an independent consulting firm, updates the environmental review of its MGP sites, including its potential liability for investigation and remedial action. From this review, NJNG estimates expenditures necessary to remediate and monitor these MGP sites. NJNG’s estimate of these liabilities is developed from then-currently available facts, existing technology and current laws and regulations.
In accordance with accounting standards for contingencies, NJNG’s policy is to record a liability when it is probable that the cost will be incurred and can be reasonably estimated. NJNG will determine a range of liabilities and will record the most likely amount. If no point within the range is more likely than any other, NJNG will accrue the lower end of the range. Since we believe that recovery of these expenditures, as well as related litigation costs, is possible through the regulatory process, we have recorded a regulatory asset corresponding to the related accrued liability. Accordingly, NJNG recorded an MGP remediation liability and a corresponding regulatory asset on the Consolidated Balance Sheets, which is based on the most likely amount.
The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations and the ultimate ability of other responsible parties to pay, as well as the potential impact of any litigation and any insurance recoveries. Previously incurred remediation costs, net of recoveries from customers and insurance proceeds received are included in regulatory assets on the Consolidated Balance Sheets.
If there are changes in the regulatory position surrounding these costs, or should actual expenditures vary significantly from estimates in that these costs are disallowed for recovery by the BPU, such costs would be charged to income in the period of such determination. See the Legal Proceedings section in Note 13. Commitments and Contingent Liabilities for more details.
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 impacted by actual employee demographics including age, compensation levels and employment periods, the level of contributions made to the plans, changes in long-term interest rates and the return on plan assets. Changes made to the provisions of the plans or healthcare legislation may also impact current and future postemployment employee benefit costs. Postemployment employee benefit costs may also be significantly affected by changes in key actuarial assumptions, including anticipated rates of return on plan assets, changes in mortality tables, health care cost trends and discount rates used in determining the PBO. In determining the PBO and cost amounts, assumptions can change from period to period and could result in material changes to net postemployment employee benefit periodic costs and the related liability recognized by us.
Our postemployment employee benefit plan assets consist primarily of U.S. equity securities, international equity securities and fixed-income investments, with a targeted allocation of 34 percent, 17 percent and 41 percent, respectively. Fluctuations in actual market returns, as well as changes in interest rates, may result in increased or decreased postemployment employee benefit costs in future periods. Postemployment employee benefit expenses are included in O&M expense on the Consolidated Statements of Operations.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The following is a summary of a sensitivity analysis for each actuarial assumption:
|
| | | | | | | | | | | | | |
| Pension Plans | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (37,153 | ) | | | $ | (4,095 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 46,432 |
| | | $ | 4,756 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (2,619 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 2,619 |
| |
|
| | | | | | | | | | | | | |
| Other Postemployment Benefits | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Discount rate | 1.00 |
| % | | $ | (28,595 | ) | | | $ | (2,728 | ) | |
| Discount rate | (1.00 | ) | % | | $ | 36,736 |
| | | $ | 3,406 |
| |
| Rate of return on plan assets | 1.00 |
| % | | n/a | | | $ | (713 | ) | |
| Rate of return on plan assets | (1.00 | ) | % | | n/a | | | $ | 714 |
| |
| | | | | | | | | |
| Actuarial Assumptions | Increase/ (Decrease) | Estimated
Increase/(Decrease) on PBO
(Thousands) | Estimated
Increase/(Decrease) to Expense
(Thousands) |
| Health care cost trend rate | 1.00 |
| % | | $ | 36,260 |
| | | $ | 3,838 |
| |
| Health care cost trend rate | (1.00 | ) | % | | $ | (28,743 | ) | | | $ | (2,991 | ) | |
On October 1, 2016, we changed our approach used to measure the service and interest cost components of our net periodic benefit costs. Previously, we estimated service cost and interest cost based on a single weighted-average discount rate from the yield curve used to measure our projected benefit obligation. We determine our service and interest cost based upon duration-specific spot rates that are aligned to each year’s future benefit payments. Under the new approach, net periodic benefit costs will be lower during periods of low interest rates and upward-sloping yield curves. Conversely, in a downward-sloping yield curve environment, costs could increase. Refer to Note 10. Employee Benefit Plans in the accompanying Consolidated Financial Statements for further discussion of our change in method.
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 an energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in the United States and Canada. In addition, we invest in clean energy projects and midstream assets and provide various repair, sales and installations services. A more detailed description of our organizational structure can be found in Item 1. Business.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Reporting Segments
We have four primary reporting segments as presented in the chart below:
In addition to our four reporting segments, we have non-utility operations that either provide corporate support services or do not meet the criteria to be treated as a separate reporting segment. These operations, which comprise Home Services and Other, include: appliance repair services, sales and installations at NJRHS and commercial real estate holdings at CR&R.
The Tax Act
On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. Since our fiscal year end is September 30, it is required by the Internal Revenue Code to calculate a statutory rate based upon the federal tax rates in effect before and after the effective date of the change in the taxable year that includes the effective date. Accordingly, we applied a federal statutory tax rate of 24.5 percent during fiscal 2018 and the enacted rate of 21 percent beginning in fiscal 2019.
As a result of the Tax Act, we revalued our deferred tax assets and liabilities at the enactment date to reflect the rates expected to be in effect when the deferred tax assets and liabilities are realized or settled. As of September 30, 2018, NJNG had a regulatory liability that included excess deferred income taxes of $205.4 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles. During fiscal 2018, we recognized an income tax benefit of approximately $17 million for NJNG and approximately $59.6 million for the remaining entities on the Consolidated Statements of Operations. See Note 12. Income Taxes for a more detailed discussion on the Tax Act.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
A summary of our consolidated results in net income and assets by reporting segment and operations for the fiscal years ended September 30, is as follows:
|
| | | | | | | | | | | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| | Net Income | Assets | Net Income | Assets | Net Income | Assets |
| Natural Gas Distribution | $ | 84,048 |
| $ | 2,663,054 |
| $ | 86,930 |
| $ | 2,519,578 |
| $ | 76,104 |
| $ | 2,517,401 |
|
| Clean Energy Ventures | 75,849 |
| 865,018 |
| 24,873 |
| 771,340 |
| 28,393 |
| 665,696 |
|
| Energy Services | 53,139 |
| 396,852 |
| 476 |
| 398,277 |
| 14,265 |
| 327,626 |
|
| Midstream | 24,367 |
| 242,069 |
| 12,857 |
| 232,806 |
| 9,406 |
| 186,259 |
|
| Home Services and Other | (3,555 | ) | 114,732 |
| 6,811 |
| 114,801 |
| 2,882 |
| 109,487 |
|
Intercompany (1) | (412 | ) | (138,061 | ) | 118 |
| (108,295 | ) | 622 |
| (87,899 | ) |
| Total | $ | 233,436 |
| $ | 4,143,664 |
| $ | 132,065 |
| $ | 3,928,507 |
| $ | 131,672 |
| $ | 3,718,570 |
|
| |
| (1) | Consists of transactions between subsidiaries that are eliminated in consolidation. |
Net Income
The primary drivers of the changes noted above, which are described in more detail in the individual segment discussions, are discussed below.
The increase in net income of $101.4 million during fiscal 2018, compared with fiscal 2017, was primarily driven by increased operating income at Energy Services related to colder weather, resulting in increased storage withdrawals due to higher demand coupled with higher volatility resulting in an increase in natural gas price spreads. Net income also increased due to impacts from the Tax Act, including a net income tax benefit of $59.6 million and a decrease in tax expense due to the lower tax rate, which was partially offset by increased O&M expense.
The increase in net income of $393,000 during fiscal 2017, compared with fiscal 2016, was primarily driven by increased margin at our Natural Gas Distribution segment due primarily to increased base rates which were effective October 1, 2016, increased other income at Home Services and Other due to the sale of available for sale securities, increased equity in earnings of affiliates at Midstream and increased revenues and PTCs at Clean Energy Ventures. These increases were partially offset by decreased operating income at Energy Services due primarily to a decrease of $16.4 million related to changes in the value of financial hedges and a decrease at Clean Energy Ventures due primarily to increased depreciation, operating and interest expenses.
Assets
The increase in assets during fiscal 2018, compared with fiscal 2017, was due primarily to additional utility plant at our Natural Gas Distribution segment and an advance payment of $10 million for the IEC acquisition, partially offset by a decrease in regulatory assets at our Natural Gas Distribution segment, as well as a decrease in the market value of the DM Common Units at Midstream.
The increase in assets during fiscal 2017, compared with fiscal 2016, was due primarily to additional solar expenditures at Clean Energy Ventures, the acquisition of Talen's wholesale and retail energy contract assets at Energy Services, increased PennEast capital contributions and an increase in the market value of our DM Common Units at Midstream, along with additional utility plant expenditures at our Natural Gas Distribution segment.
Non-GAAP Financial Measures
Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. Energy Services economically hedges its natural gas inventory with financial derivative instruments and calculates the related tax effect based on the statutory rate. 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 gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. To the extent we utilize forwards or futures to hedge forecasted SREC production, unrealized gains and losses are also eliminated for NFE purposes.
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 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. 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, except per share data) | 2018 | 2017 | 2016 |
| Net income | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| Add: | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,770 |
| (11,241 | ) | 46,883 |
|
| Tax effect | (4,512 | ) | 4,062 |
| (17,018 | ) |
Effects of economic hedging related to natural gas inventory (1) | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Tax effect | 7,362 |
| (13,964 | ) | 13,364 |
|
| Net financial earnings | $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
|
| | | | |
| Basic earnings per share | $ | 2.66 |
| $ | 1.53 |
| $ | 1.53 |
|
| Add: | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 0.31 |
| (0.13 | ) | 0.55 |
|
| Tax effect | (0.05 | ) | 0.05 |
| (0.20 | ) |
Effects of economic hedging related to natural gas inventory (1) | (0.26 | ) | 0.45 |
| (0.43 | ) |
| Tax effect | 0.08 |
| (0.17 | ) | 0.16 |
|
| Basic net financial earnings per share | $ | 2.74 |
| $ | 1.73 |
| $ | 1.61 |
|
| |
| (1) | Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period. |
NFE by reporting segment and other operations for the fiscal years ended September 30, discussed in more detail within the operating results sections of each segment, is summarized as follows:
|
| | | | | | | | | | | | | | | | | |
| (Thousands) | 2018 | | 2017 | | 2016 |
| Natural Gas Distribution | $ | 84,048 |
| 35 | % | | $ | 86,930 |
| 58 | % | | $ | 76,104 |
| 55 | % |
| Clean Energy Ventures | 75,849 |
| 32 |
| | 24,873 |
| 17 |
| | 28,393 |
| 20 |
|
| Energy Services | 60,378 |
| 25 |
| | 18,554 |
| 12 |
| | 21,934 |
| 16 |
|
| Midstream | 24,367 |
| 10 |
| | 12,857 |
| 9 |
| | 9,406 |
| 7 |
|
| Home Services and Other | (3,829 | ) | (2 | ) | | 6,811 |
| 4 |
| | 2,882 |
| 2 |
|
Eliminations (1) | (327 | ) | — |
| | (633 | ) | — |
| | (634 | ) | — |
|
| Total | $ | 240,486 |
| 100 | % | | $ | 149,392 |
| 100 | % | | $ | 138,085 |
| 100 | % |
| |
| (1) | Consists of transactions between subsidiaries that are eliminated in consolidation. |
The increase in NFE during fiscal 2018, compared with fiscal 2017, was driven primarily by higher financial margin generated at Energy Services due primarily to colder weather, resulting in increased storage withdrawals due to higher demand coupled with higher volatility, allowing Energy Services to capture additional margin from natural gas price spreads. The increase in NFE also included a net income tax benefit of $59.6 million associated with the Tax Act, as previously discussed.
The increase in NFE during fiscal 2017, compared with fiscal 2016, was driven primarily by increases at our Natural Gas Distribution segment, Midstream and Home Services and Other, as previously discussed, partially offset by lower financial margin at Energy Services due primarily to lower sales volumes and fewer market opportunities and the decrease at Clean Energy Ventures, as previously discussed.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Natural Gas Distribution Segment
Overview
Our Natural Gas Distribution segment is comprised of NJNG, a natural gas utility that provides regulated retail natural gas service in central and northern New Jersey to approximately 538,700 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 can negatively impact customer growth, operating and financing costs, fluctuations in commodity prices and customer conservation efforts. These risks include, but are not limited to, adverse economic conditions, customer usage, 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.
In addition, NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered to customers on an annual basis. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG receives most of its natural gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the year.
As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 3. Regulation in the accompanying Consolidated Financial Statements for a more detailed discussion on regulatory actions, including filings related to programs and associated expenditures, as well as rate requests related to recovery of capital investments and operating costs.
NJNG’s operations are managed with the goal of providing safe and reliable service, growing its customer base, diversifying its margin, promoting clean energy programs and mitigating the risks discussed above through several key initiatives, including:
earning a reasonable rate of return on the investments in its natural gas distribution and transmission businesses, as well as timely recovery of all prudently incurred costs to provide safe and reliable service throughout NJNG’s territory;
continuing to invest in the safety and integrity of its infrastructure;
managing its customer growth rate, which NJNG expects will be approximately 1.8 percent annually through fiscal 2021;
maintaining a collaborative relationship with the BPU on regulatory initiatives, including:
- planning and authorization of infrastructure investments;
- pursuing rate and regulatory strategies to stabilize and decouple margin, including CIP;
- utilizing BGSS incentive programs through BPU-approved mechanisms to reduce gas costs and generate margin; and
- administering and promoting NJNG’s BPU-approved SAVEGREEN Project;
managing the volatility of wholesale natural gas prices through a hedging program designed to keep customers’ BGSS rates as stable as possible; and
working with the NJDEP and BPU to manage its financial obligations related to remediation activities associated with its former MGP sites.
Base Rate Case
In September 2016, the BPU approved NJNG's base rate case, effective October 2016, which included an increase in base rates in the amount of $45 million. The base rate increase includes a return on common equity of 9.75 percent, a common equity ratio of 52.5 percent and a depreciation rate of 2.4 percent. The approval also included the rate mechanism and five-year extension of SAFE II, rate recovery of NJ RISE capital investment costs through June 30, 2016, recovery of NJNG’s SAFE I, Natural Gas Vehicle Refueling Stations and LNG capital investments and recovery of other costs previously deferred in regulatory assets.
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 and estimates for expected investments over the next two fiscal years:
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.
SAFE and NJ RISE
NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability and integrity of NJNG’s gas distribution system.
The BPU approved recovery of SAFE I capital investments through September 30, 2016, and approved the rate mechanism and extension of SAFE II for an additional five years to replace the remaining unprotected steel mains and services from NJNG’s natural gas distribution system at an estimated cost of approximately $200 million, excluding AFUDC. The accelerated cost recovery methodology for the $157.5 million associated with the extension of SAFE II was approved in NJNG’s new base rates. The remaining $42.5 million in capital expenditures will be requested for recovery in future base rate cases.
The BPU approved NJNG’s NJ RISE capital infrastructure program, which consists of six capital investment projects estimated to cost $102.5 million, excluding AFUDC, for 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 July 2017, the BPU approved NJNG’s annual petition requesting a $4.1 million increase in recoveries of NJ RISE and SAFE II capital investment costs, with a weighted cost of capital of 6.9 percent including a return on equity of 9.75 percent, related to the period ending June 30, 2017, effective October 2017.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On September 17, 2018, the BPU approved NJNG’s annual petition requesting a base rate increase of $6.8 million for the recovery of SAFE II and NJ RISE capital investment costs, with a weighted cost of capital of 6.9 percent including a return on equity of 9.75 percent, related to the 12-months ended June 30, 2018, effective October 1, 2018.
Natural Gas Vehicle Refueling Stations
NJNG has three natural gas vehicle refueling stations open to the public. Costs for these stations were approximately $10 million and are being recovered through NJNG’s base rates, effective October 2016.
Liquefaction/LNG
NJNG’s Liquefaction facility allows NJNG to convert natural gas into LNG to fill its existing LNG storage tanks. Costs for this facility along with other plant upgrades were approximately $36.5 million and are being recovered through NJNG’s base rates effective October 2016.
Southern Reliability Link
The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system reliability and integrity in the southern portion of NJNG’s service territory, estimated to cost between $180 million and $215 million. In January 2016, the BPU issued an order approving NJNG’s modified, proposed SRL pipeline installation, operation and route selection. In March 2016, the BPU issued an order designating the SRL route and exempting the SRL from municipal land use ordinances, regulations, permits and license requirements. In February 2017, the New Jersey Department of Environmental Protection issued a permit authorizing construction of the SRL within the jurisdiction of the Coastal Area Facility Review Act, as well as a Freshwater Wetlands permit. In September 2017, the NJ Pinelands Commission approved construction of the SRL as being compliant with the Commission’s Comprehensive Management Plan. All approvals issued by state agencies are under appeal and certain road-opening permits and easements are in the process of being secured. Construction is expected to begin in fiscal 2019, with an estimated in-service date in 2019.
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:
|
| | | | | | |
| | 2018 | 2017 | 2016 |
| Firm customers | | | |
| Residential | 474,495 |
| 460,013 |
| 448,273 |
|
| Commercial, industrial & other | 28,037 |
| 26,947 |
| 26,218 |
|
| Residential transport | 26,490 |
| 32,653 |
| 36,292 |
|
| Commercial transport | 9,636 |
| 10,137 |
| 10,316 |
|
| Total firm customers | 538,658 |
| 529,750 |
| 521,099 |
|
| Other | 59 |
| 60 |
| 64 |
|
| Total customers | 538,717 |
| 529,810 |
| 521,163 |
|
During fiscal 2018, NJNG added 9,596 new customers, which represents a new customer growth rate of approximately 1.8 percent. During that same time period, NJNG converted 613 existing customers to natural gas heat and other services. This customer growth, as well as commercial customers who switched from interruptible to firm natural gas service, will contribute approximately $5.5 million, on an annualized basis, to utility gross margin. NJNG also added 9,126 and 8,170 new customers and converted 662 and 644 existing customers to natural gas heat and other services during the fiscal years ended September 30, 2017 and 2016, respectively.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
In addition, NJNG currently expects to add approximately 28,000 to 30,000 new customers during the three-year period of fiscal 2019 to 2021. NJNG’s estimates are based on information from municipalities and developers, as well as external industry analysts and management’s experience. NJNG estimates that approximately 68 percent of the growth will come from new construction markets and 32 percent from customer conversions to natural gas from other fuel sources. This new customer and conversion growth would increase utility gross margin under NJNG’s base rates by approximately $5.5 million annually, as calculated under NJNG’s CIP tariff. See the Natural Gas Distribution Segment Operating Results section that follows for a definition and further discussion of utility gross margin.
Energy Efficiency Programs
SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives, which are 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 June 2016, the BPU approved NJNG’s extension of SAVEGREEN through December 31, 2018. On September 17, 2018, the BPU approved the continuation of existing SAVEGREEN programs and the addition of new programs with investments of $135 million through December 2021.
On October 20, 2017, the BPU approved NJNG’s filing to decrease its EE recovery rate, which resulted in an annual decrease of $3.9 million, effective November 1, 2017. On May 25, 2018, NJNG filed a petition with the BPU to decrease its EE recovery rate. On October 16, 2018, NJNG updated this information through September 30, 2018, which will result in an annual decrease of $8.8 million, anticipated to be effective January 1, 2019.
Since inception, $162 million in grants, rebates and loans have been provided to customers, with a total annual recovery of approximately $16.1 million. The recovery includes a weighted average cost of capital that ranges from 6.69 percent to 7.76 percent, with a return on equity of 9.75 percent to 10.3 percent.
Conservation Incentive Program
The CIP facilitates normalizing NJNG’s utility gross margin for variances not only due to weather but also for other factors affecting customer usage, such as conservation and energy efficiency. Recovery of utility gross margin for the non-weather variance through the CIP is limited to the amount of certain gas supply cost savings achieved and is subject to a variable margin review test. Additionally, recovery of the CIP utility gross margin is subject to an annual earnings test. An annual review of the CIP must be filed by June 1, coincident with NJNG’s annual BGSS filing, during which NJNG can request rate changes to the CIP. In May 2014, the BPU approved the continuation of the CIP program with no expiration date. Refer to Note 3. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements, for a discussion of CIP rate actions.
NJNG’s total utility firm gross margin includes the following adjustments related to the CIP mechanism:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
Weather (1) | $ | 205 |
| $ | 19,261 |
| $ | 27,547 |
|
| Usage | (1,629 | ) | (2,309 | ) | 10,420 |
|
| Total | $ | (1,424 | ) | $ | 16,952 |
| $ | 37,967 |
|
| |
| (1) | Compared with the CIP 20-year average, weather was 0.5 percent, 10 percent and 17.5 percent warmer-than-normal during fiscal 2018, 2017 and 2016, respectively. |
Commodity prices
Our Natural Gas Distribution segment is affected by the price of natural gas, which can have a significant impact on our cash flows, short-term financing costs, the price of natural gas charged to our customers through the BGSS clause, our ability to collect accounts receivable, which impacts our bad debt expense, and our ability to maintain a competitive advantage over other fuel sources.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Natural gas commodity prices may experience high volatility as shown in the graph below, which illustrates the daily natural gas prices(1) in the Northeast market region, also known as Tetco M-3.
(1) Midpoint daily gas price sourced from Platts, a division of McGraw Hill Financial.
The maximum price per MMBtu was $94.93, $8.71 and $4.74 and the minimum price was $0.53, $0.36 and $0.67 for the fiscal years ended September 30, 2018, 2017 and 2016, respectively. A more detailed discussion of the impacts of the price of natural gas on operating revenues, gas purchases and cash flows can be found in the Results of Operations and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
BGSS
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 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.
On March 26, 2018, the BPU approved maintaining NJNG's BGSS rate for residential and small commercial customers and an increase to its balancing charge rate, which resulted in a $3.7 million increase to the annual revenues credited to BGSS, effective October 2017. 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. During fiscal 2017, NJNG issued bill credits of $42 million as a result of a decline in the wholesale price of natural gas. There were no bill credits issued during fiscal 2018, related to BGSS prices.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On September 17, 2018, the BPU provisionally approved NJNG’s annual petition to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well changes to the CIP rates, which will result in a $30.9 million annual recovery decrease, effective October 1, 2018. Refer to Note 3. Regulation - BGSS and CIP in the accompanying Consolidated Financial Statements for a further discussion of NJNG’s periodic BGSS rate adjustments and bill credits.
BGSS Incentive Programs
NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of utility gross margin-sharing programs that include off-system sales, capacity release and storage incentive programs. These programs are designed to encourage better utilization and hedging of NJNG’s natural gas supply, transportation and storage assets. Depending on the program, NJNG shares 80 or 85 percent of utility gross margin generated by these programs with firm customers. Should performance of the existing incentives or market conditions warrant, NJNG is permitted to propose a process to re-evaluate and discuss alternative incentive programs annually. Utility gross margin from incentive programs was $12.5 million, $13.7 million and $15 million during the fiscal years ended September 30, 2018, 2017 and 2016, respectively. A more detailed discussion of the impacts to utility gross margin can be found in the Natural Gas Distribution Segment Operating Results section that follows.
Hedging
In order to provide relative price stability to its natural gas supply portfolio, NJNG employs a hedging strategy with the goal of having at least 75 percent of its projected winter periodic BGSS gas sales volumes hedged by each November 1 and at least 25 percent of the projected BGSS gas sales hedged for the following April-through-March period. This is accomplished with the use of various financial instruments including futures, swaps and options used in conjunction with commodity and/or weather-related hedging activity.
Due to the capital-intensive nature of NJNG’s operations and the seasonal nature of its working capital requirements, significant changes in interest rates can impact NJNG’s results. In June 2015, NJNG entered into a transaction to fix a benchmark treasury rate of 3.26 percent associated with a $125 million debt issuance that was finalized in May 2018. The debt issuance coincided with the maturity of NJNG's $125 million, 5.6 percent notes that came due on May 15, 2018. This treasury lock was settled on March 13, 2018, which coincided with the pricing of the new debt being issued. Settlement of the interest rate contract resulted in a $2.6 million loss, which is recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized to earnings over the 30-year term of the $125 million note issued on May 11, 2018.
A more detailed discussion of NJNG’s debt can be found in the Liquidity and Capital Resources and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Societal Benefits Charge
USF
NJNG’s qualifying customers are eligible for the USF program, which is administered by the New Jersey Department of Community Affairs, to help make energy bills more affordable. On September 17, 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which will result in a $1 million annual increase, effective October 1, 2018. Refer to Note 3. Regulation - Societal Benefits Clause in the accompanying Consolidated Financial Statements for a further discussion of NJNG’s USF rates.
Environmental Remediation
NJNG is responsible for the environmental remediation of five 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 $130.8 million as of September 30, 2018, a decrease of $18.2 million, compared with the prior fiscal period.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Other
In May 2016, NJNG included a proposal in its base rate case to recover certain capital costs and incremental operation and maintenance costs related to a March 2016 BPU Order regarding new cybersecurity requirements. This proposal was updated in July 2016, and the associated costs were approved for recovery through NJNG’s new base rates, effective October 2016.
Interest Rate Risk
Due to the capital-intensive nature of NJNG’s operations and the seasonal nature of its working capital requirements, significant changes in interest rates can impact NJNG’s results. A more detailed discussion can be found in the Liquidity and Capital Resources and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Other regulatory filings and a more detailed discussion of the filings in this section can be found in Note 3. Regulation in the accompanying Consolidated Financial Statements.
Commodity Service to Customers
The EDECA, which was enacted in 1999, provides the framework for New Jersey’s retail energy markets, which are open to competition from other electric and natural gas suppliers. 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 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 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.
Operating Results
NJNG’s operating results for the fiscal years ended September 30, are as follows:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Operating expenses | | | |
Gas purchases (1) (2) | 333,208 |
| 269,480 |
| 215,849 |
|
| Operation and maintenance | 161,723 |
| 142,509 |
| 130,575 |
|
Regulatory rider expense (3) | 38,969 |
| 40,243 |
| 39,300 |
|
| Depreciation and amortization | 53,208 |
| 49,347 |
| 47,828 |
|
Energy and other taxes (4) | 44,184 |
| 42,417 |
| 34,561 |
|
| Total operating expenses | 631,292 |
| 543,996 |
| 468,113 |
|
| Operating income | 100,573 |
| 151,641 |
| 126,233 |
|
| Other income, net | 6,864 |
| 4,592 |
| 4,752 |
|
| Interest expense, net of capitalized interest | 25,299 |
| 25,818 |
| 19,930 |
|
| Income tax (benefit) provision | (1,910 | ) | 43,485 |
| 34,951 |
|
| Net income | $ | 84,048 |
| $ | 86,930 |
| $ | 76,104 |
|
| |
| (1) | Includes the purchased cost of the natural gas, fees paid to pipelines and storage facilities, adjustments as a result of BGSS incentive programs and hedging transactions. These expenses are passed through to customers and are offset by corresponding revenues. |
| |
| (2) | Includes related party transactions of approximately $57.2 million, $10.8 million and $10.8 million during fiscal 2018, 2017 and 2016, respectively, a portion of which are eliminated in consolidation. |
| |
| (3) | Consists of expenses associated with state-mandated programs, the RAC and energy efficiency programs, and are calculated on a per-therm basis. These expenses are passed through to customers and offset by corresponding revenues. |
| |
| (4) | Consists primarily of sales tax, which is passed through to customers and offset by corresponding revenues. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Revenues and Gas Purchases
Operating revenues increased 5.2 percent during fiscal 2018 and increased 17 percent during fiscal 2017. Gas purchases increased 23.6 percent during fiscal 2018 and increased 24.8 percent during fiscal 2017. The factors contributing to the increases (decreases) in operating revenues and gas purchases during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | | | | |
| | 2018 v. 2017 | | 2017 v. 2016 |
| (Thousands) | Operating revenue | Gas purchases | | Operating revenue | Gas purchases |
| Firm sales | $ | 49,414 |
| $ | 19,779 |
| | $ | 44,397 |
| $ | 21,634 |
|
Bill credits (1) | 41,971 |
| 39,260 |
| | 19,588 |
| 18,265 |
|
Average BGSS rates (2) | 1,147 |
| 1,413 |
| | (17,874 | ) | (16,544 | ) |
| Off-system sales | 677 |
| 221 |
| | 29,156 |
| 29,117 |
|
| Tax Act impact | (35,910 | ) | — |
| | — |
| — |
|
| CIP adjustments | (18,375 | ) | — |
| | (21,015 | ) | — |
|
Rate impact (3) | — |
| — |
| | 37,436 |
| — |
|
Other (4) | (2,696 | ) | 3,055 |
| | 9,603 |
| 1,159 |
|
| Total increase | $ | 36,228 |
| $ | 63,728 |
| | $ | 101,291 |
| $ | 53,631 |
|
| |
| (1) | Operating revenues include changes in sales tax of $2.7 million and $1.3 million during fiscal 2018 and 2017, respectively. |
| |
| (2) | Operating revenues include changes in sales tax of $266,000 and $1.4 million during fiscal 2018 and 2017, respectively. |
| |
| (3) | Includes rate adjustments for the base rate case, CIP and demand charges. |
| |
| (4) | Other includes changes for NJ RISE/SAFE II and rider rates, including those related to EE, NJCEP and other programs. |
Fiscal 2018 compared with fiscal 2017
The changes in operating revenues and gas purchases during fiscal 2018 were due primarily to:
increased firm sales due primarily to customer growth and higher usage related to weather being 9.9 percent colder than fiscal 2017;
bill credits issued to residential and small commercial customers during fiscal 2017 that did not occur in fiscal 2018; partially offset by
the Tax Act impact, which is comprised of customer credits related to the initial revaluation of excess deferred income taxes and the overcollection of taxes from customers during the second quarter of fiscal 2018, including related interest and sales tax, as well as the effects from the reduction in base rates related to the Tax Act implemented during the third quarter;
a decrease in CIP due primarily to normal weather during fiscal 2018, compared with warmer-than-normal weather during fiscal 2017; and
higher off-system sales due primarily to an increase of 19.7 percent in the average price of natural gas sold, partially offset by a reduction in volumes of 15.9 percent.
Fiscal 2017 compared with fiscal 2016
The changes in operating revenues and gas purchases during fiscal 2017 were due primarily to:
increased firm sales due primarily to customer growth and higher usage, related to weather being 6.8 percent colder;
increased base rates resulting from the settlement of the base rate case;
higher off-system sales due primarily to a 49.8 percent increase in the average price of natural gas sold, partially offset by a 12.2 percent reduction in volumes;
a decrease in bill credits issued to residential and small commercial customers during the months of November 2016 through February 2017 compared with the same period in the prior year; partially offset by
a decrease in CIP due primarily to weather, partially offset by changes in the CIP as a result of the settlement of the base rate case.
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 utility gross margin, a non-GAAP financial measure, when evaluating the operating results of NJNG. NJNG’s utility gross margin is defined as natural gas revenues less natural gas purchases, sales tax and regulatory rider expenses, and may not be comparable to the definition of gross margin used by others in the natural gas distribution business and other industries. Management believes that utility gross margin provides a meaningful basis for evaluating utility operations since natural gas costs, sales tax and regulatory rider expenses are included in operating revenue and passed through to customers and, therefore, have no effect on utility gross margin. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.
Utility Gross Margin
A reconciliation of operating revenues, the closest GAAP financial measure to NJNG’s utility gross margin, is as follows for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Operating revenues | $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Less: | | | |
| Gas purchases | 333,208 |
| 269,480 |
| 215,849 |
|
| Energy taxes | 39,426 |
| 37,917 |
| 29,832 |
|
| Regulatory rider expense | 38,969 |
| 40,243 |
| 39,300 |
|
| Utility gross margin | $ | 320,262 |
| $ | 347,997 |
| $ | 309,365 |
|
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:
|
| | | | | | | | | | | | | | | | | |
| | 2018 | | 2017 | | 2016 |
| ($ in thousands) | Margin | Bcf | | Margin | Bcf | | Margin | Bcf |
| Utility gross margin/throughput | | | | | | | | |
| Residential | $ | 203,195 |
| 45.5 |
| | $ | 218,093 |
| 40.7 |
| | $ | 187,762 |
| 36.9 |
|
| Commercial, industrial and other | 46,636 |
| 8.9 |
| | 51,510 |
| 8.7 |
| | 46,878 |
| 7.3 |
|
| Firm transportation | 51,880 |
| 15.5 |
| | 58,172 |
| 14.4 |
| | 54,841 |
| 14.1 |
|
| Total utility firm gross margin/throughput | 301,711 |
| 69.9 |
| | 327,775 |
| 63.8 |
| | 289,481 |
| 58.3 |
|
| BGSS incentive programs | 12,482 |
| 150.2 |
| | 13,724 |
| 178.4 |
| | 14,978 |
| 216.7 |
|
| Interruptible/off-tariff agreements | 6,069 |
| 46.2 |
| | 6,498 |
| 55 |
| | 4,906 |
| 61.5 |
|
| Total utility gross margin/throughput | $ | 320,262 |
| 266.3 |
| | $ | 347,997 |
| 297.2 |
| | $ | 309,365 |
| 336.5 |
|
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Utility Firm Gross Margin
A description of the factors contributing to the (decreases) increases in utility firm gross margin during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2018 v. 2017 | 2017 v. 2016 |
| Tax Act impact | | $ | (33,657 | ) | | | $ | — |
| |
| SAVEGREEN | | (977 | ) | | | (345 | ) | |
| NJ RISE/SAFE II | | 4,334 |
| | | — |
| |
| Customer growth | | 4,236 |
| | | 3,619 |
| |
| Rate impact | | — |
| | | 35,019 |
| |
| Total (decrease) increase | | $ | (26,064 | ) | | | $ | 38,293 |
| |
BGSS Incentive Programs
A description of the factors contributing to the (decreases) increases in utility gross margin generated by NJNG’s BGSS incentive programs during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2018 v. 2017 | 2017 v. 2016 |
| Storage | | $ | (954 | ) | | | $ | 378 |
| |
| Capacity release | | (745 | ) | | | (1,672 | ) | |
| Off-system sales | | 457 |
| | | 39 |
| |
| Total decrease | | $ | (1,242 | ) | | | $ | (1,255 | ) | |
Fiscal 2018 compared with fiscal 2017
The decrease in utility gross margin was due primarily to the Tax Act impact, as previously discussed, a decrease in value in the storage incentive program and a decrease in capacity release due to less volume and lower values, partially offset by increased margins for off-system sales.
Fiscal 2017 compared with fiscal 2016
The increase in utility gross margin was due primarily to the base rate increase and customer growth, along with an increase in interruptible/off-tariff agreements, partially offset by decreased margins related to capacity release due to lower volumes and lower value of capacity.
Operation and Maintenance Expense
A summary and description of the factors contributing to the increases (decreases) in O&M expense during fiscal 2018 and 2017, are as follows:
|
| | | | | | | | | | |
| (Thousands) | 2018 v. 2017 | 2017 v. 2016 |
| Shared corporate costs | | $ | 5,991 |
| | | $ | 3,061 |
| |
| Compensation and benefits | | 5,767 |
| | | 5,412 |
| |
| Consulting | | 5,184 |
| | | 512 |
| |
| Other | | 2,272 |
| | | 2,949 |
| |
| Total increase | | $ | 19,214 |
| | | $ | 11,934 |
| |
Fiscal 2018 compared with fiscal 2017
The increase in O&M expense during fiscal 2018 was due primarily to:
increased shared corporate costs due primarily to increased headcount and incentives, along with additional expenses related to a voluntary early retirement program;
increased compensation and benefits as a result of voluntary early retirement program costs; and
increased consulting expenses due primarily to technology improvements.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Fiscal 2017 compared with fiscal 2016
The increase in O&M expense during fiscal 2017 was due primarily to:
increased compensation costs due primarily to increases in headcount, incentives, healthcare premiums, lower capitalized labor and increased pension/OPEB benefit costs related to changes in actuarial assumptions, partially offset by implementation of the spot rate method to measure interest and service cost components;
additional amortization of regulatory assets in other that are being recovered as a result of the settlement of the base rate case; and
increased shared corporate costs resulting primarily from increased software maintenance, incentives, postemployment costs and healthcare premiums.
Depreciation Expense
Depreciation expense increased $3.9 million in fiscal 2018, compared with fiscal 2017, as a result of additional utility plant being placed into service. Depreciation expense increased $1.5 million in fiscal 2017, compared with fiscal 2016, as a result of additional utility plant being placed into service, as well as an increase in the overall depreciation rate from 2.34 percent to 2.4 percent resulting from the settlement of the base rate case.
Operating Income
Operating income decreased $51.1 million, or 33.7 percent, in fiscal 2018, compared with fiscal 2017, due primarily to the decrease in total utility gross margin of $27.7 million, as well as the increase in O&M and depreciation, as previously discussed. Operating income increased $25.4 million, or 20.1 percent, in fiscal 2017, compared with fiscal 2016, due primarily to theincrease in total utility gross margin of $38.6 million, partially offset by the increase in O&M, as previously discussed.
Income Tax Provision
Income tax provision decreased $45.4 million during fiscal 2018, compared with fiscal 2017, due primarily to the impacts of the change in the federal corporate tax rate resulting from the Tax Act. Income tax provision increased $8.5 million during fiscal 2017, compared with fiscal 2016, due primarily to an increase in pre-tax income, partially offset by increased costs associated with the removal of distribution main that was placed in service before 1981, for which the tax benefit is passed on to customers in base rates.
Net Income
Net income decreased $2.9 million to $84 million in fiscal 2018, compared with fiscal 2017, due primarily to decreased utility gross margin and increased O&M and depreciation, partially offset by the decrease in the income tax provision as previously discussed.
Net income increased $10.8 million to $86.9 million in fiscal 2017, compared with fiscal 2016, due primarily to an increase in operating income as discussed above, partially offset by an increase in the income tax provision as discussed above and interest expense associated with debt issued in June 2016.
Clean Energy Ventures Segment
Overview
Our Clean Energy Ventures segment actively pursues opportunities in the renewable energy markets. Clean Energy Ventures has entered into various agreements to install solar net-metered systems for residential and commercial customers, as well as large commercial grid-connected projects. In addition, Clean Energy Ventures has entered into various long-term agreements, including PPAs, to supply energy from wind and solar projects.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Solar
Solar projects placed in service and related expenditures for the fiscal years ended September 30, are as follows:
|
| | | | | | | | | | | | | | | | | | | | | |
| ($ in Thousands) | 2018 | 2017 | 2016 |
| Placed in service | Projects | MW | Costs | Projects | MW | Costs | Projects | MW | Costs |
Grid-connected (1) | 3 |
| 33.7 |
| $ | 70,216 |
| 2 |
| 20.0 |
| $ | 62,700 |
| 5 |
| 21.8 |
| $ | 51,240 |
|
| Net-metered: | | | | | | | | | |
Commercial (1) | — |
| — |
| 74 |
| 3 |
| 7.1 |
| 19,714 |
| — |
| — |
| 3 |
|
| Residential | 910 |
| 8.5 |
| 27,342 |
| 1,300 |
| 12.4 |
| 37,901 |
| 1,123 |
| 10.4 |
| 34,318 |
|
| Total placed in service | 913 |
| 42.2 |
| $ | 97,632 |
| 1,305 |
| 39.5 |
| $ | 120,315 |
| 1,128 |
| 32.2 |
| $ | 85,561 |
|
| |
| (1) | Includes projects subject to sale-leaseback arrangements. |
Since its inception, Clean Energy Ventures has constructed a total of 231.3 MW of solar capacity and has an additional 19.6 MW under construction. Projects that are placed in service through December 31, 2019, qualify for a 30 percent federal ITC. The credit will decline to 26 percent for property under construction during 2020 and to 22 percent for property under construction during 2021. The ITC will be reduced to 10 percent for any property that is under construction before 2022, but not placed in service before 2024.
Clean Energy Ventures may enter into transactions to sell certain of its commercial solar assets concurrent with agreements to lease the assets back over a period of six to 15 years. The Company will continue to operate the solar assets and are responsible for related expenses and entitled to retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects have been transferred to the buyer; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. As of September 30, 2018, Clean Energy Ventures has entered into five sale-leaseback transactions, three during fiscal 2018 with costs of $70.2 million and two during fiscal 2017 with costs of $31.1 million. Clean Energy Ventures did not enter into sale-leasebacks during fiscal 2016.
Excluding the project costs related to the commercial solar projects that were included in the sale-leaseback transactions, the Company had $27.4 million, $89.2 million and $85.6 million of solar-related capital expenditures were ITC-eligible during fiscal 2018, 2017 and 2016, respectively, which were recognized in income tax (benefit) provision on the Consolidated Statements of Operations when the assets were placed in service.
As part of its solar investment portfolio, Clean Energy Ventures operates a residential solar program, The Sunlight Advantage®, which provides qualifying homeowners the opportunity to have a solar system installed at their home with no installation or maintenance expenses. Clean Energy Ventures owns, operates and maintains the system over the life of the contract in exchange for monthly lease payments.
Once a solar installation has received the proper certifications and commences operations, each MWh of electricity produced creates an SREC that represents the renewable energy attribute of the solar-electricity generated that can be sold to third parties, predominantly load-serving entities that are required to comply with the solar requirements under New Jersey’s renewable portfolio standard.
SREC activity for the fiscal years ended September 30, is as follows:
|
| | | | | | |
| | 2018 | 2017 | 2016 |
| Inventory balance as of October 1, | 48,357 |
| 24,135 |
| 33,203 |
|
| SRECs generated | 245,147 |
| 197,521 |
| 160,009 |
|
| SRECs delivered | (188,312 | ) | (173,299 | ) | (169,077 | ) |
| Inventory balance as of September 30, | 105,192 |
| 48,357 |
| 24,135 |
|
SRECs generated increased 24.1 percent and 23.4 percent for the fiscal years ended September 30, 2018 and 2017, respectively, compared with the previous fiscal years. The average SREC sales price was $217 in fiscal 2018, $233 in fiscal 2017 and $214 in fiscal 2016.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Clean Energy Ventures hedges a portion of its expected SREC production through the use of forward sales contracts. The following table reflects the hedged percentage of SREC inventory and projected SREC production related to its in-service commercial and residential assets as of September 30, 2018:
|
| |
Energy Year (1) | Percent of SRECs Hedged |
| 2019 | 91% |
| 2020 | 86% |
| 2021 | 58% |
| |
| (1) | Energy years are compliance periods for New Jersey’s renewable portfolio standard that run from June 1 to May 31. |
There are no direct costs associated with the production of SRECs by our solar assets. All related costs are included as a component of O&M expenses on the Consolidated Statements of Operations, including such expenses as facility maintenance and various fees.
Onshore Wind
Clean Energy Ventures has invested in small to mid-size onshore wind projects that fit its investment profile and has a total of 116.9 MW of wind capacity as of September 30, 2018. The wind projects are eligible for PTCs for a 10-year period following commencement of operations and have PPAs of various terms in place, which typically govern the sale of energy, capacity and/or renewable energy credits. Once a wind installation has commenced operations, each MWh of electricity produced creates an REC that represents the renewable energy attribute of the wind-electricity generated that can be sold to third parties. There are no direct costs associated with the production of RECs by our wind assets and all related costs are included as a component of O&M expenses on the Consolidated Statements of Operations.
On June 1, 2018, Clean Energy Ventures completed the sale of its membership interest in its 9.7 MW wind farm in Two Dot, Montana to NorthWestern Energy for a total purchase price of $18.5 million. The transaction generated a pre-tax gain of approximately $951,000, which is recognized as a reduction to O&M on the Consolidated Statements of Operations.
In March 2018, Clean Energy Ventures committed to a plan to sell its remaining wind assets, and it is probable that these sales will be completed within the next 12 months. Accordingly, we classified our wind assets and related liabilities as held for sale, as of March 31, 2018, on Consolidated Balance Sheets.
Operating Results
Clean Energy Ventures’ financial results for the fiscal years ended September 30, are summarized as follows:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Operating revenues | $ | 71,375 |
| $ | 64,394 |
| $ | 53,540 |
|
| Operating expenses | | | |
| Operation and maintenance | 26,298 |
| 23,448 |
| 18,897 |
|
| Depreciation and amortization | 31,877 |
| 31,834 |
| 23,971 |
|
| Other taxes | 1,137 |
| 1,209 |
| 900 |
|
| Total operating expenses | 59,312 |
| 56,491 |
| 43,768 |
|
| Operating income | 12,063 |
| 7,903 |
| 9,772 |
|
| Other income, net | 2,174 |
| 2,072 |
| 2,333 |
|
| Interest expense, net | 18,320 |
| 16,263 |
| 10,304 |
|
| Income tax benefit | (79,932 | ) | (31,161 | ) | (26,592 | ) |
| Net income | $ | 75,849 |
| $ | 24,873 |
| $ | 28,393 |
|
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Revenues
Operating revenues increased $7 million in fiscal 2018, compared with fiscal 2017, due primarily to increased electricity sales from solar assets. Operating revenues increased $10.9 million in fiscal 2017, compared with fiscal 2016, due primarily to higher SREC sales and increased electricity sales from wind assets.
Operation and Maintenance Expense
O&M expense increased $2.9 million in fiscal 2018, compared with fiscal 2017, due primarily to increased consulting expenses and additional maintenance costs related to additional solar assets, partially offset by a pre-tax gain of $951,000 associated with the sale of the Two Dot wind farm. O&M expense increased $4.6 million in fiscal 2017, compared with fiscal 2016, due primarily to additional maintenance, leasing and administrative costs associated with wind and solar projects placed in service, as well as increased shared corporate costs.
Depreciation Expense
Depreciation expense remained relatively flat in fiscal 2018, compared with fiscal 2017, due primarily to increases in solar capital additions that were offset by depreciation expense on wind assets no longer being recorded resulting from their reclassification as held for sale in March 2018. Depreciation expense increased $7.9 million in fiscal 2017, compared with fiscal 2016, as a result of increases in wind and solar projects placed in service.
Income Tax Benefit
Income tax benefit increased $48.8 million during fiscal 2018, compared with fiscal 2017, due primarily to an income tax benefit of $61.4 million associated with the Tax Act, which was caused by a revaluation of the deferred tax liability related to the book versus tax differences in depreciation calculated on property-related items, partially offset by the decrease in ITCs recognized as a result of solar sale-leaseback financing activity.
Income tax benefit during fiscal 2018, 2017 and 2016 includes $10.5 million, $24.6 million and $25.7 million, respectively, of ITCs associated with solar projects, that were completed and placed into service during the corresponding fiscal year. Income tax benefit during fiscal 2018, 2017 and 2016 includes $10.8 million, $9.9 million and $6.7 million, respectively, of PTCs associated with wind projects. Clean Energy Ventures recognized $19 million, $29.2 million and $27 million related to tax credits, net of deferred taxes, during fiscal 2018, 2017 and 2016, respectively.
Net Income
Net income in fiscal 2018 increased $51 million, compared with fiscal 2017, due primarily to the increased income tax benefit resulting from the impact of the Tax Act partially offset by a decreased income tax benefit related to ITCs, as previously discussed. Net income during fiscal 2017 decreased $3.5 million, compared with fiscal 2016, due primarily to increased costs related to depreciation and O&M, as previously discussed, as well as an increase in interest expense related to higher debt associated with capital expenditures, partially offset by increases in operating revenues and tax benefits recognized due primarily to an increase in PTCs, as previously discussed.
Energy Services Segment
Overview
Energy Services markets and sells natural gas to wholesale and retail customers and manages natural gas storage and transportation assets throughout major market areas across North America. Energy Services maintains a strategic portfolio of natural gas storage and transportation contracts that it utilizes in conjunction with its market expertise to provide service and value to its customers. Availability of these storage and transportation contracts allows Energy Services to generate market opportunities by capturing price differentials over specific time horizons and between geographic market locations.
Energy Services also provides management of storage and transportation assets for natural gas producers and regulated utilities. These management transactions typically involve the release of producer/utility-owned storage and/or transportation capacity in combination with an obligation to purchase and/or deliver physical natural gas. In addition to the contractual purchase and/or sale of physical natural gas, Energy Services generates or pays fee-based margin in exchange for its active management and may provide the producer and/or utility with additional margin based on actual results.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued) ��
In conjunction with the active management of these contracts, Energy Services generates financial margin by identifying market opportunities and simultaneously entering into natural gas purchase/sale, storage or transportation contracts and financial derivative contracts. In cases where storage is utilized to fulfill these contracts, these forecast sales and/or purchases are economically hedged through the use of financial derivative contracts. The financial derivative contracts consist primarily of exchange-traded futures, options and swap contracts, and are frequently used to lock in anticipated transactional cash flows and to help manage volatility in natural gas market prices. Generally, when its storage and transportation contracts are exposed to periods of increased market volatility, Energy Services is able to implement strategies that allow it to capture margin by improving the respective time or geographic spreads on a forward basis.
In July 2017, Energy Services acquired certain retail and wholesale natural gas energy contract assets from Talen. The acquisition included sales agreements with large commercial and industrial retail customers in Delaware, Maryland, New Jersey and Pennsylvania, pipeline and storage capacity agreements on various pipelines and various wholesale transportation contracts.
On February 28, 2018, NJR sold all of the issued and outstanding shares of capital stock of NJRRS, which was a component of our Energy Services segment. We received $9.5 million in cash and a natural gas swap contract with a gain at inception of $14.6 million. The sale generated a pre-tax gain of $3.7 million, which was recognized as a reduction to O&M on the Consolidated Statements of Operations.
Energy Services accounts for its physical commodity contracts and its financial derivative instruments at fair value on the Consolidated Balance Sheets. Changes in the fair value of physical commodity contracts and financial derivative instruments are included in earnings as a component of operating revenue or gas purchases on the Consolidated Statements of Operations. Volatility in reported net income at Energy Services can occur over periods of time due to changes in the fair value of derivatives, as well as timing differences related to certain transactions. Unrealized gains and losses can fluctuate as a result of changes in the price of natural gas, SRECs and foreign currency from the original transaction price. Volatility in earnings can also occur as a result of timing differences between the settlement of financial derivatives and the sale of the underlying physical commodity. For example, when a financial instrument settles and the physical natural gas is injected into inventory, the realized gains and losses associated with the financial instrument are recognized in earnings. However, the gains and losses associated with the physical natural gas are not recognized in earnings until the natural gas inventory is withdrawn from storage and sold, at which time Energy Services realizes the entire margin on the transaction.
Operating Results
Energy Services’ financial results for the fiscal years ended September 30, are summarized as follows:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
Operating revenues (1) | $ | 2,112,804 |
| $ | 1,462,681 |
| $ | 1,197,253 |
|
| Operating expenses | | | |
Gas purchases (including demand charges (2)(3)) | 1,995,335 |
| 1,441,310 |
| 1,153,911 |
|
| Operation and maintenance | 32,821 |
| 20,313 |
| 20,025 |
|
| Depreciation and amortization | 76 |
| 63 |
| 88 |
|
| Other taxes | 2,732 |
| 1,788 |
| 937 |
|
| Total operating expenses | 2,030,964 |
| 1,463,474 |
| 1,174,961 |
|
| Operating income (loss) | 81,840 |
| (793 | ) | 22,292 |
|
| Other income | 240 |
| 1 |
| 98 |
|
| Interest expense, net | 3,945 |
| 2,747 |
| 1,095 |
|
| Income tax provision (benefit) | 24,996 |
| (4,015 | ) | 7,030 |
|
| Net income | $ | 53,139 |
| $ | 476 |
| $ | 14,265 |
|
| |
| (1) | Includes related party transactions of approximately $48.3 million, $316,000 and $9.5 million during fiscal 2018, 2017 and 2016, respectively, which is eliminated in consolidation. |
| |
| (2) | Costs associated with pipeline and storage capacity that are expensed over the term of the related contracts, which generally varies from less than one year to 10 years. |
| |
| (3) | Includes related party transactions of approximately $4.5 million, $4.6 million and $14.6 million during fiscal 2018, 2017 and 2016, respectively, a portion of which are eliminated in consolidation. |
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, Energy Services’ portfolio of financial derivative instruments are composed of:
|
| | | | | | |
| (in Bcf) | 2018 |
| 2017 |
| 2016 |
|
| Net short futures contracts | 24.3 |
| 16.4 |
| 79.1 |
|
| Net long options | — |
| — |
| 1.2 |
|
Operating Revenues and Gas Purchases
During fiscal 2018, operating revenues increased $650.1 million and gas purchases increased $554 million, due primarily to increased volume and price spreads resulting from market volatility caused by changes in weather and related demand. Gas purchases also include an increase due to the changes in the economic hedging of natural gas inventory of $61 million, partially offset by a decrease of $25.7 million in unrealized gains on derivative instruments.
During fiscal 2017, operating revenues increased $265.4 million and gas purchases increased $287.4 million due primarily to an approximate 36.8 percent increase in the average price of natural gas and the acquisition of Talen’s sales, pipeline and storage capacity agreements, as well as various wholesale transactions, partially offset by a 5.4 percent increase in wholesale volumes. Gas purchases also include a decrease due to the changes in the economic hedging of natural gas inventory of $75.3 million, partially offset by an increase of $63.4 million in unrealized gains on derivative instruments.
Future results at Energy Services are contingent upon natural gas market price volatility driven by variations in both the supply and demand balances caused by weather and other factors. As a result, variations in weather patterns in the key market areas served may affect earnings during the fiscal year. Changes in market fundamentals, such as an increase in supply and decrease in demand due to milder temperatures, and reduced volatility, can negatively impact Energy Services’ earnings. See Item 7. Management’s Discussion and Analysisof Financial Condition and Results of Operations - Natural Gas Distribution Segment forTetco M-3 Daily Prices, which illustrates the daily natural gas prices in the Northeast market region.
Operation and Maintenance Expense
O&M expense increased $12.5 million or 61.6 percent during fiscal 2018, compared with fiscal 2017, due primarily to increased incentive compensation and shared corporate costs, partially offset by the pre-tax gain of $3.7 million, associated with the sale of NJRRS. O&M expense remained relatively unchanged during fiscal 2017, compared with fiscal 2016.
Income Tax Provision
Income tax benefit increased $29 million during fiscal 2018, compared with fiscal 2017, due primarily to increased operating income and income tax expenseof $6.1 million related to the revaluation of deferred tax assets due to the Tax Act, partially offset by the lower effective tax rate as a result of the new tax legislation. Income taxes decreased $11 million during fiscal 2017, compared with fiscal 2016, due primarily to decreased operating income.
Net Income
Net income increased $52.7 million during fiscal 2018, compared with fiscal 2017, due primarily to the increase in operating income, partially offset by an increase in O&M and income tax expense, as previously discussed. Net income decreased $13.8 million during fiscal 2017, compared with fiscal 2016, due primarily to the decrease in operating income, partially offset by the related decrease in income tax expense. Net income decreased $57.8 million during fiscal 2016, compared with fiscal 2015, due primarily to lower operating income, partially offset by the related decrease in income tax expense.
Non-GAAP Financial Measures
Management uses financial margin and NFE, non-GAAP financial measures, when evaluating the operating results of Energy Services. Energy Services economically hedges its natural gas inventory with financial derivative instruments and calculates the related tax effect based on the statutory rate. Financial margin and NFE are based on removing timing differences associated with certain derivative instruments, as discussed above. Management views these measures as representative of the overall expected economic result and uses these measures to compare Energy Services’ results against established benchmarks and earnings targets, as these measures eliminate the impact of volatility on GAAP earnings as a result of timing differences associated with the settlement of derivative instruments. To the extent that there are unanticipated impacts from changes in the market value related to the effectiveness of economic hedges, Energy Services’ actual non-GAAP results can differ from the results anticipated at the outset of the transaction. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
When Energy Services reconciles the most directly comparable GAAP measure to both financial margin and NFE, the current periodcurrent-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 gas flows.
Financial Margin
The following table is a computation of Energy Services’ financial margin for the fiscal years ended September 30.
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Operating revenues | $ | 1,462,681 |
| $ | 1,197,253 |
| $ | 1,934,307 |
| $ | 2,112,804 |
| $ | 1,462,681 |
| $ | 1,197,253 |
|
| Less: Gas purchases | 1,441,310 |
| 1,153,911 |
| 1,795,719 |
| 1,995,335 |
| 1,441,310 |
| 1,153,911 |
|
| Add: | | |
Unrealized (gain) loss on derivative instruments and related transactions (1) | (10,063 | ) | 48,855 |
| (39,408 | ) | 26,728 |
| (10,063 | ) | 48,855 |
|
Effects of economic hedging related to natural gas inventory (2) | 38,470 |
| (36,816 | ) | (8,225 | ) | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Financial margin | $ | 49,778 |
| $ | 55,381 |
| $ | 90,955 |
| $ | 121,627 |
| $ | 49,778 |
| $ | 55,381 |
|
| |
| (1) | Includes unrealized (gains) losses related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $85,000, $(751,000), and $(1.3) million and $465,000 for the fiscal years ended September 30, 2018, 2017 2016 and 2015,2016, respectively. |
| |
| (2) | Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period. |
A reconciliation of operating income, the closest GAAP financial measure to Energy Services’ financial margin, is as follows for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Thousands) | 2017 | 2016 | 2015 |
| Operating (loss) income | $ | (793 | ) | $ | 22,292 |
| $ | 111,858 |
|
| Add: | | | |
| Operation and maintenance | 20,313 |
| 20,025 |
| 25,403 |
|
| Depreciation and amortization | 63 |
| 88 |
| 90 |
|
| Other taxes | 1,788 |
| 937 |
| 1,237 |
|
| Subtotal | 21,371 |
| 43,342 |
| 138,588 |
|
| Add: | | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (10,063 | ) | 48,855 |
| (39,408 | ) |
| Effects of economic hedging related to natural gas inventory | 38,470 |
| (36,816 | ) | (8,225 | ) |
| Financial margin | $ | 49,778 |
| $ | 55,381 |
| $ | 90,955 |
|
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Operating income (loss) | $ | 81,840 |
| $ | (793 | ) | $ | 22,292 |
|
| Add: | | | |
| Operation and maintenance | 32,821 |
| 20,313 |
| 20,025 |
|
| Depreciation and amortization | 76 |
| 63 |
| 88 |
|
| Other taxes | 2,732 |
| 1,788 |
| 937 |
|
| Subtotal | 117,469 |
| 21,371 |
| 43,342 |
|
| Add: | | | |
| Unrealized loss (gain) on derivative instruments and related transactions | 26,728 |
| (10,063 | ) | 48,855 |
|
| Effects of economic hedging related to natural gas inventory | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Financial margin | $ | 121,627 |
| $ | 49,778 |
| $ | 55,381 |
|
Financial margin increased $71.8 million during fiscal 2018, compared with fiscal 2017, due primarily to increased volume and price spreads resulting from market volatility caused by changes in weather and related demand. Financial margin decreased $5.6 million during fiscal 2017, compared with fiscal 2016, due primarily to fewer market opportunities related to transportation assets and timing of certain transactions related to storage withdrawals along with a warmer than normal winter and a milder than normal spring. Financial margin decreased $35.6 million during fiscal 2016, compared with fiscal 2015, due primarily to lower volatility and narrower price spreads resulting from the warmer weather and fewer market opportunities, as previously discussed.
Net Financial Earnings
A reconciliation of Energy Services’ net income (loss), the most directly comparable GAAP financial measure to NFE, is as follows for the fiscal years ended September 30:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Net income | $ | 476 |
| $ | 14,265 |
| $ | 72,044 |
| $ | 53,139 |
| $ | 476 |
| $ | 14,265 |
|
| Add: | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (10,063 | ) | 48,855 |
| (39,408 | ) | |
| Unrealized loss (gain) on derivative instruments and related transactions | | 26,728 |
| (10,063 | ) | 48,855 |
|
Tax effect (1) | 3,635 |
| (17,734 | ) | 14,653 |
| (4,281 | ) | 3,635 |
| (17,734 | ) |
| Effects of economic hedging related to natural gas inventory | 38,470 |
| (36,816 | ) | (8,225 | ) | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Tax effect | (13,964 | ) | 13,364 |
| 3,058 |
| 7,362 |
| (13,964 | ) | 13,364 |
|
| Net financial earnings | $ | 18,554 |
| $ | 21,934 |
| $ | 42,122 |
| $ | 60,378 |
| $ | 18,554 |
| $ | 21,934 |
|
| |
| (1) | Includes taxes related to an intercompany transaction between NJNG and Energy Services that have been eliminated in consolidation of approximately $(337,000), $427,000 and $716,000 and $(262,000) for the fiscal years ended September 30, 2018, 2017 2016 and 2015,2016, respectively. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
NFE increased $41.8 million during fiscal 2018, compared with fiscal 2017, due primarily to higher financial margin, partially offset by increased O&M expense, as previously discussed, and an income tax expense of $6.1 million associated with the Tax Act, as previously discussed. NFE decreased $3.4 million during fiscal 2017, compared with fiscal 2016, due primarily to a decrease in financial margin as previously discussed, and higher interest expense related to increased borrowing, partially offset by a reduction in income tax expense related to the decrease in NFE. NFE decreased $20.2 million during fiscal 2016, compared with fiscal 2015, due primarily to a decrease in financial margin, partially offset by lower O&M.
Future results are subject to Energy Services’ ability to expand its wholesale sales and service activities and are contingent upon many other factors, including an adequate number of appropriate and credit qualifiedcredit-qualified counterparties in an active and liquid natural marketplace,marketplace; volatility in the natural gas market due to weather or other fundamental market factors impacting supply and/or demand,demand; transportation, storage and/or other market arbitrage opportunities,opportunities; sufficient liquidity in the overall energy trading marketmarket; and continued access to liquidity in the capital markets.
Midstream Segment
Overview
Our Midstream segment invests in natural gas assets, such as natural gas transportation and storage facilities. We believe that acquiring, owning and developing these midstream assets, which operate under a tariff structure that has either regulated or market-based rates, can provide us a growth opportunity. To that end, we have a 50 percent ownership interest in Steckman Ridge, a storage facility that operates under market-based rates, and a 20 percent ownership interest in PennEast, a natural gas pipeline. PennEast received a Certificate of Public Convenience and Necessity for the project from FERC on January 19, 2018. PennEast has advised that it currently expects the pipeline which we estimate to be completed and operational in 2019. PennEast may reviseHowever, the project timeline further upon receipt of a Certificate of Public Conveniencecould be delayed beyond 2019, due to factors beyond PennEast’s ability to control or estimate precisely, including potential delays in obtaining (or the inability to obtain) governmental and Necessity from FERC.regulatory approvals and land-use rights and unforeseen construction delays. As of September 30, 2017,2018, our net investments in Steckman Ridge and PennEast were $120.3$117 million and $52.3$73.9 million, respectively.
In September 2015, Midstream exchanged its 5.53 percent ownership interest in Iroquois with Dominion Midstream Partners, L.P. for 1.84 million DM Common Units. As of September 30, 2017,2018, the market value of the DM Common Units was $58.8$32.9 million. See Note 2. Summary of Significant Accounting Policies - Available for Sale Securities in the accompanying Consolidated Financial Statements for a more detailed discussion.
Operating Results
The financial results of our Midstream segment for the fiscal years ended September 30, are summarized as follows:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Equity in earnings of affiliates | $ | 16,165 |
| $ | 17,797 |
| $ | 13,936 |
|
| Operation and maintenance | $ | 4,441 |
| $ | 2,302 |
| $ | 1,197 |
|
| Other income | $ | 5,775 |
| $ | 4,162 |
| $ | 3,130 |
|
| Interest expense, net | $ | 1,667 |
| $ | 960 |
| $ | 287 |
|
| Income tax provision | $ | (8,548 | ) | $ | 5,820 |
| $ | 6,130 |
|
| Net income | $ | 24,367 |
| $ | 12,857 |
| $ | 9,406 |
|
Equity in earnings of affiliates are driven primarily by storage revenues generated by Steckman Ridge and AFUDC earned at PennEast.
Equity in earnings of affiliates is as follows for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Steckman Ridge | $ | 11,283 |
| $ | 13,351 |
| $ | 14,050 |
|
| PennEast | 4,882 |
| 4,446 |
| (114 | ) |
| Total equity in earnings of affiliates | $ | 16,165 |
| $ | 17,797 |
| $ | 13,936 |
|
Equity in earnings of affiliates decreased $1.6 million during fiscal 2018, compared with fiscal 2017, due primarily to decreases in revenue and increases in debt service costs at Steckman Ridge. Equity in earnings of affiliates increased $3.9 million during fiscal 2017, compared with fiscal 2016, due primarily to increased AFUDC earned at PennEast resulting from the cumulative effect adjustment recorded in fiscal 2017.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Operating Results
The financial results of our Midstream segment for the fiscal years ended September 30, are summarized as follows:
|
| | | | | | | | | |
| (Thousands) | 2017 | 2016 | 2015 |
| Equity in earnings of affiliates | $ | 17,797 |
| $ | 13,936 |
| $ | 17,487 |
|
| Operation and maintenance | $ | 2,302 |
| $ | 1,197 |
| $ | 1,136 |
|
| Other income | $ | 4,162 |
| $ | 3,130 |
| $ | 977 |
|
| Interest expense, net | $ | 960 |
| $ | 287 |
| $ | 717 |
|
| Income tax provision | $ | 5,820 |
| $ | 6,130 |
| $ | 6,849 |
|
| Net income | $ | 12,857 |
| $ | 9,406 |
| $ | 9,780 |
|
Equity in earnings of affiliates are driven primarily by storage revenues generated by Steckman Ridge and, through September 29, 2015, transportation revenues generated by Iroquois.
Equity in earnings of affiliates is as follows for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Thousands) | 2017 | 2016 | 2015 |
| Steckman Ridge | $ | 13,351 |
| $ | 14,050 |
| $ | 12,330 |
|
Iroquois (1) | — |
| — |
| 5,164 |
|
| PennEast | 4,446 |
| (114 | ) | (7 | ) |
| Total equity in earnings of affiliates | $ | 17,797 |
| $ | 13,936 |
| $ | 17,487 |
|
| |
(1) | Transportation revenues generated by Iroquois ended September 29, 2015.
|
Equity in earnings of affiliatesO&M expense increased $3.9$2.1 million during fiscal 2017,2018, compared with fiscal 2016,2017, due primarily to the AFUDC earned at PennEast. Equity in earnings of affiliates decreased $3.6 million during fiscal 2016, compared with fiscal 2015, due primarily to the exchange of our ownership interest in Iroquois during the fourth quarter of fiscal 2015, partially offset by increases in storage service revenue and demand for hub services at Steckman Ridge.
increased shared corporate costs. O&M expense increased $1.1 million during fiscal 2017, compared with fiscal 2016, due primarily to increased consulting expenses, charitable donations and shared services costs. O&M expense remained relatively flat during fiscal 2016, compared with fiscal 2015.
Other income increased $1.6 million during fiscal 2018, compared with fiscal 2017, and increased $1 million during fiscal 2017, compared with fiscal 2016, due primarily to increased interest income from Steckman Ridge and dividend income from our investment in DM Common Units. Other income increased $2.2 million during fiscal 2016, compared with fiscal 2015, due primarily to dividend income from the DM Common Units.
Interest expense, net increased $707,000 during fiscal 2018, compared with fiscal 2017, and $673,000 during fiscal 2017, compared with fiscal 2016, due primarily to increased intercompany borrowing related to our PennEast investment andinvestment.
Income taxes decreased $430,000$14.4 million during fiscal 2016,2018, compared with fiscal 2015,2017, due primarily to proceeds generated by our investments that are being used to reduce intercompany loans.
an income tax benefit of $13.9 million associated with the Tax Act. The income tax provision remained relatively unchanged during fiscal 2017, compared with fiscal 2016. Equity in earnings increased,increased; however, the tax benefits associated with AFUDC reduced the overall tax expense. The
Net income tax provision decreased $719,000 duringin fiscal 2016,2018 increased $11.5 million, compared with fiscal 2015,2017, due primarily to the income tax benefit and the decrease in effective tax rate related to the Tax Act, as previously discussed, partially offset by lower equity in earnings of affiliates, as discussed above.
previously discussed. Net income increased $3.5 million in fiscal 2017, increased $3.5 million, compared with fiscal 2016, due primarily to the increase in equity in earnings of affiliates, as discussed above. Net income decreased $374,000 in fiscal 2016, compared with fiscal 2015, due primarily to the decrease in equity in earnings of affiliates, partially offset by the increase in other income and the decreases in the income tax provision and net interest expense.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Home Services and Other Operations
Overview
The financial results of Home Services and Other consist primarily of the operating results of NJRHS and CR&R.NJRHS. NJRHS provides service, sales and installation of appliances to approximately 112,000110,000 service contract customers and has been focused on growing its installation business and expanding its service contract customer base. Home Services and Other also includes organizational expenses incurred at NJR. NJR Energy, a subsidiary ofand rental income at CR&R, which invested in other energy-related ventures, was dissolved on November 28, 2016, and all assets were moved to CR&R during the first quarter of fiscal 2017.&R.
Operating Results
The consolidated financial results of Home Services and Other for the fiscal years ended September 30, are summarized as follows:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Operating revenues | $ | 49,591 |
| $ | 48,497 |
| $ | 48,703 |
| $ | 50,057 |
| $ | 49,591 |
| $ | 48,497 |
|
| Operation and maintenance | $ | 40,245 |
| $ | 40,106 |
| $ | 39,601 |
| $ | 43,731 |
| $ | 40,245 |
| $ | 40,106 |
|
| Energy and other taxes | $ | 3,938 |
| $ | 3,777 |
| $ | 3,815 |
| $ | 4,042 |
| $ | 3,938 |
| $ | 3,777 |
|
| Other income, net | $ | 6,467 |
| $ | 869 |
| $ | 685 |
| $ | 6,892 |
| $ | 6,467 |
| $ | 869 |
|
| Income tax provision | $ | 3,857 |
| $ | 1,387 |
| $ | 1,551 |
| $ | 11,944 |
| $ | 3,857 |
| $ | 1,387 |
|
| Net income | $ | 6,811 |
| $ | 2,882 |
| $ | 3,420 |
| |
| Net (loss) income | | $ | (3,555 | ) | $ | 6,811 |
| $ | 2,882 |
|
Operating revenue remained relatively flat during fiscal 2018, compared with fiscal 2017. Operating revenue increased $1.1 million during fiscal 2017, compared with fiscal 2016, due primarily to increased furnace/air conditioner combination installations at NJRHS related to increased marketing promotions, along with increased contract revenue, partially offset by decreased operating revenue at CR&R due to the sale of a 56,400 square foot office building.
Operating revenue decreased $206,000O&M expense increased $3.5 million during fiscal 2016,2018, compared with fiscal 2015,2017, due primarily to a decreasepre-tax gain of $1.9 million, associated with the sale of a 56,400 square foot office building that was recorded during fiscal 2017, as well as an increase in heating equipment installations and generator sales at NJRHS resulting from warmer weather, partially offset by increased solar installations and increased contract revenue as a result of existing customers upgradingconsulting expense due primarily to enhanced plans and expanded service contract product lines.additional technology improvements. O&M expense remained relatively flat during fiscal 2017 compared with fiscal 2016.
Other income, net remained relatively unchanged during fiscal 2018, compared with fiscal 2017, due primarily to pre-tax gains associated with the sale of available for sale securities of $5.3 million and $5.4 million during fiscal 2018 and 2017, respectively. Other income, net increased $5.6 million during fiscal 2017, compared with fiscal 2016, due primarily to the sale of available for sale securities, which resulted in a pre-tax gain during fiscal 2017 of $5.4 million. Other income, net remained relatively flat during fiscal 2016, compared with fiscal 2015.
Income taxes increased $2.5 million during fiscal 2017, compared with fiscal 2016, due primarily to the increase in other income, as previously discussed. Income taxes decreased $164,000 during fiscal 2016, compared with fiscal 2015, due primarily to the decrease in operating revenues and the increase in O&M at NJRHS.
Net income increased $3.9 million during fiscal 2017, compared with fiscal 2016, due primarily to the increases in other income and operating revenue, partially offset by the increase in the income tax provision, as discussed above. Net income during fiscal 2016 decreased $538,000, compared with fiscal 2015, due primarily to the decrease in operating revenues and the increase in O&M, partially offset by the decrease in income taxes, as discussed above.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Income taxes increased $8.1 million during fiscal 2018, compared with fiscal 2017, due primarily to tax expense of $9.7 millionassociated with the Tax Act. Income taxes increased $2.5 million during fiscal 2017, compared with fiscal 2016, due primarily to the increase in other income, as previously discussed.
Net income decreased $10.4 million during fiscal 2018, compared with fiscal 2017, due primarily to increased income tax provision, as previously discussed. Net income during fiscal 2017 increased $3.9 million, compared with fiscal 2016, due primarily to the increases in other income and operating revenue, partially offset by the increase in the income tax provision.
Non-GAAP Financial Measures
NFE is based on removing timing differences associated with NJR's variable-for-fixed interest rate swap. Non-GAAP financial measures are not in accordance with, or an alternative to GAAP, and should be considered in addition to, and not as a substitute for the comparable GAAP measure. A reconciliation of Home Services and Other's net income for the fiscal years ended September 30, to the GAAP financial measure most directly comparable to NFE, is as follows:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Net income (loss) | $ | (3,555 | ) | $ | 6,811 |
| $ | 2,882 |
|
| Add: | | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (381 | ) | — |
| — |
|
| Tax effect | 107 |
| — |
| — |
|
| Net financial earnings (loss) | $ | (3,829 | ) | $ | 6,811 |
| $ | 2,882 |
|
Liquidity and Capital Resources
Our objective is to maintain an efficient consolidated capital structure that reflects the different characteristics of each reporting segment and business operations and provides adequate financial flexibility for accessing capital markets as required.
Our consolidated capital structure as of September 30, was as follows:
| | | | 2017 |
| 2016 |
| 2018 |
| 2017 |
|
| Common stock equity | 46 | % | 48 | % | 49 | % | 46 | % |
| Long-term debt | 38 |
| 44 |
| 41 |
| 38 |
|
| Short-term debt | 16 |
| 8 |
| 10 |
| 16 |
|
| Total | 100 | % | 100 | % | 100 | % | 100 | % |
Common Stock Equity
We satisfy our external common equity requirements, if any, through issuances of our common stock, including the proceeds from stock issuances under our DRP. The DRP allows us, at our option, to use treasury shares or newly issued shares to raise capital. In December 2015,On September 28, 2018, we registered an additional 5approximately 3.2 million shares of ouradditional common stock for issuance under the DRP. WeNJR raised $17.5approximately $41.7 million of equity by issuing approximately 1,014,000 new shares through the waiver discount feature of the DRP during fiscal 2018. NJR did not issue new shares through the waiver discount feature of the DRP during fiscal 2017.
NJR also raised approximately $17.1 million and $16$17.5 million of equity through the DRP by issuing approximately 472,000413,000 and 471,000472,000 shares of treasury stock during fiscal 20172018 and 2016,2017, respectively.
In 1996, the Board of Directors authorized us to implement a share repurchase program, which was expanded seven times since the inception of the program, authorizing a total of 19.5 million shares of common stock for repurchase. As of September 30, 2017,2018, we have repurchased a total of approximately 17.1 million shares and may repurchase an additional 2.4 million shares under the approved program. There were 105,000 and 126,600 shares of common stock shares repurchased during fiscal 2017 and 2016, respectively.2017.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Debt
NJR and its unregulated subsidiaries generally rely on cash flows generated from operating activities and the utilization of committed credit facilities to provide liquidity to meet working capital and short-term debt financing requirements. NJNG also relies on the issuance of commercial paper for short-term funding. NJR and NJNG periodically access the capital markets to fund long-lived assets through the issuance of long-term debt securities.
As of September 30, 2017, we had a working capital deficit of $223.5 million, net income of $132.1 million and cash flows from operations of $248 million. The working capital deficit was primarily caused by the reclassification of approximately $150 million of long-term debt to current maturities. We believe that our existing borrowing availability, equity proceeds and cash flows from operations will be sufficient to satisfy our working capital, capital expenditures and dividend requirements for the next 12 months. NJR, NJNG, Clean Energy Ventures, Midstream and Energy Services currently anticipate that each of their financing requirements for the next 12 months will be met primarily through the issuance of short and long-term debt, meter and solar sale-leasebacks and proceeds from our DRP, including utilizing the waiver discount feature.
We believe that as of September 30, 2017,2018, NJR and NJNG were, and currently are, in compliance with all existing debt covenants, both financial and non-financial.
Short-Term Debt
We use our short-term borrowings primarily to finance Energy Services’ short-term liquidity needs, Midstream segment’s PennEast contributions, share repurchases and, on an initial basis, Clean Energy Ventures’ investments. Energy Services’ use of high volume storage facilities and anticipated pipeline park-and-loan arrangements, combined with related economic hedging activities in the volatile wholesale natural gas market, create significant short-term cash requirements.
NJNG satisfies its debt needs by issuing short- 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.
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, 2017,2018, NJR and NJNG, respectively, had revolving credit facilities totaling $425 million and $250 million, and letters of credit outstanding totaling $13.4$14.9 million and $731,000, which reduced the amounts available under the facilities along with short-term borrowings to $157$322 million and $238$185 million. Short-term borrowings were as follows:
| | | | Three Months Ended | Twelve Months Ended | Three Months Ended | Twelve Months Ended |
| ($ in thousands) | September 30, 2017 | September 30, 2018 |
| NJR | | |
| Notes Payable to banks: | | |
| Balance at end of period | $ | 255,000 |
| $ | 255,000 |
| $ | 87,950 |
| $ | 87,950 |
|
| Weighted average interest rate at end of period | 2.14 | % | 2.14 | % | 3.07 | % | 3.07 | % |
| Average balance for the period | $ | 259,672 |
| $ | 239,591 |
| $ | 63,089 |
| $ | 197,154 |
|
| Weighted average interest rate for average balance | 2.11 | % | 1.80 | % | 3.02 | % | 2.64 | % |
| Month end maximum for the period | $ | 299,400 |
| $ | 299,400 |
| $ | 87,950 |
| $ | 330,900 |
|
| NJNG | | |
| Commercial Paper and Notes Payable to banks: | | |
| Balance at end of period | $ | 11,000 |
| $ | 11,000 |
| $ | 64,000 |
| $ | 64,000 |
|
| Weighted average interest rate at end of period | — | % | 1.13 | % | 2.18 | % | 2.18 | % |
| Average balance for the period | $ | 889 |
| $ | 222 |
| $ | 63,698 |
| $ | 31,924 |
|
| Weighted average interest rate for average balance | 0.38 | % | 0.09 | % | 2.07 | % | 1.37 | % |
| Month end maximum for the period | $ | 11,000 |
| $ | 11,000 |
| $ | 82,000 |
| $ | 82,000 |
|
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 November and December.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
NJR
On September 28, 2015, NJR entered into a $425 million Amended and Restated Credit Agreement, which refinanced an earlier $425 million revolving credit facility that was scheduled to expire on August 22, 2017.facility. The NJR Credit Facility is scheduled to terminate on September 28, 2020, subject to two mutual options for a one-year extension beyond that date. Certain of NJR’s unregulated subsidiaries have guaranteed to the lenders all of NJR’s obligations under the NJR Credit Facility.
The NJR Credit Facility permits the borrowing of revolving loans and swingline loans, as well as the issuance of letters of credit. The NJR Credit Facility also includes an accordion feature, which would allow NJR, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit Facility in minimum $5 million increments up to a maximum of $100 million. In addition, borrowings under the NJR Credit Facility are conditioned upon compliance with a maximum leverage ratio (consolidated total indebtedness to consolidated total capitalization as defined in the NJR Credit Facility) of not more than .65 to 1.00 at any time. As of September 30, 2017,2018, the consolidated total indebtedness to total capitalization ratio, as defined in the NJR Credit Facility, was 5451 percent.
On June 25, 2018, the $425 million NJR Credit Facility was amended to permit liens and the disposition of assets relating to sale-leaseback or other similar tax equity financing arrangements of meter assets or of solar or wind facilities. These transactions are permissible so long as NJR is in compliance with certain covenants both before and after such incurrence, and if no event of default may be caused by such sale-leaseback or similar arrangement.
As of September 30, 2017,2018, NJR had $255$88 million outstanding under the NJR Credit Facility. Neither NJNG nor its assets are obligated or pledged to support the NJR Credit Facility.
During fiscal 2017,2018, NJR’s average interest rate under the NJR Credit Facility was 1.82.64 percent, resulting in interest expense of $4.4$4.9 million. Based on average borrowings under the facilities of $239.6$197.2 million during the period, a 100 basis point change in the underlying average interest rate would have caused a change in interest expense of approximately $2.5$2.1 million during fiscal 2017.2018.
As of September 30, 2017,2018, NJR has six letters of credit outstanding totaling $13.4$14.9 million. Three letters of credit totaling $10.4$11.9 million are on behalf of Energy Services and three letters of credit totaling $3 million are on behalf of Clean Energy Ventures. These letters of credit reduce the amount available under NJR’s committed credit facility by the same amount. NJR does not anticipate that these letters of credit will be drawn upon by the counterparties and they will be renewed as necessary.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Energy Services’ letters of credit are used for margin requirements for natural gas transactions and expire on dates ranging from December 20172018 to September 2018.2019. Clean Energy Ventures’ letters of credit are used to secure construction of ground-mounted solar projects and to secure obligations pursuant to an Interconnection Services Agreement.interconnection services agreement. They expire on dates ranging from May 20182019 to August 2018.2019.
NJNG
NJNG’s commercial paper is sold through several commercial banks under an issuing and paying agency agreement and is supported by the $250 million NJNG Credit Facility. The NJNG Credit Facility permits the borrowing of revolving loans and swing loans, as well as the issuance of letters of credit. It also permits an increase to the facility, from time to time, with the existing or new lenders, in a minimum of $15 million increments up to a maximum of $50 million at the lending banks’ discretion. Borrowings under NJNG’s credit facility are conditioned upon compliance with a maximum leverage ratio (consolidated total indebtedness to consolidated total capitalization as defined in the NJNG Credit Facility) of not more than .65 to 1.00 at any time. As of September 30, 2017,2018, NJNG’s consolidated total indebtedness to total capitalization ratio was 4543 percent. As of September 30, 2017,2018, 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 $238$185 million. During fiscal 2017,2018, NJNG’s weighted average interest rate on outstanding commercial paper was .091.37 percent, resulting in interest expense of $2,500.$557,300. Based on average borrowings under the facility of $222,169$31.9 million during the period, a 100 basis point change in the underlying average interest rate would have caused a change in interest expense of approximately $2,200$325,400 during fiscal 2017.2018.
As of September 30, 2017,2018, NJNG has two letters of credit outstanding for $731,000. These letters of credit reduce the amount available under NJNG’s committed credit facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by the counterparties. These letters of credit are used as collateral for soil remediation systems and expire onin August 2018.2019.
Short-Term Debt Covenants
Borrowings under the NJR Credit Facility and NJNG Credit Facility are conditioned upon compliance with a maximum leverage ratio (consolidated total indebtedness to consolidated total capitalization as defined in the applicable agreements), of
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
not more than .65 to 1.00 at any time. These revolving credit facilities contain customary representations and warranties for transactions of this type. They also contain customary events of default and certain covenants that will limit NJR’s or NJNG’s ability, beyond agreed upon thresholds, to, among other things:
•incur additional debt;
•incur liens and encumbrances;
•make dispositions of assets;
•enter into transactions with affiliates; and
•merge, consolidate, transfer, sell or lease all or substantially all of the borrowers’ or guarantors’ assets.
These covenants are subject to a number of exceptions and qualifications set forth in the applicable agreements.
Default Provisions
The agreements governing our long-term and short-term debt obligations include provisions that, if not complied with, could require early payment or similar actions. Default events include, but are not limited to, the following:
•defaults for non-payment;
•defaults for breach of representations and warranties;
•defaults for insolvency;
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
•defaults for non-performance of covenants;
•cross-defaults to other debt obligations of the borrower; and
•guarantor defaults.
The occurrence of an event of default under these agreements could result in all loans and other obligations of the borrower becoming immediately due and payable and the termination of the credit facilities or term loan.
Long-Term Debt
NJR
The MetLife Facility, an unsecured, uncommitted $100 million private placement shelf note agreement with MetLife, allowed NJR to issue senior notes to MetLife or certain of MetLife’s affiliates during a three-year issuance period that ended September 26, 2016, and was not renewed. There were no notes outstanding under the expired facility.
NJR has outstanding $25 million of 2.51 percent senior notes due September 15, 2018, which were issued under a now-expired facility with MetLife and as of September 30, 2017, were classified as a current maturity of long-term debt.
NJR has $50 million of 3.25 percent senior notes due September 2022, issued under a private placement debt shelf facility.
OnIn November 7, 2014, NJR issued $100 million in 3.48 percent senior notes due November 7, 2024, under the Prudential Facility, which fully utilized the remaining capacity under the facility. The notes issued under the Prudential Facility are guaranteed by certain unregulated subsidiaries of NJR.
OnIn March 22, 2016, NJR entered into a Note Purchase Agreementnote purchase agreement under which we issued, on August 18, 2016, $50 million of the Company’s 3.2 percent senior notes due August 18, 2023, and $100 million of the Company’s 3.54 percent senior notes due August 18, 2026. The notes are guaranteed by certain of our unregulated subsidiaries of the Company.subsidiaries. The notes are unsecured. The proceeds of the notes were used for general corporate purposes, including working capital and capital expenditures.
OnIn August 18, 2017, NJR entered into a $100 million credit agreement due August 16, 2019. The term loan will accrueaccrues interest at a variable rate determined monthly, which is LIBOR plus 70 basis points. The weighted averageOn January 26, 2018, NJR entered into a variable-for-fixed interest rate on the on theswap for its variable rate term loan, aswhich fixed the variable rate at 2.84 percent. As of September 30, 2017,2018, the $100 million term loan, net of deferred financing costs, was 1.95 percent. Proceeds fromclassified as a current maturity of long-term debt.
On June 8, 2018, NJR entered into a note purchase agreement, under which we issued $100 million of 3.96 percent senior notes due June 8, 2028. The notes are not secured by assets, but are instead guaranteed by certain unregulated subsidiaries of NJR. The proceeds of the term loannotes will be used for general corporate purposes, including, but not limited to, funding capital expenditures.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On July 17, 2018, the $100 million variable rate term loan was amended to permit the disposition of assets relating to sale-leaseback or other similar tax equity financing arrangements of meter assets or of solar or wind facilities. These transactions are permissible so long as NJR is in compliance with certain covenants both before and working capital.after such incurrence, and if no event of default may be caused by such sale-leaseback or similar arrangement.
Neither NJNG nor its assets are obligated or pledged to support NJR’s long-term debt.
NJNG
NJNG and the Trustee are parties to the Mortgage Indenture, which secures all of NJNG'sNJNG’s outstanding FMB. The Mortgage Indenture provides a direct first mortgage lien upon substantially all of the operating properties and franchises of NJNG (other than excepted property, such as cash on hand, choses-in-action, securities, rent, natural gas meters and certain materials, supplies, appliances and vehicles), subject only to certain permitted encumbrances. The Mortgage Indenture contains provisions subjecting after-acquired property (other than excepted property and subject to pre-existing liens, if any, at the time of acquisition) to the lien thereof.
As of September 30, 2017,2018, NJNG’s long-term debt consisted of $575 million in fixed-rate debt issuances, secured by the Mortgage Indenture, with maturities ranging from 20182024 to 2046,2048, and $97 million in secured variable rate debt, with maturities ranging from 2027 to 2041, which are both secured by the Mortgage Indenture, and $28.9$26.4 million in capital leases with various maturities ranging from 20172019 to 2025.
On May 31, 2017, the BPU approved a petition filed by NJNG requesting authorization over a three-year period to issue up to $400 million of medium-term notes with a maturity of not more than 40 years, for up to five years with an option for two additional one-year extensions; enter into interest rate risk management transactions related to debt securities and redeem and refinance or defease any of NJNG’s outstanding long-term debt securities.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
On April 15, 2015, NJNG issued $50 million of 2.82 percent senior notes due April 15, 2025, and $100 million of 3.66 percent senior notes due April 15, 2045, in the private placement market pursuant to a note purchase agreement entered into on February 12, 2015. The notes are secured by an equal principal amount of NJNG’s FMB (Series SS and TT, respectively) issued under NJNG’s Mortgage Indenture. The proceeds of the notes were used for general corporate purposes, to refinance or retire debt and to fund capital expenditure requirements. The notes are subject to required prepayments upon the occurrence of certain events. NJNG may at any time prepay all or a portion of the notes at a make-whole prepayment price.
On June 1, 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with a forecasted $125 million debt issuance expected in May 2018. This forecasted debt issuance coincides with the maturity of NJNG’s existing $125 million, 5.6 percent notes due May 15, 2018, which as of September 30, 2017, were classified as a current maturity of long-term debt on the Consolidated Balance Sheets.
On June 21, 2016, NJNG entered into a Note Purchase Agreement, under which NJNG issued $125 million of its 3.63 percent senior notes due June 21, 2046. The notes are secured by an equal principal amount of NJNG’s FMB (series UU) issued under NJNG’s Mortgage Indenture. The proceeds of the notes will be used for general corporate purposes, including, but not limited to, refinancing or retiring short-term debt and funding capital expenditures. The notes are subject to required prepayments upon the occurrence of certain events. NJNG may prepay all or any part of the notes in amounts not less than $1 million in aggregate principal amount of the notes then outstanding at 100 percent of the aggregate principal amount, plus accrued interest and a make-whole amount, if applicable.
On January 17, 2017, the Companywe completed the purchase of three FMBs in lieu of redemption with an aggregate principal amount totaling $35.8 million. The FMBs bore interest at rates ranging from 4.5 percent to 4.9 percent. The bonds purchased in lieu of redemption are being held by the Companyus to provide an opportunity to evaluate remarketing alternatives.
On May 11, 2018, NJNG entered into a note purchase agreement, under which NJNG issued $125 million of 4.01 percent senior notes due May 11, 2048. The interest rate includes the quoted March 9, 2018 30-year treasury rate, plus a market-based credit spread. The notes are secured by an equal principal amount of NJNG's FMB (series VV) issued under NJNG's Mortgage Indenture. The proceeds of the notes will be used for general corporate purposes, including, but not limited to, refinancing or retiring short-term debt and funding capital expenditures.
In June 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with a $125 million debt issuance that was finalized in May 2018. This debt issuance coincided with the maturity of NJNG's $125 million, 5.6 percent notes that came due on May 15, 2018. This treasury lock was settled on March 13, 2018, which coincided with the pricing of the new debt being issued. Settlement of the treasury lock resulted in a $2.6 million loss, which is recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized to earnings over the 30-year term of the $125 million, 4.01 percent notes that were issued on May 11, 2018.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
In August 2011, NJNG completed a refunding of its outstanding Auction-Rate Securities whereby the EDA issued a total of $97 million of Natural Gas Facilities Refunding Revenue Bonds (New Jersey Natural Gas Company Project) composed of three series of bonds. EDA Bonds are special, limited obligations of the EDA payable solely from payments made by NJNG pursuant to a Loan Agreement and are secured by the pledge of $97 million principal amount of the FMB issued by the Company.
EDA Bonds accrue interest at a variable rate determined monthly, which was initially calculated as a rate of .55 percent, plus 70 percent of one month LIBOR, subject to earlier redemption or conversion to another interest rate mode. The maximum interest rate on the EDA Bonds is 12 percent per annum. NJNG’s obligations under the Loan Agreement, and its corresponding obligations under the FMB, match the respective principal amounts, interest rates and maturity dates of the EDA Bonds. The weighted average interest rate on the EDA Bonds as of September 30, 2017,2018, was 1.422.03 percent.
The interest rates on variable rate debt may vary based upon market conditions. Sudden increases in the interest rate could cause a change in interest expense and cash flow for the Company in the future.
NJR is not obligated directly or contingently with respect to the NJNG notes or the FMB.
Long-Term Debt Covenants and Default Provisions
The NJR and NJNG long-term debt instruments contain customary representations and warranties for transactions of their type. They also contain customary events of default and certain covenants that will limit NJR or NJNG’s ability beyond agreed upon thresholds to, among other things:
•incur additional debt (including a covenant that limits the amount of consolidated total debt of the borrower at the end of a fiscal quarter to 65 percent of the consolidated total capitalization of the borrower, as those terms are defined in the applicable agreements, and a covenant limiting priority debt to 20 percent of the borrower’s consolidated total capitalization, as those terms are defined in the applicable agreements);
•incur liens and encumbrances;
•make loans and investments;
•make dispositions of assets;
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
•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 FMB issued by NJNG under the Mortgage Indenture are subject to certain default provisions. Events of Default, as defined in the Mortgage Indenture, consist mainly of:
•failure for 30 days to pay interest when due;
•failure to pay principal or premium when due and payable;
•failure to make sinking fund payments when due;
•failure to comply with any other covenants of the Mortgage Indenture after 30 days’ written notice from the Trustee;
•failure to pay or provide for judgments in excess of $30 million in aggregate amount within 60 days of the entry thereof; or
•certain events that are or could be the basis of a bankruptcy, reorganization, insolvency or receivership proceeding.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Upon the occurrence and continuance of such an Event of Default, the Mortgage Indenture, subject to any provisions of law applicable thereto, provides that the Trustee may take possession and conduct the business of NJNG, may sell the trust estate or proceed to foreclose the lien of the Mortgage Indenture. The interest rate on defaulted principal and interest, to the extent permitted by law, on the FMB issued under the Mortgage Indenture is the rate stated in the applicable supplement or, if no such rate is stated, six percent per annum.
Sale-Leaseback
NJNG
NJNG received $7.8 million, $9.6 million $7.1 million and $7.2$7.1 million in fiscal 2018, 2017 2016 and 2015,2016, respectively, in connection with the sale-leaseback of its natural gas meters. During fiscal 2018, 2017 2016 and 2015,2016, NJNG exercised early purchase options with respect to meter leases by making final principal payments of $2.2 million, $2.4 million and $1.9 million, and $768,000, respectively. NJNG continues to evaluate this sale-leaseback program based on current market conditions. As noted, natural gas meters are accepted as property under the Mortgage Indenture.
Clean Energy Ventures
During September 2017, Clean Energy Ventures received proceeds of $71.5 million and $32.9 million in fiscal 2018 and 2017, respectively, in connection with the sale-leaseback of commercial solar assets. Clean Energy Ventures has entered into transactions to sell twocertain of its commercial solar assets concurrent with agreements to lease the assets back over seven year periods.six to 15-year terms. These sale-leasebacks are financing obligations secured by the solar assets and related future cash flows from SREC and energy sales. ITCs and other tax benefits associated with these solar projects were transferred to the buyer. Clean Energy Ventures will continue to operate the solar projects and retain ownership of SRECs generated, and has the option to renew the lease or repurchase the assets at the end of the lease term. Clean Energy Ventures received proceedsterm per the terms of $32.9 million in connection with these sale-leasebacks.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)the arrangement.
Contractual Obligations
The following table is a summary of NJR, NJNG, Energy Services and Clean Energy Ventures contractual cash obligations and financial commitments and their applicable payment due dates as of September 30, 2017:2018:
| | | | | Up to | 2-3 | 4-5 | After | | Up to | 1-3 | 3-5 | After |
| (Thousands) | Total | 1 Year | Years | 5 Years | Total | 1 Year | Years | 5 Years |
Long-term debt (1) | $ | 1,548,726 |
| $ | 184,769 |
| $ | 157,472 |
| $ | 105,694 |
| $ | 1,100,791 |
| $ | 1,783,345 |
| $ | 139,772 |
| $ | 74,338 |
| $ | 172,472 |
| $ | 1,396,763 |
|
Capital lease obligations (1) | 44,154 |
| 12,436 |
| 18,524 |
| 8,380 |
| 4,814 |
| 39,570 |
| 10,932 |
| 17,225 |
| 6,168 |
| 5,245 |
|
Solar asset financing obligations (1) | 18,866 |
| 2,719 |
| 5,438 |
| 5,438 |
| 5,271 |
| 79,410 |
| 9,794 |
| 15,633 |
| 15,680 |
| 38,303 |
|
Operating leases (1) | 51,073 |
| 2,387 |
| 5,239 |
| 5,156 |
| 38,291 |
| 67,740 |
| 3,217 |
| 7,445 |
| 7,028 |
| 50,050 |
|
| Short-term debt | 266,000 |
| 266,000 |
| — |
| — |
| — |
| 151,950 |
| 151,950 |
| — |
| — |
| — |
|
New Jersey Clean Energy Program (1) | 14,202 |
| 14,202 |
| — |
| — |
| — |
| 14,052 |
| 14,052 |
| — |
| — |
| — |
|
| Construction obligations | 23,120 |
| 23,120 |
| — |
| — |
| — |
| 23,903 |
| 23,903 |
| — |
| — |
| — |
|
Remediation expenditures (2) | 149,000 |
| 19,300 |
| 37,000 |
| 27,600 |
| 65,100 |
| 130,800 |
| 19,800 |
| 28,800 |
| 28,800 |
| 53,400 |
|
| Natural gas supply purchase obligations-NJNG | 94,720 |
| 51,050 |
| 43,670 |
| — |
| — |
| 240,731 |
| 65,737 |
| 71,465 |
| 67,767 |
| 35,762 |
|
| Demand fee commitments-NJNG | 1,187,054 |
| 98,586 |
| 244,959 |
| 197,125 |
| 646,384 |
| 1,128,331 |
| 111,993 |
| 223,991 |
| 200,015 |
| 592,332 |
|
| Natural gas supply purchase obligations-Energy Services | 445,066 |
| 296,491 |
| 137,087 |
| 11,488 |
| — |
| 467,369 |
| 428,015 |
| 39,354 |
| — |
| — |
|
| Demand fee commitments-Energy Services | 259,195 |
| 88,786 |
| 92,204 |
| 56,148 |
| 22,057 |
| 257,666 |
| 83,864 |
| 111,403 |
| 56,257 |
| 6,142 |
|
| Total contractual cash obligations | $ | 4,101,176 |
| $ | 1,059,846 |
| $ | 741,593 |
| $ | 417,029 |
| $ | 1,882,708 |
| $ | 4,384,867 |
| $ | 1,063,029 |
| $ | 589,654 |
| $ | 554,187 |
| $ | 2,177,997 |
|
| |
| (1) | These obligations include an interest component, as defined under the related governing agreements or in accordance with the applicable tax statute. |
| |
| (2) | Expenditures are estimated, seeestimated. See Note 14.13. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements. |
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
We made a discretionary contribution of $30 million during the first quarter of fiscal 2016, to improve the funded status of the pension plans based on then currentthen-current actuarial assumptions, which included the adoption of the most recent mortality table. We do not expect to be required to make additional contributions to fund the pension plans over the following two fiscal years based on current actuarial assumptions,assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents. In addition, as in the past, we may elect to make discretionary contributions to the plans in excess of the minimum required amount. We made no discretionary contributions to the pension plans in fiscal 2018 and 2017. There are no Federalfederal requirements to pre-fund OPEB benefits. However, we are required to fund certain amounts due to regulatory agreements with the BPU. We anticipate that the annual funding level toof the OPEB plans will range from $4$5 million to $7$8 million annually over each of the next five years. Additional contributions may vary based on market conditions and various assumptions.
As of September 30, 2017,2018, there were NJR guarantees covering approximately $331.4$418.1 million of natural gas purchases and Energy Services demand fee commitments not yet reflected in accounts payable on the Consolidated Balance Sheets.
NJNG’sNJNG incurs significant capital expenditures consisting primarily of its construction program to support customer growth, maintenance of its distribution and transmission system and replacement needed under pipeline safety regulations. During fiscal 2017,2018, committed and spent capital expenditures totaled $177.6$241.3 million. In fiscal 20182019 and 2019,2020, NJNG’s total capital expenditures are projected to be $399.8$475.2 million and $235$343.2 million, respectively.
In November 2012, NJNG filed a petition with the BPU requesting deferral accounting for incurred uninsured incremental O&M costs associated with Superstorm Sandy. As of September 30, 2017,2018, NJNG deferred $13$10.9 million in regulatory assets that was approved for recovery through NJNG’s new base rates, effective October 2016.
NJNG expects to fund its obligations with a combination of cash flow from operations, cash on hand, issuance of commercial paper, available capacity under its revolving credit facility and the issuance of long-term debt.
As of September 30, 2017,2018, NJNG’s future MGP expenditures are estimated to be $149$130.8 million. For a more detailed description of MGP see Note 14.13. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Estimated capital expenditures are reviewed on a regular basis and may vary based on the ongoing effects of regulatory constraints, environmental regulations, unforeseen events and the ability to access capital.
Clean Energy Ventures’sVentures’ expenditures include clean energy projects that support our goal to promote renewable energy. Accordingly, Clean Energy Ventures enters into agreements to install solar equipment involving both residential and commercial projects. During fiscal 2017,2018, capital expenditures related to the purchase and installation of the solar equipment were $115.1$120.1 million. An additional $13.3In fiscal 2019, Clean Energy Ventures plans to spend an estimated $134.4 million has been committed or accrued foron commercial and residential solar projects to be placed into service during fiscal 2018 and beyond.projects. We estimate the value of solar-related capital expendituresprojects placed in service in fiscal 20182019 to be between $132$156 million and $140$166 million.
During the first quarter of fiscal 2017, Clean Energy Ventures completed construction of a $89 million, 39.9 MW onshore wind project in Somerset County, Pennsylvania.
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.
During fiscal 2017,2018, Midstream had a total of $27.1$16.2 million of expenditures related to our investment in the PennEast pipeline project. Expenditures in the PennEast pipeline are expected to total between $220$13 million and $280$15 million. Capital expenditures related to our Midstream investment in the Adelphia project were $16.7 million, which includes the initial payment of $10 million towards the purchase price. Including the purchase price of $166 million and assuming the transaction closes, we estimate expenditures related to the Adelphia project to be between $306 million and $310 million.
Energy Services does not currently anticipate any significant capital expenditures in fiscal 20182019 and 2019.2020.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
Off-Balance-Sheet Arrangements
Our off-balance-sheet arrangements consist of guarantees covering approximately $331.4$418.1 million of natural gas purchases, SREC sales and demand fee commitments see Note 14. Commitments and Contingent Liabilities,, and eight outstanding letters of credit totaling $14.1$15.6 million, as noted above, seepreviously mentioned. See Note 9.13. Commitments and Contingent Liabilities and Note 8. Debt. for more information.
Cash Flows
Operating Activities
Cash flows from operating activities during fiscal 2017,2018 totaled $248$398.3 million compared with $142.6$248 million during fiscal 2016.2017. 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 gas costs;
•changes in contractual assets utilizedused 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.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
The increase of $150.2 million in operating cash flows during fiscal 2018, compared with fiscal 2017, was due primarily to increased earnings at Energy Services and decreased working capital requirements as mentioned above.
The increase of $105.4 million in operating cash flows during fiscal 2017, compared with fiscal 2016, was due primarily to increased base rates, increased working capital due primarily to lower broker margin requirements, a decrease in bill credits issued and a discretionary contribution of $30 million to our pension plan during fiscal 2016 that did not recur in fiscal 2017.
Investing Activities
Cash flows used in investing activities totaled $373.1 million during fiscal 2018, compared with $390.7 million during fiscal 2017. The decrease of $248.3$17.6 million is due primarily to our fiscal 2017 acquisition of Talen’s retail and wholesale energy contract assets totaling $55.7 million that did not recur in operatingfiscal 2018, cash flows during fiscal 2016, compared with fiscal 2015, was impacted byproceeds of $27.9 million from the sale of Two Dot wind farm and NJRRS and a decrease in market volatility related to the warm winter weather primarily across the eastern United States, which contributed to a lower profitabilitysolar capital expenditures and decrease in working capital at Energy Services, including a reduction in natural gas sold outPennEast investment of storage$26 million and $10.9 million, respectively, partially offset by an increase in broker margin due to decreasesexpenditures of $78.3 million for our utility plant at NJNG, an advance payment of $10 million for the IEC acquisition and cash proceeds in the fair valuefiscal 2017 of derivatives and higher initial margin requirements. Also contributing to the decrease$9.4 million from a sale of a building that did not recur in operating cash flows were bill credits of $61.6 million issued to NJNG’s customers during fiscal 2016, for overrecovered gas costs and a discretionary contribution of $30 million to our pension plan during fiscal 2016.
Investing Activities2018.
Cash flows used in investing activities totaled $390.7 million during fiscal 2017, compared with $363.2 million during fiscal 2016. The increase of $27.5 million was due primarily to our acquisition of Talen'sTalen’s retail and wholesale energy contract assets totaling $55.7 million and increased investments in solar projects and PennEast of $39.4 million and $15.9 million, respectively, partially offset by a decrease in capital expenditures in wind investments of $39.1 million and utility plant of $32 million, along with net proceeds of $9.4 million from the sale of an office building and $6.6 million from the sale of available for sale securities.
Cash flows used in investing activities totaled $363.2 million during fiscal 2016, compared with $321.7 million during fiscal 2015. The increase of $41.5 million was due primarily to an increase in utility plant of $36.3 million and an increase in capital expenditures at Clean Energy Ventures of $14.5 million related to solar projects. We also contributed an additional $5.4 million for the investment in PennEast during fiscal 2016. The increases were partially offset by a decrease of $16.5 million in capital expenditures related to solar projects at Clean Energy Ventures.New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
NJNG’s capital expenditures result primarily from the need for services, mains and meters to support its continued customer growth, mandated pipeline safety rulemaking, general system improvements and approved infrastructure programs. NJNG’s capital expenditures, including cost of removal, totaled $176.2$254.5 million and $205.1$176.2 million in fiscal 20172018 and fiscal 2016,2017, respectively.
The Company enters into various agreements to install, own and operate solar equipment, including both residential and commercial projects and onshore wind projects. During fiscal 20172018 and fiscal 2016,2017, capital expenditures on these projects totaled $123.4 million and $149.4 million, and $149.1 million, respectively.
Home Services and Other capital expenditures in past years were made primarily in connection with investments made to preserve the value of real estate holdings. On March 8, 2017, CR&R sold a 56,400 square foot office building on five acres of land located in Monmouth County for $9.4 million, net of closing costs, generating a pre-tax gain of $1.9 million.
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 gas management and marketing activities at Energy Services and clean energy investments at Clean Energy Ventures.
Cash flows used in financing activities during fiscal 2018 totaled $26 million, compared with cash flows from financing activities of $107.3 million during fiscal 2017. The increase of $133.3 million is due primarily to increased payments of short-term borrowings at NJR and long-term borrowings at NJNG, partially offset by an additional $125 million in long-term borrowings at NJNG, proceeds from the issuance of stock through our waiver discount plan and increased proceeds from solar sale-leasebacks.
Cash flows from financing activities during fiscal 2017 totaled $107.3 million, compared with cash flows used in financing activities of $253.2 million during fiscal 2016. The decreaseincrease of $145.9 million iswas due primarily to the issuance of $100 million of long-term debt compared with $275 million in the previous year, the purchase of three FMBs in lieu of redemption totaling $35.8 million at NJNG and $50 million redemption of long-term debt at NJR, partially offset by an increase in short-term borrowings at NJR and proceeds of $32.9 million from the solar sale-leasebacks at Clean Energy Ventures.
Cash flows used in financing activities during fiscal 2016 totaled $253.2 million, compared with $66.4 million during fiscal 2015. The decrease of $319.6 million was due primarily to increased short-term borrowings at NJR. This was partially offset by the issuance of $100 million in long-term debt for NJR during fiscal 2015, along with a decrease of $25 million in long-term debt at NJNG, which issued $125 million during fiscal 2016, compared with $150 million during fiscal 2015. There was also a decrease in proceeds from the issuance of common stock when compared with fiscal 2015, during which 688,000 new shares were issued through the waiver discount feature of the DRP.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
NJNG received $7.8 million, $9.6 million $7.1 million and $7.2$7.1 million for fiscal 2018, 2017 2016 and 2015,2016, respectively, in connection with the sale-leaseback of its natural gas meters. During fiscal 2018, 2017, 2016 and 2015,2016, NJNG exercised early purchase options with respect to meter leases by making final principal payments of $2.4$2.2 million,, $1.9 $2.4 million and $768,000,$1.9 million, respectively. NJNG continues to evaluate the natural gas meter sale-leaseback program based on current market conditions.
Credit Ratings
The table below summarizes NJNG’s current credit ratings issued by two rating entities, S&P and Moody’s, as of September 30, 2017:2018:
|
| | |
| | S&P | Moody’s |
| Corporate Rating | ABBB+ | N/A |
| Commercial Paper | A-1A-2 | P-1 |
| Senior Secured | A+A | Aa2 |
| Ratings Outlook | StableNegative | StableNegative |
On January 19, 2018, Moody’s revised NJNG's rating outlook from stable to negative along with 23 other utility companies. This change reflects Moody’s view that tax reform is credit-negative for regulated utilities due to reduced cash collected from customers, while the loss of bonus depreciation reduces tax deferrals. The negative outlook also considers the uncertainty over timing of any regulatory actions or changes to corporate finance polices made to offset the financial impact. This action does not currently affect any of NJNG’s long-term borrowing rates. These ratings were reaffirmed by S&P on October 26, 2017, and by Moody’s on October 4, 2017. February 2, 2018.
On August 13, 2018, S&P lowered NJNG’s credit rating to BBB+ from A, senior secured debt rating to A from A+ and short-term and Commercial Paper rating to A-2 from A-1, and also reaffirmed NJNG's rating outlook that was changed on May 23, 2018, from stable to negative. S&P's negative outlook reflects NJNG's rising capital spending program, impacts of corporate tax reform and modestly higher use of debt leverage to fund NJR's growing midstream business. This action does not currently affect any of NJNG’s long-term borrowing rates or financial covenants. The impact on NJNG’s short-term borrowing rates was immaterial.
NJNG’s S&P and Moody’s ratings are investment-grade ratings. NJR is not a rated entity.
New Jersey Resources Corporation
Part II
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (Continued)
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, CME, 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 deregulated 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 three of our reporting segments. NJNG is a regulated utility that uses futures, options and swaps to economically hedge against price fluctuations, and its recovery of natural gas costs is governed by the BPU. Energy Services uses futures, options, swaps and physical contracts to economically hedge purchases and sales of natural gas. Financial derivatives have historically been transacted on an exchange and cleared through an FCM, thus requiring daily cash margining for a majority of Energy Services’ and NJNG’s positions. As a result of the Dodd-Frank Act, certain Energy Services and NJNG transactions that were previously executed in the over-the-counter markets are now cleared through an FCM, resulting in increased margin requirements. The related cash flow impact from the increased
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
requirements is expected to be minimal. Non-financial (i.e., physical) derivatives utilized by us have received statutory exclusion from similar Dodd-Frank provisions due to the element of physical settlement.
The following table reflects the changes in the fair market value of financial derivatives related to natural gas purchases and sales from September 30, 20162017 to September 30, 2017:2018:
| | | | Balance | Increase | Less | Balance | Balance | Increase | Less | Balance |
| (Thousands) | September 30,
2016 | (Decrease) in Fair Market Value | Amounts Settled | September 30,
2017 | September 30,
2017 | (Decrease) in Fair Market Value | Amounts Settled | September 30,
2018 |
| NJNG | | $ | (2,485 | ) | | $ | 5,288 |
| | $ | 3,952 |
| | $ | (1,149 | ) | |
| Natural Gas Distribution | | | $ | (1,149 | ) | | $ | (25 | ) | | $ | (1,268 | ) | | $ | 94 |
|
| Energy Services | | (21,742 | ) | | 19,703 |
| | 3,513 |
| | (5,552 | ) | | (5,552 | ) | | (22,571 | ) | (1) | (14,198 | ) | | (13,925 | ) |
| Total | | $ | (24,227 | ) | | $ | 24,991 |
| | $ | 7,465 |
| | $ | (6,701 | ) | | $ | (6,701 | ) | | $ | (22,596 | ) | | $ | (15,466 | ) | | $ | (13,831 | ) |
(1) Includes the addition of $9.5 million related to the fair value of the derivative instrument acquired through the disposition of NJRRS.
There were no changes in methods of valuations during the year ended September 30, 2017.2018.
The following is a summary of fair market value of financial derivatives as of September 30, 2017,2018, excluding foreign exchange contracts discussed below, by method of valuation and by maturity for each fiscal year period:
| | | (Thousands) | 2018 | 2019 | 2020 - 2022 | After 2022 | Total Fair Value | 2019 | 2020 | 2021 - 2023 | After 2023 | Total Fair Value |
| Price based on NYMEX/CME | $ | — |
| $ | — |
| | $ | — |
| | $ | — |
| | $ | — |
| $ | 4,425 |
| $ | 1,880 |
| | $ | 721 |
| | $ | — |
| | $ | 7,026 |
|
| Price based on ICE | (6,115 | ) | (736 | ) | | 147 |
| | 3 |
| | (6,701 | ) | (13,371 | ) | (7,263 | ) | | (223 | ) | | — |
| | (20,857 | ) |
| Total | $ | (6,115 | ) | $ | (736 | ) | | $ | 147 |
| | $ | 3 |
| | $ | (6,701 | ) | $ | (8,946 | ) | $ | (5,383 | ) | | $ | 498 |
| | $ | — |
| | $ | (13,831 | ) |
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
The following is a summary of financial derivatives by type at September 30, 2017:2018:
| | | | | Volume Bcf | Price per MMBtu (1) | Amounts included in Derivatives (Thousands) | | Volume Bcf | Price per MMBtu (1) | Amounts included in Derivatives (Thousands) |
| NJNG | Futures | 18.2 |
| $1.12-$3.33 | | $ | (1,149 | ) | |
| Natural Gas Distribution | | Futures | 27.9 |
| 2.28 - 3.05 | | $ | 94 |
|
| Energy Services | Futures | (16.4 | ) | $0.90-$5.30 | | (5,552 | ) | Futures | (7.0 | ) | $1.48 - $5.93 | | (20,949 | ) |
| | Options | — |
|
| |
| Swaps | (17.3 | ) | 2.72 - 3.46 | | 7,024 |
|
| Total | | | | $ | (6,701 | ) | | | | $ | (13,831 | ) |
| |
| (1) | Million British thermal unit |
The following table reflects the changes in the fair market value of physical commodity contracts from September 30, 20162017 to September 30, 2017:2018:
| | | | Balance | Increase | Less | Balance | Balance | Increase | Less | Balance |
| (Thousands) | September 30,
2016 | (Decrease) in Fair Market Value | Amounts Settled | September 30,
2017 | September 30,
2017 | (Decrease) in Fair Market Value | Amounts Settled | September 30,
2018 |
| NJNG - Prices based on other external data | | $ | (919 | ) | | (10,096 | ) | | (11,094 | ) | | $ | 79 |
| |
| Natural Gas Distribution - Prices based on other external data | | | $ | 79 |
| | 4,587 |
| | 4,773 |
| | $ | (107 | ) |
| Energy Services - Prices based on other external data | | (2,891 | ) | | (11,765 | ) | | (11,072 | ) | | (3,584 | ) | | (3,584 | ) | | 277 |
| | 14,570 |
| | (17,877 | ) |
| Total | | $ | (3,810 | ) | | (21,861 | ) | | (22,166 | ) | | $ | (3,505 | ) | | $ | (3,505 | ) | | 4,864 |
| | 19,343 |
| | $ | (17,984 | ) |
The following table reflects the changes in the fair market value of interest rate contracts from September 30, 20162017 to September 30, 2017:2018:
|
| | | | | | | | | | | | | | |
| | Balance | Increase | Less | Balance |
| (Thousands) | September 30, 2016 | (Decrease) in Fair Market Value | Amounts Settled | September 30, 2017 |
| NJNG - Prices based on other external data | | $ | (23,073 | ) | | 14,606 |
| | — |
| | $ | (8,467 | ) |
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
|
| | | | | | | | | | | | | | |
| | Balance | Increase | Less | Balance |
| (Thousands) | September 30, 2017 | (Decrease) in Fair Market Value | Amounts Settled | September 30, 2018 |
| Natural Gas Distribution - Prices based on other external data | | $ | (8,467 | ) | | 5,892 |
| | (2,575 | ) | | $ | — |
|
| Home Services and Other - Prices based on other external data | | — |
| | 335 |
| | (46 | ) | | 381 |
|
| Total | | $ | (8,467 | ) | | 6,227 |
| | (2,621 | ) | | $ | 381 |
|
Foreign Currency Market Risks
The following table reflects the changes in the fair market value of financial derivatives related to foreign currency hedges from September 30, 20162017 to September 30, 2017:2018:
| | | | Balance | Increase | Less | Balance | Balance | Increase | Less | Balance |
| (Thousands) | September 30,
2016 | (Decrease) in Fair Market Value | Amounts Settled | September 30,
2017 | September 30,
2017 | (Decrease) in Fair Market Value | Amounts Settled | September 30,
2018 |
| Energy Services | | $ | (31 | ) | | 43 |
| | (32 | ) | | $ | 44 |
| | $ | 44 |
| | (379 | ) | | (91 | ) | | $ | (244 | ) |
There were no changes in methods of valuations during the fiscal year ended September 30, 2017.2018.
The following is a summary of fair market value of financial derivatives related to foreign currency hedges atas of September 30, 2017,2018, by method of valuation and by maturity for each fiscal year period:
| | | (Thousands) | 2018 | 2019 | 2020 - 2022 | | After 2022 | | Total
Fair Value | 2019 | 2020 | 2021 - 2023 | | After 2023 | | Total
Fair Value |
| Prices based on other external data | $ | 40 |
| 4 |
| | — |
| | — |
| | $ | 44 |
| $ | (126 | ) | (84 | ) | | (34 | ) | | — |
| | $ | (244 | ) |
Our market price risk is predominately related to changes in the price of natural gas at the Henry Hub, which is the delivery point for the NYMEX natural gas futures contracts. As the fair value of futures and fixed price swaps is linked to this location, the price sensitivity analysis has been prepared for all open Henry Hub natural gas futures and fixed swap positions. Based on this, an illustrative 10 percent movement in the natural gas futures contract price, for example, increases (decreases) the reported
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
derivative fair value of all open, unadjusted Henry Hub natural gas futures and fixed swap positions by approximately $17.7$10.8 million. This analysis does not include potential changes to reported credit adjustments embedded in the $2.1$5.1 million reported fair value.
| | | Derivative Fair Value Sensitivity Analysis | | |
| (Thousands) | Henry Hub Futures and Fixed Price Swaps | Henry Hub Futures and Fixed Price Swaps |
| Percent increase in NYMEX natural gas futures prices | 0% | 5% | 10% | 15% | 20% | 0% | 5% | 10% | 15% | 20% |
| Estimated change in derivative fair value | $ | — |
| $ | (8,844 | ) | $ | (17,689 | ) | $ | (26,534 | ) | $ | (35,378 | ) | $ | — |
| $ | (5,414 | ) | $ | (10,829 | ) | $ | (16,243 | ) | $ | (21,657 | ) |
| Ending derivative fair value | $ | 2,110 |
| $ | (6,734 | ) | $ | (15,579 | ) | $ | (24,424 | ) | $ | (33,268 | ) | $ | 5,081 |
| $ | (333 | ) | $ | (5,748 | ) | $ | (11,162 | ) | $ | (16,576 | ) |
| Percent decrease in NYMEX natural gas futures prices | 0% | (5)% | (10)% | (15)% | (20)% | 0% | (5)% | (10)% | (15)% | (20)% |
| Estimated change in derivative fair value | $ | — |
| $ | 8,844 |
| $ | 17,689 |
| $ | 26,534 |
| $ | 35,378 |
| $ | — |
| $ | 5,414 |
| $ | 10,829 |
| $ | 16,243 |
| $ | 21,657 |
|
| Ending derivative fair value | $ | 2,110 |
| $ | 10,954 |
| $ | 19,799 |
| $ | 28,644 |
| $ | 37,488 |
| $ | 5,081 |
| $ | 10,495 |
| $ | 15,910 |
| $ | 21,324 |
| $ | 26,738 |
|
Wholesale Credit Risk
NJNGNatural Gas Distribution and Energy Services engage in wholesale marketing activities and Clean Energy Ventures engages in SREC sales. We monitor and manage the credit risk of our operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of prospective counterparties’ financial statements and/or credit ratings, daily monitoring of counterparties’ credit limits, daily communication with traders regarding credit status and the use of credit mitigation measures, such as minimum margin requirements, collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit.
Our Risk Management Committee continuously monitors our credit risk management policies and procedures and is composed of individuals from NJR-affiliated companies. The Risk Management Committee meets at least once a month and, among other things, evaluates the effectiveness of existing credit policies and procedures, reviews material transactions and discusses emerging issues.
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
The following is a summary of gross and net credit exposures, grouped by investment and non-investment grade counterparties, as of September 30, 2017.2018. Gross credit exposure 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. Net credit exposure is defined as gross credit exposure reduced by collateral received from counterparties and/or payables, where netting agreements exist. The amounts presented below exclude accounts receivable for NJNG retail natural gas sales and services.
Energy Services’ and Clean Energy Ventures’ counterparty credit exposure as of September 30, 2017,2018, is as follows:
| | | (Thousands) | Gross Credit Exposure | Net Credit Exposure | Gross Credit Exposure | Net Credit Exposure |
| Investment grade | | $ | 133,431 |
| | $ | 100,703 |
| | $ | 175,064 |
| | $ | 143,438 |
|
| Noninvestment grade | | 16,725 |
| | 9,483 |
| | 43,419 |
| | 10,648 |
|
| Internally-rated investment grade | | 16,282 |
| | 14,069 |
| | 30,693 |
| | 26,189 |
|
| Internally-rated noninvestment grade | | 48,960 |
| | 4,886 |
| | 15,566 |
| | 3,789 |
|
| Total | | $ | 215,398 |
| | $ | 129,141 |
| | $ | 264,742 |
| | $ | 184,064 |
|
NJNG’s counterparty credit exposure as of September 30, 2017,2018, is as follows:
| | | (Thousands) | Gross Credit Exposure | Net Credit Exposure | Gross Credit Exposure | Net Credit Exposure |
| Investment grade | | $ | 3,373 |
| | $ | 2,211 |
| | $ | 4,918 |
| | $ | 4,121 |
|
| Noninvestment grade | | 164 |
| | — |
| | 67 |
| | — |
|
| Internally-rated investment grade | | 96 |
| | 83 |
| | 93 |
| | 43 |
|
| Internally-rated noninvestment grade | | 19,538 |
| | 13,452 |
| | 10,184 |
| | — |
|
| Total | | $ | 23,171 |
| | $ | 15,746 |
| | $ | 15,262 |
| | $ | 4,164 |
|
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
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.
Retail Credit Risk
NJR is exposed to retail credit risk through NJRRS' natural gas retail business, which serves customers in Pennsylvania, New Jersey, Delaware and Maryland. Retail credit risk could result in losses if a customer failed to pay for natural gas that has been delivered.
NJR manages retail credit risk through the use of established credit policies that include customer credit evaluation software, monitoring of the portfolio and the use of credit mitigation measures such as deposits, letters of credit or prepayment arrangements, where applicable.
As of September 30, 2017, our retail customer credit exposure was diversified across many customers and various industries, as well as government entities. Credit exposure for NJRRS at September 30, 2017, was $25.4 million. Non-performance by any of these customers would not be material to our financial position, results of operations or cash flows.
New Jersey Resources Corporation
Part II
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)
Effects of Interest Rate and Foreign Currency Rate Fluctuations
We are also exposed to changes in interest rates on our debt hedges, variable rate debt and changes in foreign currency rates for our business conducted in Canada using Canadian dollars. We do not believe an immediate 10 percent increase or decrease in interest rates or foreign currency rates would have a material effect on our operating results or cash flows.
As of September 30, 2017,2018, NJNG is obligated to make principal and interest payments under a loan agreement securing $97 million of variable rate debt issued by the EDA. The bonds are in a LIBOR-based monthly interest rate mode and will accrue interest for five years at a variable rate determined monthly, which was initially calculated at .55 percent plus 70 percent of one-month LIBOR. As of September 30, 2017,2018, the EDA Bonds had a weighted average interest rate of 1.421.78 percent. The EDA Bonds are subject to changes in market conditions for tax-exempt bonds and there can be no assurance that the interest rate will remain stable and not increase significantly due to market conditions, which could adversely affect NJNG’s borrowing costs. A 100 basis point change in the EDA Bonds’ average interest rate would have caused a change in interest expense for these variable rate bonds by approximately $903,000$922,000 during fiscal 2017.2018.
As of September 30, 2017,2018, NJR is obligated to make principal and interest payments under a loan agreement securing $100 million of variable rate debt dated August 18, 2017. The term loan will accrueaccrues interest at a variable rate determined monthly, which is LIBOR plus 70 basis points. The weighted averageOn January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on the on thevariable rate term loan, as of September 30, 2017, was 1.95 percent. A 100 basis point change inwhich fixed the average interest rate would have caused a change in interest expense for this variable rate debt by approximately $990,000 during fiscal 2017.at 2.84 percent.
For more information regarding the interest rate risk related to our short-term debt, please see the Liquidity and Capital Resources - Debt section of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Effects of Inflation
Although inflation rates have been relatively low to moderate in recent years, including the three most recent fiscal years, any change in price levels has an effect on operating results due to the capital-intensive and regulated nature of our utility subsidiary. We attempt to minimize the effects of inflation through cost control, productivity improvements and regulatory actions, when appropriate.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
Management of New Jersey Resources Corporation is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) and 15d-15(f) of the Securities and Exchange Act of 1934, as amended. The Company’s internal control over financial reporting is a process designed to provide reasonable assurance to the Company’s Management and Board of Directors regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles and includes policies and procedures that:
pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company;
provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and
provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the Company’s assets that could have a material effect on the financial statements.
Under the supervision and with the participation of the Company’s management, including its principal executive officer and principal financial officer, management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting as of September 30, 20172018. 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, 20172018, the Company’s internal control over financial reporting was effective to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the Unites States of America.
The conclusion of the Company’s principal executive officer and principal financial officer is based on the recognition that there are inherent limitations in all systems of internal control over financial reporting. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements, errors or fraud. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
The Company’s independent registered public accounting firm, Deloitte & Touche LLP, has issued its report on the effectiveness of the Company’s internal control over financial reporting as of September 30, 20172018, which appears herein.
November 21, 201720, 2018
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the shareholders and the Board of Directors and Stockholders of
New Jersey Resources CorporationCorporation:
Wall, New Jersey
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, 20172018 and 20162017, and the related consolidated statements of operations, comprehensive income, common stock equity, and cash flows, for each of the three years in the period ended September 30, 2017. Our audits also included2018, and the related notes and the financial statement schedule listed in the Index at Item 15. These financial statements and financial statement schedule are15 (collectively referred to as the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements and financial statement schedule based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States)"financial statements"). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidatedthe financial statements present fairly, in all material respects, the financial position of the Company as of September 30, 20172018 and 2016,2017, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2017,2018, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’sCompany's internal control over financial reporting as of September 30, 2017,2018, based on the 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, 201720, 2018, expressed an unqualified opinion on the Company’sCompany'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.
/s/ DELOITTE & TOUCHE LLP
Parsippany, New Jersey
November 20, 2018
November 21, 2017We have served as the Company's auditor since 1951.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the shareholders and the Board of Directors and Stockholders of
New Jersey Resources CorporationCorporation:
Wall, New Jersey
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, 2017,2018, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of September 30, 2018, 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 and financial statement schedule as of and for the year ended September 30, 2018, of the Company and our report dated November 20, 2018, expressed an unqualified opinion on those financial statements and financial statement schedule.
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’sManagement'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 Public Company Accounting Oversight Board (United States).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 by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel 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 theits inherent limitations, of internal control over financial reporting including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be preventedprevent or detected on a timely basis.detect misstatements. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of September 30, 2017, based on the criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedule as of and for the year ended September 30, 2017 of the Company and our report dated November 21, 2017 expressed an unqualified opinion on those financial statements and financial statement schedule.
/s/ DELOITTE & TOUCHE LLP
Parsippany, New Jersey
November 21, 201720, 2018
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CONSOLIDATED STATEMENTS OF OPERATIONS
| | | (Thousands, except per share data) | | | | |
| Fiscal years ended September 30, | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| OPERATING REVENUES | | |
| Utility | $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Nonutility | 1,572,980 |
| 1,286,559 |
| 1,952,017 |
| 2,183,244 |
| 1,572,980 |
| 1,286,559 |
|
| Total operating revenues | 2,268,617 |
| 1,880,905 |
| 2,733,987 |
| 2,915,109 |
| 2,268,617 |
| 1,880,905 |
|
| OPERATING EXPENSES | | | | |
| Gas purchases: | | |
| Utility | 258,687 |
| 205,034 |
| 304,953 |
| 276,005 |
| 258,687 |
| 205,034 |
|
| Nonutility | 1,436,740 |
| 1,139,301 |
| 1,767,841 |
| 1,990,832 |
| 1,436,740 |
| 1,139,301 |
|
| Related parties | 8,340 |
| 8,351 |
| 12,851 |
| 8,505 |
| 8,340 |
| 8,351 |
|
| Operation and maintenance | 226,356 |
| 208,421 |
| 209,453 |
| 266,919 |
| 226,356 |
| 208,421 |
|
| Regulatory rider expenses | 40,243 |
| 39,300 |
| 75,779 |
| 38,969 |
| 40,243 |
| 39,300 |
|
| Depreciation and amortization | 81,841 |
| 72,748 |
| 61,399 |
| 85,701 |
| 81,841 |
| 72,748 |
|
| Energy and other taxes | 49,366 |
| 40,215 |
| 53,260 |
| 52,102 |
| 49,366 |
| 40,215 |
|
| Total operating expenses | 2,101,573 |
| 1,713,370 |
| 2,485,536 |
| 2,719,033 |
| 2,101,573 |
| 1,713,370 |
|
| OPERATING INCOME | 167,044 |
| 167,535 |
| 248,451 |
| 196,076 |
| 167,044 |
| 167,535 |
|
| Other income, net | 14,437 |
| 9,196 |
| 6,545 |
| 16,853 |
| 14,437 |
| 9,196 |
|
| Interest expense, net of capitalized interest | 44,886 |
| 31,044 |
| 27,721 |
| 46,286 |
| 44,886 |
| 31,044 |
|
| INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES | 136,595 |
| 145,687 |
| 227,275 |
| 166,643 |
| 136,595 |
| 145,687 |
|
| Income tax provision | 18,343 |
| 23,530 |
| 59,724 |
| |
| Income tax (benefit) provision | | (53,785 | ) | 18,343 |
| 23,530 |
|
| Equity in earnings of affiliates | 13,813 |
| 9,515 |
| 13,409 |
| 13,008 |
| 13,813 |
| 9,515 |
|
| NET INCOME | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| | | |
| EARNINGS PER COMMON SHARE | | |
| Basic | $1.53 | $1.53 | $2.12 | $2.66 | $1.53 |
| Diluted | $1.52 | $1.52 | $2.10 | $2.64 | $1.52 |
| DIVIDENDS DECLARED PER COMMON SHARE | $1.0375 | $0.9750 | $0.9150 | |
| WEIGHTED AVERAGE SHARES OUTSTANDING | | |
| Basic | 86,321 |
| 85,884 |
| 85,186 |
| 87,689 |
| 86,321 |
| 85,884 |
|
| Diluted | 87,144 |
| 86,731 |
| 86,265 |
| 88,315 |
| 87,144 |
| 86,731 |
|
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
| | | (Thousands) | | |
| Fiscal years ended September 30, | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Net income | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| Other comprehensive income, net of tax: | | |
Unrealized gain (loss) on available for sale securities, net of tax of $(4,401), $1,499, and $(1,135), respectively (1) | 6,846 |
| (2,187 | ) | 1,603 |
| |
| Net unrealized gain on derivatives, net of tax of $0, $0 and $(56), respectively | — |
| — |
| 93 |
| |
| Adjustment to postemployment benefit obligation, net of tax of $(3,487), $2,466 and $3,688 respectively | 5,053 |
| (3,574 | ) | (5,496 | ) | |
| Other comprehensive income (loss) | 11,899 |
| (5,761 | ) | (3,800 | ) | |
| Unrealized (loss) gain on available for sale securities, net of tax of 6,973, $(4,401) and $1,499, respectively | | (19,245 | ) | 6,846 |
| (2,187 | ) |
| Reclassifications of losses to net income on available for sale securities, net of tax of $(858), $0 and $0, respectively | | 11,647 |
| — |
| — |
|
| Adjustment to postemployment benefit obligation, net of tax of $(573), $(3,487) and $2,466, respectively | | 1,520 |
| 5,053 |
| (3,574 | ) |
| Other comprehensive (loss) income | | (6,078 | ) | 11,899 |
| (5,761 | ) |
| Comprehensive income | $ | 143,964 |
| $ | 125,911 |
| $ | 177,160 |
| $ | 227,358 |
| $ | 143,964 |
| $ | 125,911 |
|
| |
| (1) | Available for sale securities are included in other noncurrent assets on the Consolidated Balance Sheets. |
See Notes to Consolidated Financial Statements
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CONSOLIDATED STATEMENTS OF CASH FLOWS
| | | (Thousands) | | | | | | | | | | |
| Fiscal years ended September 30, | 2017 | | 2016 | | 2015 | 2018 | | 2017 | | 2016 |
| CASH FLOWS FROM OPERATING ACTIVITIES | | | | | | | | | | |
| Net income | $ | 132,065 |
| | $ | 131,672 |
| | $ | 180,960 |
| $ | 233,436 |
| | $ | 132,065 |
| | $ | 131,672 |
|
| Adjustments to reconcile net income to cash flows from operating activities | | | | | | | | | | |
| Unrealized (gain) loss on derivative instruments | (11,241 | ) | | 46,883 |
| | (38,681 | ) | |
| Gain on sale of property and available for sale securities, net | (7,287 | ) | | — |
| | — |
| |
| Unrealized loss (gain) on derivative instruments | | 26,770 |
| | (11,241 | ) | | 46,883 |
|
| Gain on sale of available for sale securities | | (5,332 | ) | | (7,287 | ) | | — |
|
| Gain on sale of businesses | | (4,663 | ) | | — |
| | — |
|
| Depreciation and amortization | 81,841 |
| | 72,748 |
| | 61,399 |
| 85,701 |
| | 81,841 |
| | 72,748 |
|
| Amortization of acquired wholesale energy contracts | | 18,222 |
| | 762 |
| | — |
|
| Allowance for equity used during construction | (3,867 | ) | | (4,375 | ) | | (3,825 | ) | (5,531 | ) | | (3,867 | ) | | (4,375 | ) |
| Allowance for bad debt expense | 2,023 |
| | 1,616 |
| | 2,859 |
| |
| Allowance for doubtful accounts | | 2,579 |
| | 2,023 |
| | 1,616 |
|
| Deferred income taxes | 41,442 |
| | 27,721 |
| | 45,934 |
| 15,590 |
| | 41,442 |
| | 27,721 |
|
| Deferred income tax benefit due to tax legislation | | (75,736 | ) | | — |
| | — |
|
| Manufactured gas plant remediation costs | (10,934 | ) | | (8,106 | ) | | (6,805 | ) | (16,171 | ) | | (10,934 | ) | | (8,106 | ) |
| Distributions received from equity investees, net of equity in earnings | (462 | ) | | 4,534 |
| | 6,663 |
| |
| Equity in earnings, net of distributions received from equity investees | | (1,725 | ) | | (462 | ) | | 4,534 |
|
| Cost of removal - asset retirement obligations | (484 | ) | | (403 | ) | | (1,034 | ) | (298 | ) | | (484 | ) | | (403 | ) |
| Contributions to postemployment benefit plans | (6,077 | ) | | (33,359 | ) | | (5,778 | ) | (6,359 | ) | | (6,077 | ) | | (33,359 | ) |
| Tax benefit of delivered shares from stock based compensation | 1,285 |
| | 1,755 |
| | 881 |
| 2,950 |
| | 1,285 |
| | 1,755 |
|
| Changes in: | | | | | | | | | | |
| Components of working capital | 17,081 |
| | (123,325 | ) | | 81,817 |
| 97,004 |
| | 17,081 |
| | (123,325 | ) |
| Other noncurrent assets | 14,740 |
| | 3,933 |
| | 38,716 |
| 17,860 |
| | 13,978 |
| | 3,933 |
|
| Other noncurrent liabilities | (2,079 | ) | | 21,336 |
| | 27,841 |
| 13,989 |
| | (2,079 | ) | | 21,336 |
|
| Cash flows from operating activities | 248,046 |
| | 142,630 |
| | 390,947 |
| 398,286 |
| | 248,046 |
| | 142,630 |
|
| CASH FLOWS (USED IN) INVESTING ACTIVITIES | | | | | | |
| CASH FLOWS USED IN INVESTING ACTIVITIES | | | | | | |
| Expenditures for: | | | | | | | | | | |
| Utility plant | (144,106 | ) | | (176,067 | ) | | (140,797 | ) | (206,880 | ) | | (144,106 | ) | | (176,067 | ) |
| Solar and wind equipment | (149,400 | ) | | (149,063 | ) | | (151,002 | ) | (123,421 | ) | | (149,400 | ) | | (149,063 | ) |
| Real estate properties and other | (2,434 | ) | | (1,896 | ) | | (209 | ) | |
| Midstream and other | | (6,644 | ) | | (2,434 | ) | | (1,896 | ) |
| Cost of removal | (32,143 | ) | | (29,066 | ) | | (28,078 | ) | (47,643 | ) | | (32,143 | ) | | (29,066 | ) |
| Acquisition of retail and wholesale energy contracts | (55,661 | ) | | — |
| | — |
| — |
| | (55,661 | ) | | — |
|
| Investments in equity investees | (27,070 | ) | | (11,176 | ) | | (5,780 | ) | (16,151 | ) | | (27,070 | ) | | (11,176 | ) |
| Distributions from equity investees in excess of equity in earnings | 2,749 |
| | 2,351 |
| | 2,620 |
| 3,117 |
| | 2,749 |
| | 2,351 |
|
| Withdrawal from (payment to) restricted cash construction fund | 1,322 |
| | 979 |
| | (1,499 | ) | |
| Proceeds from sale of investment | — |
| | — |
| | 3,016 |
| |
| Proceeds from sale of property | 9,443 |
| | 748 |
| | — |
| |
| Proceeds from sale of available for sale securities | 6,639 |
| | — |
| | — |
| |
| Cash flows (used in) investing activities | (390,661 | ) | | (363,190 | ) | | (321,729 | ) | |
| CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES | | | | | | |
| Cash paid related to acquisition | | (10,000 | ) | | — |
| | — |
|
| (Deposits to) withdrawal from restricted cash construction fund | | (9 | ) | | 1,322 |
| | 979 |
|
| Proceeds from sale of property, net of closing costs | | — |
| | 9,443 |
| | 748 |
|
| Proceeds from sale of businesses, net of closing costs | | 27,916 |
| | — |
| | — |
|
| Proceeds from sale of available for sale securities, net | | 6,616 |
| | 6,639 |
| | — |
|
| Cash flows used in investing activities | | (373,099 | ) | | (390,661 | ) | | (363,190 | ) |
| CASH FLOWS (USED IN) FROM FINANCING ACTIVITIES | | | | | | |
| Proceeds from long-term debt | 100,000 |
| | 275,000 |
| | 250,000 |
| 225,000 |
| | 100,000 |
| | 275,000 |
|
| Payments of long-term debt | (97,854 | ) | | (13,289 | ) | | (37,039 | ) | (165,486 | ) | | (97,854 | ) | | (13,289 | ) |
| Net proceeds from (payments of) short-term debt | 144,300 |
| | 55,350 |
| | (234,650 | ) | |
| (Payments of) proceeds from short-term debt, net | | (114,050 | ) | | 144,300 |
| | 55,350 |
|
| Proceeds from sale-leaseback transaction - solar | 32,901 |
| | — |
| | — |
| 71,538 |
| | 32,901 |
| | — |
|
| Proceeds from sale-leaseback transaction - other | 9,587 |
| | 7,107 |
| | 7,216 |
| |
| Proceeds from sale-leaseback transaction - gas meters | | 7,820 |
| | 9,587 |
| | 7,107 |
|
| Payments of common stock dividends | (87,988 | ) | | (82,445 | ) | | (76,532 | ) | (95,835 | ) | | (87,988 | ) | | (82,445 | ) |
Proceeds from waiver discount issuance of common stock
| | 41,677 |
| | — |
| | — |
|
| Proceeds from issuance of common stock | 17,492 |
| | 16,010 |
| | 37,299 |
| 17,136 |
| | 17,492 |
| | 16,010 |
|
| Purchases of treasury stock | (6,355 | ) | | (1,008 | ) | | (10,589 | ) | — |
| | (6,355 | ) | | (1,008 | ) |
| Tax withholding payments related to net settled stock compensation | (4,788 | ) | | (3,547 | ) | | (2,146 | ) | (13,755 | ) | | (4,788 | ) | | (3,547 | ) |
| Cash flows from (used in) financing activities | 107,295 |
| | 253,178 |
| | (66,441 | ) | |
| Cash flows (used in) from financing activities | | (25,955 | ) | | 107,295 |
| | 253,178 |
|
| Change in cash and cash equivalents | (35,320 | ) | | 32,618 |
| | 2,777 |
| (768 | ) | | (35,320 | ) | | 32,618 |
|
| Cash and cash equivalents at beginning of period | 37,546 |
| | 4,928 |
| | 2,151 |
| 2,226 |
| | 37,546 |
| | 4,928 |
|
| Cash and cash equivalents at end of period | $ | 2,226 |
| | $ | 37,546 |
| | $ | 4,928 |
| $ | 1,458 |
| | $ | 2,226 |
| | $ | 37,546 |
|
| CHANGES IN COMPONENTS OF WORKING CAPITAL | | | | | | | | | | |
| Receivables | $ | (56,974 | ) | | $ | 11,303 |
| | $ | 32,529 |
| $ | (7,524 | ) | | $ | (56,974 | ) | | $ | 11,303 |
|
| Inventories | 3,022 |
| | (45,986 | ) | | 114,638 |
| 15,464 |
| | 3,022 |
| | (45,986 | ) |
| Recovery of gas costs | (90 | ) | | (39,642 | ) | | 18,979 |
| 30,439 |
| | (90 | ) | | (39,642 | ) |
| Gas purchases payable | 20,663 |
| | (11,963 | ) | | (54,525 | ) | 51,187 |
| | 20,663 |
| | (11,963 | ) |
| Gas purchases payable - related parties | 2 |
| | (411 | ) | | 202 |
| (1 | ) | | 2 |
| | (411 | ) |
| Prepaid and accrued taxes | 10,366 |
| | 2,385 |
| | (18,161 | ) | 1,254 |
| | 10,366 |
| | 2,385 |
|
| Accounts payable and other | 13,086 |
| | (15,656 | ) | | (14,714 | ) | 40,422 |
| | 13,086 |
| | (15,656 | ) |
| Restricted broker margin accounts | 22,570 |
| | (38,752 | ) | | 18,452 |
| (30,974 | ) | | 22,570 |
| | (38,752 | ) |
Customers’ credit balances and deposits | (5,877 | ) | | 12,044 |
| | (1,545 | ) | |
| Customers’ credit balances and deposits | | 368 |
| | (5,877 | ) | | 12,044 |
|
| Other current assets | 10,313 |
| | 3,353 |
| | (14,038 | ) | (3,631 | ) | | 10,313 |
| | 3,353 |
|
| Total | $ | 17,081 |
| | $ | (123,325 | ) | | $ | 81,817 |
| $ | 97,004 |
| | $ | 17,081 |
| | $ | (123,325 | ) |
| SUPPLEMENTAL DISCLOSURES | | | | | | | | | | |
| Cash paid (received) for: | | | | | | | | | | |
| Interest (net of amounts capitalized) | $ | 44,362 |
| | $ | 31,996 |
| | $ | 24,208 |
| $ | 44,821 |
| | $ | 44,362 |
| | $ | 31,996 |
|
| Income taxes | $ | (6,877 | ) | | $ | (3,516 | ) | | $ | 28,790 |
| $ | 5,577 |
| | $ | (6,877 | ) | | $ | (3,516 | ) |
| Accrued capital expenditures | $ | 21,769 |
| | $ | 48,881 |
| | $ | 28,676 |
| $ | 30,559 |
| | $ | 21,769 |
| | $ | 48,881 |
|
| Deferred gain on non-cash exchange of investments | $ | — |
| | $ | — |
| | $ | 24,601 |
| |
Inception gain on natural gas swap contract recognized as non-cash proceeds from sale of business
| | $ | 14,579 |
| | $ | — |
| | $ | — |
|
See Notes to Consolidated Financial Statements |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CONSOLIDATED BALANCE SHEETS
ASSETS
| | | (Thousands) | | |
| September 30, | 2017 | 2016 | 2018 | 2017 |
| | | |
| PROPERTY, PLANT AND EQUIPMENT | | |
| Utility plant, at cost | $ | 2,241,324 |
| $ | 2,107,375 |
| $ | 2,368,914 |
| $ | 2,241,324 |
|
| Construction work in progress | 119,318 |
| 122,268 |
| 192,481 |
| 119,318 |
|
| Solar and wind equipment, real estate properties and other, at cost | 843,142 |
| 631,696 |
| |
| Nonutility plant and equipment, at cost | | 697,406 |
| 843,142 |
|
| Construction work in progress | 7,286 |
| 93,791 |
| 45,690 |
| 7,286 |
|
| Total property, plant and equipment | 3,211,070 |
| 2,955,130 |
| 3,304,491 |
| 3,211,070 |
|
| Accumulated depreciation and amortization, utility plant | (489,122 | ) | (467,702 | ) | (530,753 | ) | (489,122 | ) |
| Accumulated depreciation and amortization, solar and wind equipment, real estate properties and other | (112,207 | ) | (79,776 | ) | |
| Accumulated depreciation and amortization, nonutility plant and equipment | | (122,689 | ) | (112,207 | ) |
| Property, plant and equipment, net | 2,609,741 |
| 2,407,652 |
| 2,651,049 |
| 2,609,741 |
|
| | | |
| CURRENT ASSETS | | |
| Cash and cash equivalents | 2,226 |
| 37,546 |
| 1,458 |
| 2,226 |
|
| Customer accounts receivable: | | |
| Billed | 196,467 |
| 142,658 |
| 205,490 |
| 196,467 |
|
| Unbilled revenues | 7,202 |
| 5,744 |
| 7,199 |
| 7,202 |
|
| Allowance for doubtful accounts | (5,181 | ) | (4,865 | ) | (5,704 | ) | (5,181 | ) |
| Regulatory assets | 50,791 |
| 54,286 |
| 18,297 |
| 50,791 |
|
| Gas in storage, at average cost | 202,063 |
| 206,251 |
| 184,633 |
| 202,063 |
|
| Materials and supplies, at average cost | 11,944 |
| 10,778 |
| 13,910 |
| 11,944 |
|
| Prepaid and accrued taxes | 24,764 |
| 34,179 |
| 23,047 |
| 24,764 |
|
| Derivatives, at fair value | 30,081 |
| 29,964 |
| 27,396 |
| 30,081 |
|
| Restricted broker margin accounts | 25,827 |
| 47,644 |
| 53,719 |
| 25,827 |
|
| Asset held for sale | — |
| 7,660 |
| 206,905 |
| — |
|
| Other current assets | 33,260 |
| 35,419 |
| 33,730 |
| 33,260 |
|
| Total current assets | 579,444 |
| 607,264 |
| 770,080 |
| 579,444 |
|
| | | |
| NONCURRENT ASSETS | | |
| Investments in equity investees | 172,585 |
| 141,148 |
| 190,866 |
| 172,585 |
|
| Regulatory assets | 375,919 |
| 441,294 |
| 368,592 |
| 375,919 |
|
| Derivatives, at fair value | 9,164 |
| 5,227 |
| 10,560 |
| 9,164 |
|
| Available for sale securities | 65,752 |
| 55,789 |
| 32,917 |
| 65,752 |
|
| Intangible assets | 41,084 |
| — |
| 23,375 |
| 41,084 |
|
| Other noncurrent assets | 74,818 |
| 60,196 |
| 96,225 |
| 74,818 |
|
| Total noncurrent assets | 739,322 |
| 703,654 |
| 722,535 |
| 739,322 |
|
| Total assets | $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 4,143,664 |
| $ | 3,928,507 |
|
See Notes to Consolidated Financial Statements
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CAPITALIZATION AND LIABILITIES
| | | (Thousands, except share data) | | |
| September 30, | 2017 | 2016 | 2018 | 2017 |
| | | |
| CAPITALIZATION | | |
Common stock, $2.50 par value; authorized 150,000,000 shares;
outstanding September 30, 2017 — 86,555,507; September 30, 2016 — 86,086,355 | $ | 222,258 |
| $ | 221,654 |
| |
Common stock, $2.50 par value; authorized 150,000,000 shares; Outstanding September 30, 2018 — 88,292,956; September 30, 2017 — 86,555,507 | | $ | 226,196 |
| $ | 222,258 |
|
| Premium on common stock | 219,696 |
| 215,580 |
| 274,748 |
| 219,696 |
|
| Accumulated other comprehensive (loss), net of tax | (3,256 | ) | (15,155 | ) | |
Treasury stock at cost and other;
shares September 30, 2017 — 2,347,380; September 30, 2016 — 2,575,139 | (70,039 | ) | (81,044 | ) | |
| Accumulated other comprehensive loss, net of tax | | (12,610 | ) | (3,256 | ) |
Treasury stock, at cost and other; Shares September 30, 2018 — 2,185,013; September 30, 2017 — 2,347,380 | | (76,473 | ) | (70,039 | ) |
| Retained earnings | 867,984 |
| 825,556 |
| 1,007,117 |
| 867,984 |
|
| Common stock equity | 1,236,643 |
| 1,166,591 |
| 1,418,978 |
| 1,236,643 |
|
| Long-term debt | 997,080 |
| 1,055,038 |
| 1,180,619 |
| 997,080 |
|
| Total capitalization | 2,233,723 |
| 2,221,629 |
| 2,599,597 |
| 2,233,723 |
|
| | | |
| CURRENT LIABILITIES | | |
| Current maturities of long-term debt | 165,375 |
| 61,452 |
| 123,545 |
| 165,375 |
|
| Short-term debt | 266,000 |
| 121,700 |
| 151,950 |
| 266,000 |
|
| Gas purchases payable | 160,115 |
| 139,452 |
| 211,303 |
| 160,115 |
|
| Gas purchases payable to related parties | 1,152 |
| 1,150 |
| 1,150 |
| 1,152 |
|
| Accounts payable and other | 96,878 |
| 107,184 |
| 135,240 |
| 96,878 |
|
| Dividends payable | 23,586 |
| 21,975 |
| 25,824 |
| 23,586 |
|
| Accrued taxes | 2,031 |
| 1,080 |
| 1,568 |
| 2,031 |
|
| Regulatory liabilities | 78 |
| 9,469 |
| 8,185 |
| 78 |
|
| New Jersey clean energy program | 14,202 |
| 14,232 |
| |
| New Jersey Clean Energy Program | | 14,052 |
| 14,202 |
|
| Derivatives, at fair value | 46,544 |
| 61,080 |
| 46,652 |
| 46,544 |
|
| Liabilities held for sale | | 4,182 |
| — |
|
| Customers’ credit balances and deposits | 26,957 |
| 32,834 |
| 27,325 |
| 26,957 |
|
| Total current liabilities | 802,918 |
| 571,608 |
| 750,976 |
| 802,918 |
|
| | | |
| NONCURRENT LIABILITIES | | |
| Deferred income taxes | 514,708 |
| 473,847 |
| 242,436 |
| 514,708 |
|
| Deferred investment tax credits | 4,297 |
| 4,619 |
| 3,976 |
| 4,297 |
|
| Deferred gain | 27,728 |
| 28,519 |
| 9,104 |
| 27,728 |
|
| Derivatives, at fair value | 11,330 |
| 25,252 |
| 22,982 |
| 11,330 |
|
| Manufactured gas plant remediation | 149,000 |
| 172,000 |
| 130,800 |
| 149,000 |
|
| Postemployment employee benefit liability | 128,888 |
| 141,604 |
| 137,007 |
| 128,888 |
|
| Regulatory liabilities | 14,507 |
| 41,411 |
| 209,139 |
| 14,507 |
|
| Asset retirement obligation | 31,420 |
| 28,379 |
| 28,688 |
| 31,420 |
|
| Other noncurrent liabilities | 9,988 |
| 9,702 |
| 8,959 |
| 9,988 |
|
| Total noncurrent liabilities | 891,866 |
| 925,333 |
| 793,091 |
| 891,866 |
|
| Commitments and contingent liabilities (Note 14) |
|
|
| |
| Commitments and contingent liabilities (Note 13) | |
|
|
|
| Total capitalization and liabilities | $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 4,143,664 |
| $ | 3,928,507 |
|
See Notes to Consolidated Financial Statements
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
CONSOLIDATED STATEMENTS OF COMMON STOCK EQUITY
| | | (Thousands) | Number of Shares | Common Stock | Premium on Common Stock | Accumulated Other Comprehensive (Loss) Income | Treasury Stock And Other | Retained Earnings | Total | Number of Shares | Common Stock | Premium on Common Stock | Accumulated Other Comprehensive (Loss) Income | Treasury Stock And Other | Retained Earnings | Total |
| Balance at September 30, 2014 | 84,356 |
| $ | 218,223 |
| $ | 199,739 |
| | $ | (5,594 | ) | | $ | (121,031 | ) | $ | 674,829 |
| $ | 966,166 |
| |
| Net income |
|
| |
| |
| 180,960 |
| 180,960 |
| |
| Other comprehensive loss |
|
| | (3,800 | ) | |
| (3,800 | ) | |
| Common stock issued: | | | | | | | |
| Incentive compensation plan | 359 |
| 895 |
| 5,013 |
| |
| |
| 5,908 |
| |
Dividend reinvestment plan (1) | 1,149 |
| 1,720 |
| 6,722 |
| |
| | 19,096 |
|
| 27,538 |
| |
| Tax benefits from stock plans |
|
| (1,344 | ) | |
| |
| (1,344 | ) | |
| Cash dividend declared ($.915 per share) |
|
| |
| |
| (78,044 | ) | (78,044 | ) | |
| Treasury stock and other | (333 | ) |
| (199 | ) | |
| | 9,771 |
|
| 9,572 |
| |
| Balance at September 30, 2015 | 85,531 |
| 220,838 |
| 209,931 |
| | (9,394 | ) | | (92,164 | ) | 777,745 |
| 1,106,956 |
| 85,531 |
| $ | 220,838 |
| $ | 209,931 |
| | $ | (9,394 | ) | | $ | (92,164 | ) | $ | 777,745 |
| $ | 1,106,956 |
|
| Net income |
|
| |
| |
| 131,672 |
| 131,672 |
|
|
| |
| |
| 131,672 |
| 131,672 |
|
| Other comprehensive loss |
|
| | (5,761 | ) | |
| (5,761 | ) |
|
| | (5,761 | ) | |
| (5,761 | ) |
| Common stock issued: | | | | | | | | | | | | |
| Incentive compensation plan | 325 |
| 816 |
| 8,583 |
| |
| |
| 9,399 |
| 325 |
| 816 |
| 8,583 |
| |
| |
| 9,399 |
|
Dividend reinvestment plan (1) | 471 |
|
| (2,879 | ) | |
| | 18,942 |
|
| 16,063 |
| 471 |
|
| (2,879 | ) | |
| | 18,942 |
|
| 16,063 |
|
| Cash dividend declared ($.975 per share) |
|
| |
| |
| (83,861 | ) | (83,861 | ) |
|
| |
| |
| (83,861 | ) | (83,861 | ) |
| Treasury stock and other | (241 | ) |
| (55 | ) | |
| | (7,822 | ) |
| (7,877 | ) | (241 | ) |
| (55 | ) | |
| | (7,822 | ) |
| (7,877 | ) |
| Balance at September 30, 2016 | 86,086 |
| 221,654 |
| 215,580 |
| | (15,155 | ) | | (81,044 | ) | 825,556 |
| 1,166,591 |
| 86,086 |
| 221,654 |
| 215,580 |
| | (15,155 | ) | | (81,044 | ) | 825,556 |
| 1,166,591 |
|
| Net income |
|
| |
| |
| 132,065 |
| 132,065 |
|
|
| |
| |
| 132,065 |
| 132,065 |
|
| Other comprehensive income |
|
| | 11,899 |
| |
| 11,899 |
|
|
| | 11,899 |
| |
| 11,899 |
|
| Common stock issued: | | | | | | | | | | | | |
| Incentive compensation plan | 241 |
| 604 |
| 5,090 |
| |
| |
| 5,694 |
| 241 |
| 604 |
| 5,090 |
| |
| |
| 5,694 |
|
Dividend reinvestment plan (1) | 472 |
|
| (946 | ) | |
| | 18,568 |
|
| 17,622 |
| 472 |
|
| (946 | ) | |
| | 18,568 |
|
| 17,622 |
|
| Cash dividend declared ($1.0375 per share) |
|
| |
| |
| (89,637 | ) | (89,637 | ) |
|
| |
| |
| (89,637 | ) | (89,637 | ) |
| Treasury stock and other | (243 | ) |
| (28 | ) | |
| | (7,563 | ) |
| (7,591 | ) | (243 | ) |
| (28 | ) | |
| | (7,563 | ) |
| (7,591 | ) |
| Balance at September 30, 2017 | 86,556 |
| $ | 222,258 |
| $ | 219,696 |
| | $ | (3,256 | ) | | $ | (70,039 | ) | $ | 867,984 |
| $ | 1,236,643 |
| 86,556 |
| 222,258 |
| 219,696 |
| | (3,256 | ) | | (70,039 | ) | 867,984 |
| 1,236,643 |
|
| Net income | |
|
| |
| |
| 233,436 |
| 233,436 |
|
| Other comprehensive loss | |
|
| | (6,078 | ) | |
| (6,078 | ) |
| Common stock issued: | | | | | | | |
| Incentive compensation plan | | 561 |
| 1,403 |
| 15,169 |
| |
| |
| 16,572 |
|
Dividend reinvestment plan (1) | | 413 |
|
| 755 |
| |
| | 16,339 |
|
| 17,094 |
|
| Waiver discount | | 1,014 |
| 2,535 |
| 39,142 |
| |
| |
| 41,677 |
|
| Cash dividend declared ($1.11 per share) | |
|
| |
| |
| (97,579 | ) | (97,579 | ) |
| Treasury stock and other | | (251 | ) |
| (14 | ) | |
| | (22,773 | ) |
| (22,787 | ) |
Reclassifications of certain income tax effects to retained earnings (2) | |
|
| | (3,276 | ) | |
| 3,276 |
| — |
|
| Balance at September 30, 2018 | | 88,293 |
| $ | 226,196 |
| $ | 274,748 |
| | $ | (12,610 | ) | | $ | (76,473 | ) | $ | 1,007,117 |
| $ | 1,418,978 |
|
| |
| (1) | The DRP allows NJR, at its option, to use newly issued shares to raise capital. During fiscal 2015, NJR issued approximately 688,000 new sharesShares sold through the waiver discount featureDRP are issued from treasury stock at average cost, which may differ from the actual market price paid.
|
| |
| (2) | Due to the adoption of its DRP. There were no new shares issued throughASU No. 2018-02, an amendment to ASC 740, Income Taxes. See Note 2. Summary of Significant Accounting Policies - Recently Adopted Updates to the waiver discount feature during fiscal 2016and fiscal 2017.Accounting Standards Codification section for more details. |
See Notes to Consolidated Financial Statements
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
1. NATURE OF THE BUSINESS
New Jersey Resources Corporation provides regulated gas distribution services and operates certain unregulated businesses primarily through the following:
New Jersey Natural Gas Company provides natural gas utility service to approximately 529,800538,700 retail customers in central and northern New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment;segment.
NJR Clean Energy Ventures Corporation, the Company’sCompany's clean energy subsidiary, comprises the Clean Energy Ventures segment and consists of the Company’sCompany's capital investments in commercial and residential solar projects located throughout New Jersey and onshore wind investments in Montana, Iowa, Kansas, Wyoming and Pennsylvania;Pennsylvania. On June 1, 2018, Clean Energy Ventures completed the sale of its membership interest in a 9.7 MW wind farm in Two Dot, Montana. See Note 17. Dispositions for more details regarding the sale.
NJR Energy Services Company and NJR Retail Services Company comprisecomprises the Energy Services segment. NJRESEnergy Services maintains and transacts around a portfolio of natural gas storage and transportation capacity contracts and provides physical wholesale energy and energy management services in the U.S. and Canada. From July 2017 through February 2018, NJRRSJR Retail Services Company providesprovided retail natural gas supply and transportation services to commercial and industrial customers in Delaware, Maryland, Pennsylvania and New Jersey;Jersey as part of the Energy Services segment. NJRRS was sold to an unrelated third party on February 28, 2018. See Note 17. Dispositions for more details regarding the sale.
NJR Midstream Holdings Corporation, which comprises the Midstream segment, invests in energy-related ventures through its subsidiaries, NJR Steckman Ridge Storage Company, which holds the Company’sCompany's 50 percent combinedownership interest in Steckman Ridge, located in Pennsylvania,Pennsylvania; NJNR Pipeline, which holds our DM Common Units; and NJR Pipeline Company, which holdsincludes Adelphia Gateway, LLC and the Company’sCompany's 20 percent ownership interest in PennEast and NJNR Pipeline Company, which holds approximately 1.84 million DM Common Units.. See Note 7.6. Investments in Equity Investees for more information; andinformation.
NJR Retail Holdings Corporation has two principal subsidiaries,subsidiaries: NJR Home Services Company, which provides heating, central air conditioning, standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey,Jersey; and Commercial Realty & Resources Corporation, which owns commercial real estate. NJR Home Services Company and Commercial Realty & Resources Corporation are included in Home Services and Other operations.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The Consolidated Financial Statements include the accounts of the Company and its wholly-owned subsidiaries. All intercompany accounts and transactions have been eliminated.
Other financial investments or contractual interests that lack the characteristics of a voting interest entity, which are commonly referred to as variable interest entities, are evaluated by the Company to determine if itthe 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, 2018, 2017 2016 and 2015.2016.
Investments in entities over which the Company does not have a controlling financial interest are either accounted for under the equity method or cost method of accounting.
Use of Estimates
The preparation of financial statements in conformity with GAAP requires the Company to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosure of contingencies during the reporting period. On a monthlyquarterly 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, investments, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, long-lived assets, regulatory assets and liabilities, income taxes, pensions and other postemployment benefits, contingencies related to environmental matters and litigation. AROs are evaluated as often as needed. The Company’s estimates are based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.
Business Combinations
The Company accounts for business combinations by applying the acquisition method of accounting. Identifiable assets acquired and liabilities assumed are measured separately at their fair value as of the acquisition date and associated transactions costs are expensed as incurred.
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. Our valuation of an acquired business is based on available information at the acquisition date and assumptions that we believe are reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date. See Note 3. Acquisition for information related to the Company’s acquisition of a gas marketing business on July 27, 2017.
Regulatory Assets & Liabilities
Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment.
Our Natural Gas Distribution segment maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and in accordance with the Regulated Operations Topic of the FASB ASC. As a result of the impact of the ratemaking process and regulatory actions of the BPU, NJNG is required to recognize the economic effects of rate regulation. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 4. Regulation for a more detailed description of NJNG’s regulatory assets and liabilities.
Gas in Storage
Gas in storage is reflected at average cost on the Consolidated Balance Sheets, and represents natural gas and LNG that will be utilized in the ordinary course of business.
The following table summarizes gas in storage, at average cost by company, as of September 30:
|
| | | | | | | | | | | | |
| | 2017 | 2016 |
| ($ in thousands) | Gas in Storage | | Bcf | Gas in Storage | | Bcf |
| Energy Services | | $ | 122,884 |
| 53.9 |
| | $ | 130,493 |
| 62.0 |
|
| Natural Gas Distribution | | 79,179 |
| 21.8 |
| | 75,758 |
| 21.3 |
|
| Total | | $ | 202,063 |
| 75.7 |
| | $ | 206,251 |
| 83.3 |
|
Demand Fees
For the purpose of securing storage and pipeline capacity in support of their respective businesses, our Energy Services and Natural Gas Distribution segments enter into storage and pipeline capacity contracts, which require the payment of associated demand fees and charges that allow them access to a high priority of service in order to maintain the ability to access storage or pipeline capacity during a fixed time period, which generally ranges from one to 10 years. Many of these demand fees and charges are based on established tariff rates as established and regulated by FERC. These charges represent commitments to pay storage providers and pipeline companies for the priority right to transport and/or store natural gas utilizing their respective assets.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table summarizes the demand charges, which are net of capacity releases, and are included as a component of gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Millions) | 2017 | 2016 | 2015 |
Energy Services
| $ | 126.4 |
| $ | 141.0 |
| $ | 130.6 |
|
| Natural Gas Distribution | 80.2 |
| 77.8 |
| 80.5 |
|
| Total | $ | 206.6 |
| $ | 218.8 |
| $ | 211.1 |
|
Energy Services expenses demand charges ratably over the term of the service being provided.
Our Natural Gas Distribution segment’s costs associated with demand charges are included in its weighted average cost of gas. The demand charges are expensed based on NJNG’s BGSS sales and recovered as part of its gas commodity component of its BGSS tariff.
Derivative Instruments
The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts, interest rate contracts, as well as its physical commodity contracts related to the purchase and sale of natural gas at Energy Services, as derivatives, and therefore recognizes them at fair value on the Consolidated Balance Sheets. The Company’s unregulated subsidiaries record changes in the fair value of their financial commodity derivatives in gas purchases and changes in the fair value of their physical forward contracts in gas purchases or operating revenues, as appropriate, on the Consolidated Statements of Operations. Energy Services designated its foreign exchange contracts, entered into prior to January 1, 2016, as cash flow hedges of Canadian dollar denominated gas purchases. Changes in the fair value of the effective portion of these hedges are recorded to AOCI, a component of stockholders’ equity, and reclassified to gas purchases on the Consolidated Statements of Operations when they settle. Ineffective portions of the cash flow hedges are recognized immediately in earnings. The Company did not have derivatives designated as fair value hedges during fiscal 2016 and 2017.
The Derivatives and Hedging Topic of the ASC also provides for a NPNS scope exception for qualifying physical commodity contracts that are intended for purchases and sales during the normal course of business and for which physical delivery is probable. 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 forward SREC contracts at Clean Energy Ventures. When applied, it does not record changes in the fair value of these contracts until the contract settles and the related underlying natural gas or SREC 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, swaps, and certain options, are based on unadjusted, quoted prices in active markets. The Company’s non-exchange-traded financial instruments, foreign currency derivatives, over-the-counter physical commodity contracts at Energy Services and NJNG’s Treasury Lock 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.
Revenues
Revenues from the sale of natural gas to NJNG customers are recognized in the period that gas is delivered and consumed by customers, including an estimate for unbilled revenue.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 gas and the most current tariff rates.
Clean Energy Ventures recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the transfer of certificates as per contractual settlement schedules.
Revenues for Energy Services are recognized when the natural gas is physically delivered to the customer. In addition, changes in the fair value of derivatives that economically hedge the forecasted sales of the natural gas are recognized in operating revenues as they occur, as noted above. Energy Services also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues.
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.
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.
Gas purchases at Energy Services are comprisedcomposed of 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 gas purchases as they occur.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Demand Fees
For the purpose of securing storage and pipeline capacity in support of their respective businesses, the Energy Services and Natural Gas Distribution segments enter into storage and pipeline capacity contracts, which require the payment of associated demand fees and charges that allow them access to a high priority of service in order to maintain the ability to access storage or pipeline capacity during a fixed time period, which generally ranges from one to 10 years. Many of these demand fees and charges are based on established tariff rates as established and regulated by FERC. These charges represent commitments to pay storage providers and pipeline companies for the priority right to transport and/or store natural gas utilizing their respective assets.
The following table summarizes the demand charges, which are net of capacity releases, and are included as a component of gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Millions) | 2018 | 2017 | 2016 |
Energy Services
| $ | 153.0 |
| $ | 126.4 |
| $ | 141.0 |
|
| Natural Gas Distribution | 92.5 |
| 80.2 |
| 77.8 |
|
| Total | $ | 245.5 |
| $ | 206.6 |
| $ | 218.8 |
|
Energy Services expenses demand charges over the term of the service being provided.
The Natural Gas Distribution segment’s costs associated with demand charges are included in its weighted average cost of gas. The demand charges are expensed based on NJNG’s BGSS sales and recovered as part of its gas commodity component of its BGSS tariff.
Operations and Maintenance Expenses
Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of vehicles, tools and equipment, payments to contractors, utility plant maintenance, customer service, professional fees and other outside services, insurance expense, accretion of cost of removal for future retirements of utility assets and other administrative expenses and are expensed as incurred.
Stock-Based Compensation
Stock-based compensation represents costs related to stock-based awards granted to employees and NJR Board of Directors members. 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 9. Stock-Based Compensation for further information.
Sales Tax Accounting
Sales tax that is collected from customers is presented in both operating revenues and operating expenses on the Consolidated Statements of Operations. During fiscal 2018, 2017 and 2016, sales tax collected was $41.7 million, $39.4 million and $31 million, respectively. Effective January 1, 2017, the New Jersey sales tax rate decreased from 7 percent to 6.875 percent. Effective January 1, 2018, the New Jersey sales tax rate decreased again to 6.625 percent.
Income Taxes
The Company computes income taxes using the asset and liability method, whereby deferred income taxes are generally determined based on the difference between the financial statement and tax basis of assets and liabilities using enacted tax rates in effect in the years in which the differences are expected to reverse. See Note 13.12. 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.
The Company invests in property that qualifies for federal ITCs and utilizes the ITCs, as allowed, based on the cost and life of the assets. ITCs at NJNG are deferred and amortized as a reduction to the tax provision over the average lives of the related equipment in accordance with regulatory treatment. ITCs at NJR’sthe unregulated subsidiaries of NJR are recognized as a reduction to income tax expense when the property is placed in service. The Company invests in property that qualifies for PTCs. PTCs are recognized as reductions to current federal income tax expense as PTCs are generated through the production activities of the assets. Changes to the federal statutes related to ITCs and PTCs, which have the effect of reducing or eliminating the credits, could have a negative impact on earnings and cash flows.
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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Capitalized amounts associated with the debt and equity components of NJNG’s AFUDC are recordedInvestments in utility plant on the Consolidated Balance Sheets. Corresponding amounts for the debt component is recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations and include the following for the fiscal years ended September 30:
|
| | | | | | | | | |
| ($ in thousands) | 2017 | 2016 | 2015 |
| AFUDC: | | | |
| Debt | $ | 1,311 |
| $ | 5,009 |
| $ | 2,472 |
|
| Equity | 3,867 |
| 4,375 |
| 3,825 |
|
| Total | $ | 5,178 |
| $ | 9,384 |
| $ | 6,297 |
|
| Weighted average interest rate | 6.90 | % | 5.06 | % | 4.63 | % |
Pursuant to a BPU order, NJNGThe Company accounts for its investments in Steckman Ridge and PennEast, using the equity method of accounting where its respective ownership interests are 50 percent or less and/or it has significant influence over operating and management decisions, but is permitted to recover carrying costs on uncollected balances related to SBC program costs, which include NJCEP, RAC and USF expenditures. Seenot the primary beneficiary, as defined under ASC 810, Note 4. RegulationConsolidation. The SBC interest rate changes each September based on the August 31 seven-year constant maturity Treasury rate plus 60 basis points. The rate was 2.55 percent, 2.05 percent and 2.54 percent for the fiscal years ended September 30, 2017, 2016 and 2015, respectively. Accordingly, other income included $78,000, $54,000 and $61,000 in the fiscal years ended September 30, 2017, 2016 and 2015, respectively.
Sale-Leasebacks
The Company utilizes sale-leaseback arrangements to fund certainCompany’s share of its capital expenditures, whereby the physical assetearnings is sold concurrent with an agreement to lease the asset back, with options that allow the Company to renew the lease at the end of the term or repurchase the asset. Proceeds from sale-leaseback transactions are included in long-term debt on the Consolidated Balance Sheets.
For certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third-parties and the concurrent leaseback of the assets. For sale-leaseback transactions where the Company has concluded that the terms of the arrangement create a continuing involvement in the asset and the asset is considered integral equipment, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the lessor that constitute a payment to acquire the solar energy asset as a financing arrangement, which is recorded as a component of debt on the Consolidated Balance Sheets.
During fiscal 2017 and 2016, NJNG received $9.6 million and $7.1 million, respectively, in connection with the sale-leaseback of its natural gas meters with terms ranging from seven to 11 years.
In September 2017, Clean Energy Ventures received $32.9 million in proceeds related to the sale of two commercial solar assets. Clean Energy Ventures simultaneously entered into an agreement to lease the assets back over seven-year terms. The Company will continue to operate the solar assets including related expenses and retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects were transferred to the buyer, however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures will recognize the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods that are recognized as the recapture periods expire, starting at the beginningequity in earnings of the second year of the lease. There were no sale-leaseback transactions at Clean Energy Ventures during fiscal 2016.
Sales Tax Accounting
Sales tax that is collected from customers is presented in both operating revenues and operating expensesaffiliates on the Consolidated Statements of Operations. During fiscal 2017, 2016 and 2015, sales tax collected was $39.4 million, $31 million and $44.1 million, respectively. Effective January 1, 2017, the New Jersey sales tax rate decreased from 7 percent to 6.875 percent.See Note 6. Investments in Equity Investees for more information.
Cash and Cash Equivalents
Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash of $243,000 and $1.6 million as of September 30, 2017 and 2016, respectively, related to escrow balances for utility plant projects, which is recorded in other current and noncurrent assets on the Consolidated Balance Sheets.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Property Plant and Equipment
Regulated property, plant and equipment and solar and wind equipment areis stated at original cost. Regulated property, plant and equipment costsCosts include direct labor, materials and third-party construction contractor costs, AFUDC and certain indirect costs related to equipment and employees engaged in construction. Nonregulated property, plant and equipment is stated at original cost. Costs include direct labor, materials and third-party construction contractor costs and certain indirect costs related to equipment and employees engaged in construction. Upon retirement, the cost of depreciable regulated 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 unregulated assets,entities, and using rates based on the estimated average lives of the various classes of depreciable property for NJNG. The composite rate of depreciation used for NJNG was 2.252.29 percent of average depreciable property in fiscal 2018, 2.25 percent in fiscal 2017 and 2.32 percent in fiscal 2016 and 2.31 percent in fiscal 2015.2016. The Company recorded $85.7 million, $81.8 million $72.7 million and $61.4$72.7 million in depreciation expense during fiscal 2018, 2017 2016 and 2015,2016, respectively. Effective October 1, 2016, the overall depreciation rate is 2.4 percent, as settled in the base rate case.
Property, plant and equipment was comprised of the following as of September 30:
| | | (Thousands) | | | | |
| Property Classifications | Estimated Useful Lives | | 2017 | 2016 | Estimated Useful Lives | | 2018 | 2017 |
| Distribution facilities | 38 to 74 years | | $ | 1,952,697 |
| $ | 1,823,672 |
| 38 to 74 years | | $ | 2,151,249 |
| $ | 1,952,697 |
|
| Transmission facilities | 35 to 56 years | | 294,586 |
| 292,433 |
| 35 to 56 years | | 295,692 |
| 294,586 |
|
| Storage facilities | 34 to 47 years | | 78,245 |
| 78,238 |
| 34 to 47 years | | 79,470 |
| 78,245 |
|
| Solar property | 20 to 25 years | | 587,345 |
| 479,948 |
| 20 to 25 years | | 720,562 |
| 587,345 |
|
Wind property | 25 years | | 244,764 |
| 228,644 |
| 17 to 25 years | | — |
| 244,764 |
|
Midstream property (2) | | 30 years | | 6,747 |
| — |
|
| All other property | 5 to 35 years | | 53,433 |
| 52,195 |
| 5 to 35 years | | 50,771 |
| 53,433 |
|
| Total property, plant and equipment | | 3,211,070 |
| 2,955,130 |
| | 3,304,491 |
| 3,211,070 |
|
| Accumulated depreciation and amortization | | (601,329 | ) | (547,478 | ) | | (653,442 | ) | (601,329 | ) |
| Property, plant and equipment, net | | $ | 2,609,741 |
| $ | 2,407,652 |
| | $ | 2,651,049 |
| $ | 2,609,741 |
|
| |
| (1) | Reclassified to assets held for sale. See Note 2. Summary of Significant Accounting Policies, for more information. |
| |
| (2) | Includes activity related to the acquisition of IEC by Adelphia. For fiscal 2017, Midstream property was originally included in All other property. |
OnIn March 8, 2017, CR&R sold a 56,400 square foot56,400-square-foot office building on five acres of land located in Monmouth County for $9.4 million, net of closing costs, generating a pre-tax gain of $1.9 million, which was recognized as a reduction to O&M on the Consolidated Statements of Operations.
Intangible Assets
Finite-lived intangible assets are stated at cost less accumulated amortization. The Company amortizes intangible assets based upon the pattern in which the economic benefits are consumed over the life of the asset unless a pattern cannot be reliably determined, in which case the Company uses a straight-line amortization method. As of September 30, 2017, the Company has an intangible asset, net of amortization, of $41.1 million related to its acquisition of Talen's wholesale natural gas energy contracts. These contracts are being amortized based upon expected cash flows over the respective terms of the agreements. The estimated future amortization expense for the next five years as of September 30, is as follows:
|
| | | |
| (Thousands) | |
| 2018 | $ | 18,222 |
|
| 2019 | $ | 8,424 |
|
| 2020 | $ | 4,925 |
|
| 2021 | $ | 4,604 |
|
| 2022 | $ | 2,561 |
|
| Thereafter | $ | 2,348 |
|
SeeNJNG’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 3. Acquisition for more information about the acquisition of Talen's gas marketing business.Regulation - Infrastructure programs.
Long-lived AssetsCapitalized 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.
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 of such assets may not be recoverable. 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. During the year, there were no events or circumstances that indicated that the carrying value of assets is not recoverable.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Investments in Equity InvesteesCapitalized and deferred interest include the following for the fiscal years ended September 30:
|
| | | | | | | | | |
| ($ in thousands) | 2018 | 2017 | 2016 |
| AFUDC: | | | |
| Debt | $ | 1,979 |
| $ | 1,311 |
| $ | 5,009 |
|
| Equity | 5,531 |
| 3,867 |
| 4,375 |
|
| Total | $ | 7,510 |
| $ | 5,178 |
| $ | 9,384 |
|
| Weighted average interest rate | 5.94 | % | 6.90 | % | 5.06 | % |
The Company accounts for its investments in Steckman Ridge, PennEastPursuant to a BPU order, NJNG is permitted to recover carrying costs on uncollected balances related to SBC program costs, which include NJCEP, RAC and Iroquois (through September 29, 2015), using the equity method of accounting, where its respective ownership interests are 50 percent or less and/or it has significant influence over operating and management decisions, but is not the primary beneficiary, as defined under ASC 810,USF expenditures. See ConsolidationNote 3. Regulation. The Company’s share of earnings is recognized as equity in earnings of affiliatesSBC interest rate changes each September based on the Consolidated Statements of Operations. See Note 7. InvestmentsAugust 31 seven-year constant maturity treasury rate plus 60 basis points. The rate was 3.41 percent, 2.55 percent and 2.05 percent for the fiscal years ended September 30, 2018, 2017 and 2016, respectively. Accordingly, other income included $411,000, $78,000 and $54,000 in Equity Investees for more information.the fiscal years ended September 30, 2018, 2017 and 2016, respectively.
Available for Sale SecuritiesCash and Cash Equivalents
The Company hadCash and cash equivalents consist of cash on deposit and temporary investments in two publicly traded energy companies that have a fair valuewith maturities of $65.8 millionthree months or less, and $55.8 millionexcludes restricted cash of $252,000 and $243,000 as of September 30, 2018 and 2017, respectively, related to escrow balances for utility plant projects, which is recorded in other current and 2016, respectively, which are included in available for sale securitiesnoncurrent assets on the Consolidated Balance Sheets. Total unrealized gains associated with these investments are included as a part of accumulated other comprehensive income, a component of common stock equity, and were $18.4 million, $11 million after tax, and $7.2 million, $4.2 million after tax, as of September 30, 2017 and 2016, respectively.
During fiscal 2017, the Company received proceeds of approximately $6.6 million from the sale of available for sale securities and realized a pre-tax gain of approximately $5.4 million, which is included in other income, net on the Consolidated Statements of Operations. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost. There were no sales of securities during fiscal 2016.
Customer Accounts Receivable and Allowance for Doubtful Accounts
Receivables consist of natural gas sales and transportation services billed to residential, commercial, industrial and other customers, as well as equipment sales, installations, solar leases and PPAs to commercial and residential customers. The Company evaluates its accounts receivables and, to the extent customer account balances are outstanding for more than 60 days, establishes an allowance for doubtful accounts. The allowance is based on a combination of factors including historical collection experience and trends, aging of receivables, general economic conditions in the company’sCompany’s distribution or sales territories and customer specificcustomer-specific information. The Company writes-off customers’customer accounts once it is determined they are uncollectible.
The following table summarizes customer accounts receivable by company as of September 30:30:
| | | (Thousands) | 2017 | | 2016 | 2018 | | 2017 |
| Energy Services | $ | 150,322 |
| 77 | % | | $ | 102,884 |
| 72 | % | $ | 157,936 |
| 77 | % | | $ | 150,322 |
| 77 | % |
NJNG (1) | 37,432 |
| 19 |
| | 30,951 |
| 22 |
| |
Natural Gas Distribution (1) | | 39,151 |
| 19 |
| | 37,432 |
| 19 |
|
| Clean Energy Ventures | 2,655 |
| 1 |
| | 1,807 |
| 1 |
| 3,330 |
| 2 |
| | 2,655 |
| 1 |
|
| NJRHS and other | 6,058 |
| 3 |
| | 7,016 |
| 5 |
| |
Home Services and Other Operations
| | 5,073 |
| 2 |
| | 6,058 |
| 3 |
|
| Total | $ | 196,467 |
| 100 | % | | $ | 142,658 |
| 100 | % | $ | 205,490 |
| 100 | % | | $ | 196,467 |
| 100 | % |
| |
| (1) | Does not include unbilled revenues of $7.2$7.2 million and $5.7 million as of September 30, 20172018 and 2016, respectively. 2017. |
Loans Receivable
NJNG currently provides loans, with terms ranging from three to 10 years, to customers that elect to purchase and install certain energy efficientenergy-efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at net present value on the Consolidated Balance Sheets. Refer to Note 6. Fair Value for a discussion of the Company’s fair value measurement policies and level disclosures. The Company has recorded $8.9$10.4 million and $7.8$8.9 million in other current assets and $40.4$39.5 million and $39.5$40.4 million in other noncurrent assets as of September 30, 20172018 and 2016,2017, respectively, on the Consolidated Balance Sheets, related to the loans.
NJNG’s policy If NJNG determines a loan is impaired, the basis of the loan would be subject to establishregulatory review for recovery. As of September 30, 2018 and 2017, the Company has not recorded an allowance for doubtful accounts for SAVEGREEN loans.
Regulatory Assets & Liabilities
Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment.
Our Natural Gas Distribution segment maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and in accordance with the ASC 980, Regulated Operations. As a result of the impact of the ratemaking process and regulatory actions of the BPU, NJNG is required to recognize the economic effects of rate regulation. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 3. Regulation for a more detailed description of NJNG’s regulatory assets and liabilities.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Gas in Storage
Gas in storage is reflected at average cost on the Consolidated Balance Sheets and represents natural gas and LNG that will be utilized in the ordinary course of business.
The following table summarizes gas in storage, at average cost by company, as of September 30:
|
| | | | | | | | | | | | |
| | 2018 | 2017 |
| ($ in thousands) | Gas in Storage | | Bcf | Gas in Storage | | Bcf |
| Energy Services | | $ | 90,166 |
| 34.1 |
| | $ | 122,884 |
| 53.9 |
|
| Natural Gas Distribution | | 94,467 |
| 24.9 |
| | 79,179 |
| 21.8 |
|
| Total | | $ | 184,633 |
| 59.0 |
| | $ | 202,063 |
| 75.7 |
|
Derivative Instruments
The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts and interest rate contracts, as well as its physical commodity contracts related to the purchase and sale of natural gas at Energy Services, as derivatives, and therefore recognizes them at fair value on the Consolidated Balance Sheets. The Company’s unregulated subsidiaries record changes in the fair value of their financial commodity derivatives in gas purchases and changes in the fair value of their physical forward contracts in gas purchases or operating revenues, as appropriate, on the Consolidated Statements of Operations. Ineffective portions of the cash flow hedges are recognized immediately in earnings.
The ASC 815, Derivatives and Hedging also provides for a NPNS scope exception for qualifying physical commodity contracts that are intended for purchases and sales during the normal course of business and for which physical delivery is probable. 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 forward SREC contracts at Clean Energy Ventures. When applied, it does not record changes in the fair value of these contracts until the contract settles and the related underlying natural gas or SREC 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 4. Derivative Instruments for additional details regarding natural gas trading and hedging activities.
Fair values of exchange-traded instruments, including futures and swaps, are based on unadjusted, quoted prices in active markets. The Company’s non-exchange-traded financial instruments, foreign currency derivatives, over-the-counter physical commodity contracts at Energy Services and interest rate contracts are valued using observable, quoted prices for similar or identical assets when loan balancesavailable. 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 arrearsthe 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.
Assets Held for Sale
The Company classifies an asset as held for sale if there is a commitment to sell the asset, the asset is available for immediate sale, the sale is probable and the sale will be completed within one year. In March 2018, Clean Energy Ventures committed to a plan to sell its wind assets and expects that the sale will be completed within the next 12 months. Accordingly, the Company classified its wind assets and related liabilities as held for sale on the Consolidated Balance Sheets, which resulted in depreciation expense on wind assets no longer being recorded.
The wind assets classified as held for sale are measured at the lower of their carrying value or fair value less cost to sell. At September 30, 2018, the Company performed a fair value assessment of its wind assets held for sale. The Company equally weighted the valuation derived from an income approach and a market approach to determine fair value. The Company believes that the estimates and assumptions used in calculating the fair value of our assets and liabilities held for sale are reasonable and appropriate based on the information that was known when the estimates were made. The Company concluded that the fair value of the wind assets was greater than the carrying value and thus no impairment was recorded.
On June 1, 2018, Clean Energy Ventures completed the sale of its membership interest in a 9.7 MW wind farm in Two Dot, Montana. See Note 17. Dispositions for more details.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The major classes of assets and liabilities included within the disposal group as held for sale are as follows:
|
| | | | | | | | | | | | | | | |
| (Thousands) | September 30, 2017 | | Assets reclassified as held for sale | | Assets Sold | | September 30, 2018 |
| Assets held for sale: | | | | | | | |
| Property, plant and equipment - wind equipment, at cost | $ | — |
| | $ | 245,044 |
| | $ | (20,688 | ) | | $ | 224,356 |
|
| Property, plant and equipment - accumulated depreciation, wind equipment | — |
| | (21,561 | ) | | 3,060 |
| | (18,501 | ) |
| Prepaid and accrued taxes | — |
| | 866 |
| | (77 | ) | | 789 |
|
| Other noncurrent assets | — |
| | 261 |
| | — |
| | 261 |
|
| | $ | — |
| | $ | 224,610 |
| | $ | (17,705 | ) | | $ | 206,905 |
|
| Liabilities held for sale: | | | | | | | |
Accounts payable and other (1) | $ | — |
| | $ | — |
| | $ | 186 |
| | $ | 186 |
|
| Asset retirement obligation | — |
| | 4,262 |
| | (266 | ) | | 3,996 |
|
| | $ | — |
| | $ | 4,262 |
| | $ | (80 | ) | | $ | 4,182 |
|
| |
| (1) | Transaction fee owed to broker for the sale of Two Dot wind farm. |
Available for Sale Securities
Available for sale securities are carried at fair value on the Consolidated Balance Sheets. For fiscal years ended September 30, 2018 and prior, total unrealized gains and losses associated are included as a part of accumulated other comprehensive income, a component of common stock equity. Reclassifications of realized gains or losses out of other comprehensive income into earnings are recorded in other income, net on the Consolidated Statements of Operations based on average cost.
Management evaluates its equity securities for other-than-temporary impairment on a quarterly basis, and more frequently when economic, market or other concerns warrant such evaluation. Consideration is given to the length of time and the extent to which the fair value has been less than 60 days. Therecost; the financial condition and near term prospects of the issuer; whether the market decline was affected by macroeconomic conditions, changes in tax laws, regulations or other governmental policies; and whether the Company has the intent to sell the security or more likely than not will be required to sell the security before the recovery of its amortized cost basis. If the decline in value of our equity securities is determined to be other-than-temporary, an impairment is recognized through earnings within other income, net on the Consolidated Statements of Operations.
During fiscal 2018, NJR sold shares of its available for sale securities and received proceeds of approximately $6.6 million and realized a pre-tax gain of approximately $5.3 million, which is included in other income, net on the Consolidated Statements of Operations, or $3.2 million, net of tax. During fiscal 2017, NJR received proceeds of approximately $6.6 million and realized a pre-tax gain of $5.4 million, or $3.2 million, net of tax. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.
DM Units
In September 2015, the Company exchanged its ownership interest in Iroquois for approximately 1.84 million DM Common Units. The investment in DM is included as part of the Company's equity investments in the Midstream segment. The exchange of ownership interests in Iroquois for DM was considered a contribution of real estate into another real estate venture. As a result, the Company recorded a deferred gain of $24.6 million on the Consolidated Balance Sheets, based on the difference between the carrying amount of its investment in Iroquois and the fair value of the DM Common Units on the closing date of the transaction. The deferred gain will be recognized in other income, net on the Consolidated Statements of Operations upon completion of the earnings process, typically through the sale of the related securities, or other earnings event.
On March 15, 2018, the FERC issued a policy revision indicating that it no longer will allow interstate natural gas and oil pipelines held by a MLP to recover an income tax allowance in cost-of-service rates. The policy revision had a material negative impact on the value of NJR's investment in DM Common Units. As a result, the Company evaluated the decrease in fair value of its available for doubtful accountssale securities and determined that the decline was other-than-temporary. Accordingly, the Company recognized an other-than-temporary impairment of $17.8 million, or $14.8 million, net of tax, as of March 31, 2018.
Since the deferred gain was established based upon the difference in the fair value of the DM Common Units acquired and the carrying value of the ownership of Iroquois, concurrent with the impairment charge to earnings, the Company reduced the amount of the deferred gain for the SAVEGREEN loansDM Common Units. This reduction of the deferred gain of $17.8 million was also recorded in other income, net on the Consolidated Statements of Operations.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
On July 18, 2018, the FERC finalized its March 15, 2018 policy regarding the tax treatment of MLP pipelines. Natural gas pipelines within an MLP structure, where the parent is a taxable entity and consolidates the financial results of the MLP on its federal income tax return, will be allowed to include an income tax allowance in its cost-of-service rates.
As of September 30, 2018, the Company's available for sale securities had a fair value of $32.9 million and total unrealized gains were $4.7 million, or $3.4 million, net of deferred income tax benefit. The remaining deferred gain associated with the Company’s investment in DM Common Units totaled $6.8 million. As of September 30, 2017, the Company's available for sale securities had a fair value of $65.8 million and total unrealized gains were $12.8 million, or $7.7 million, net of deferred income tax expense.
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, 2018, intangible assets consist of internal-use software costs of $513,000 and $22.9 million, net of amortization, related to its acquisition of Talen’s wholesale natural gas energy contracts. These contracts are being amortized based upon expected cash flows over the respective terms of the agreements. The estimated future amortization expense for the next five years as of September 30, is as follows:
|
| | | |
| (Thousands) | |
| 2019 | $ | 8,424 |
|
| 2020 | $ | 4,925 |
|
| 2021 | $ | 4,604 |
|
| 2022 | $ | 2,561 |
|
| 2023 | $ | 2,271 |
|
| Thereafter | $ | 77 |
|
Long-lived Assets
The Company reviews the recoverability of long-lived assets and finite-lived intangible assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable, such as significant adverse changes in regulation, business climate or market conditions, including prolonged periods of adverse commodity and capacity prices. If there are changes indicating that the carrying value of such assets may not be recoverable, an undiscounted cash flows test is performed. If the sum of the expected future undiscounted cash flows is less than the carrying amount of the asset, an impairment loss is recognized by reducing the recorded value of the asset to its fair value. During the year, the Company evaluated whether there were such events or circumstances that occurred, including evaluation of the new clean energy legislation signed in May 2018, and concluded that there were no events or circumstances in the current year that indicated that the carrying value of long-lived assets or finite-lived intangibles is not recoverable.
Debt Issuance Costs
Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt. See Note 8. Debt for the total unamortized debt issuance costs that are recorded as a reduction to long-term debt on the Consolidated Balance Sheets.
Sale-Leasebacks
NJNG utilizes sale-leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease at the end of the term or repurchase the asset. Proceeds from sale-leaseback transactions are accounted for as financings and are included in long-term debt on the Consolidated Balance Sheets. During fiscal 2018 and 2017, NJNG received $7.8 million and $9.6 million, respectively, in connection with the sale-leaseback of its natural gas meters with terms ranging from seven to 11 years.
In addition, for certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third parties and the concurrent leaseback of the assets. For sale-leaseback transactions where the Company has concluded that the terms of the arrangement create a continuing involvement in the asset and the asset is
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
considered integral equipment, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the 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.
Clean Energy Ventures received $71.5 million and $32.9 million in proceeds related to the sale of commercial solar assets during fiscal 2018 and 2017, respectively. Clean Energy Ventures simultaneously entered into agreements to lease the assets back over six to 15-year terms. The Company will continue to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects have been transferred to the buyer; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. Clean Energy Ventures did not enter into sale-leaseback during fiscal 2016 and therefore recognized the full ITC in income tax (benefit) provision on the Consolidated Statements of Operations when the assets were placed in service.
Environmental Contingencies
Loss contingencies are recorded as liabilities when it is probable a liability has been incurred and the amount of the loss is reasonably estimable in accordance with accounting standards for contingencies. Estimating probable losses requires an analysis of uncertainties that often depend upon judgments about potential actions by third parties. Accruals for loss contingencies are recorded based on an analysis of potential results.
With respect to environmental liabilities and related costs, NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination. See Note 13. Commitments and Contingent Liabilities for more details.
Pension and Postemployment Plans
The Company has two noncontributory defined pension plans covering eligible employees, including officers. Benefits are based on each employee’s years of service and compensation. The Company’s funding policy is to contribute annually to these plans at least the minimum amount required under the Employee Retirement Income Security Act, as amended, and not more than can be deducted for federal income tax purposes. Plan assets consist of equity securities, fixed-income securities and short-term investments. The Company made a discretionary contribution of $30 million during the first quarter of fiscal 2016 to improve the funded status of the pension plans based on the current actuarial assumptions, which included the adoption of the most recent mortality table. The Company made no discretionary contributions to the pension plans in fiscal 2018 and 2017.
The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds. The Company contributed $6.2 million, $6 million and $3.2 million in aggregate to these plans in fiscal 2018, 2017 and 2016.2016, respectively, which is recorded in postemployment employee benefit liability on the Consolidated Balance Sheets.
See Note 10. Employee Benefit Plans, for a more detailed description of the Company’s pension and postemployment plans.
Asset Retirement Obligations
The Company recognizes a liability for its AROs based onrelated to the fair valuecosts associated with cutting and capping NJNG’s main and service gas distribution mains, which is required by New Jersey law when taking such gas distribution mains out of service. The Company also recognizes AROs associated with Clean Energy Ventures’ solar and wind assets when there are decommissioning provisions in lease agreements that require removal of the liability when incurred, which is generally upon acquisition, construction, development and/or throughasset at the normal operationend of the asset. Concurrently, the Company also capitalizes an asset retirement cost by increasing the carrying amount of the related asset by the same amount as the liability. In periods subsequent to the initial measurement, the Company is required to recognize changes in the liability resulting from the passage of time (accretion) or due to revisions to either timing or the amount of the originally estimated cash flows to settle the conditional ARO.lease term.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
PensionAROs are initially recognized when the legal obligation to retire an asset has been incurred and Postemployment Plansa reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations. Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets.
TheEstimating 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 AROs 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 has two noncontributory defined pension plans covering eligible employees, including officers. Benefits aredevelops possible retirement scenarios and assign probabilities based on each employee’s yearsmanagement’s reasonable judgment and knowledge of service and compensation. The Company’s funding policy isindustry practice. Accordingly, AROs are subject to contribute annually to these plans at least the minimum amount required under 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 made a discretionary contribution of $30 million during the first quarter of fiscal 2016 to improve the funded status of the pension plans based on the current actuarial assumptions, which included the adoption of the most recent mortality table. The Company made no discretionary contributions to the pension plans in fiscal 2017 and 2015.
The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds. The Company contributed $6 million, $3.2 million and $5.7 million in aggregate to these plans in fiscal 2017, 2016 and 2015, respectively.
See Note 11. Employee Benefit Plans, for a more detailed description of the Company’s pension and postemployment plans.change.
Accumulated Other Comprehensive Income
The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects, as of September 30:
|
| | | | | | | | | | | | | | | |
| (Thousands) | Unrealized gain (loss) on available for sale securities | Net unrealized gain (loss) on derivatives | Adjustment to postemployment benefit obligation | Total |
| Balance as of September 30, 2015 | $ | 6,385 |
| | $ | — |
| | $ | (15,779 | ) | | $ | (9,394 | ) |
| Other comprehensive income, net of tax | | | | | | | |
| Other comprehensive (loss), before reclassifications, net of tax of $1,499, $10, $3,164, $4,673 | (2,187 | ) | | (17 | ) | | (4,600 | ) | | (6,804 | ) |
| Amounts reclassified from accumulated other comprehensive income, net of tax of $0, $(10), $(698), $(708) | — |
| | 17 |
| (1) | 1,026 |
| (2) | 1,043 |
|
| Net current-period other comprehensive (loss), net of tax of $1,499, $0, $2,466, $3,965 | (2,187 | ) | | — |
| | (3,574 | ) | | (5,761 | ) |
| Balance at September 30, 2016 | $ | 4,198 |
| | $ | — |
| | $ | (19,353 | ) | | $ | (15,155 | ) |
| Other comprehensive income, net of tax | | | | | | | |
| Other comprehensive income, before reclassifications, net of tax of $(6,593), $0, $(2,619), $(9,212) | 10,019 |
| | — |
| | 3,783 |
| | 13,802 |
|
| Amounts reclassified from accumulated other comprehensive (loss) income, net of tax of $2,192, $0, $(868), $1,324 | (3,173 | ) | | — |
| (1) | 1,270 |
| (2) | (1,903 | ) |
| Net current-period other comprehensive income, net of tax of $(4,401), $0, $(3,487), $(7,888) | 6,846 |
| | — |
| | 5,053 |
| | 11,899 |
|
| Balance at September 30, 2017 | $ | 11,044 |
| | $ | — |
| | $ | (14,300 | ) | | $ | (3,256 | ) |
|
| | | | | | | | | | | |
| (Thousands) | Unrealized gain (loss) on available for sale securities | Adjustment to postemployment benefit obligation | Total |
| Balance as of September 30, 2016 | $ | 4,198 |
| | $ | (19,353 | ) | | $ | (15,155 | ) |
| Other comprehensive income, net of tax | | | | | |
| Other comprehensive income, before reclassifications, net of tax of $(6,593), $(2,619), $(9,212) | 10,019 |
| | 3,783 |
| | 13,802 |
|
| Amounts reclassified from accumulated other comprehensive (loss) income, net of tax of $2,192, $(868), $1,324 | (3,173 | ) | | 1,270 |
| (1) | (1,903 | ) |
| Net current-period other comprehensive income, net of tax of $(4,401), $(3,487), $(7,888) | 6,846 |
| | 5,053 |
| | 11,899 |
|
| Balance at September 30, 2017 | $ | 11,044 |
| | $ | (14,300 | ) | | $ | (3,256 | ) |
| Other comprehensive income, net of tax | | | | | |
| Other comprehensive (loss) income, before reclassifications, net of tax of $6,973, $(125), $6,848 | (19,245 | ) | | 464 |
| | (18,781 | ) |
| Amounts reclassified from accumulated other comprehensive income, net of tax of $(858), $(448), $(1,306) | 11,647 |
| | 1,056 |
| (1) | 12,703 |
|
| Net current-period other comprehensive (loss) income, net of tax of $6,115, $(573), $5,542 | (7,598 | ) | | 1,520 |
| | (6,078 | ) |
Reclassifications of certain income tax effects to retained earnings (2)
| — |
| | (3,276 | ) | | (3,276 | ) |
| Balance at September 30, 2018 | $ | 3,446 |
| | $ | (16,056 | ) | | $ | (12,610 | ) |
| |
| (1) | Consists of realized losses related to foreign currency derivatives, which are reclassified to gas purchases on the Consolidated Statements of Operations. |
| |
(2) | Included in the computation of net periodic pension cost, a component of O&M expense on the Consolidated Statements of Operations. For more details, see Note 11.10. Employee Benefit Plans. |
| |
| (2) | Due to the adoption of ASU No. 2018-02, an amendment to ASC 740, Income Taxes. See Note 2. Summary of Significant Accounting Policies- Recently Adopted Updates to the Accounting Standards Codification section for more details. |
Foreign Currency Transactions
Energy Services’The market area of Energy Services includes Canadian delivery points and as a result, Energy Services incurs certain natural gas commodity costs and demand fees denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of gas purchases on the Consolidated Statements of OperationsOperations. Gains and were not material duringlosses recognized for the fiscal years ended September 30, 2018, 2017 and 2016, and 2015.are considered immaterial.
Reclassification
Certain prior period amounts related to the amortization of acquired wholesale energy contracts on the Consolidated Statements of Cash Flows and in the deferred tax table in Note 12. Income Taxes for the fiscal year ended September 30, 2017, were reclassified to conform to the current period presentation.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Recently Adopted Updates to the Accounting Standards Codification
Inventory
In July 2015, the FASB issued ASU No. 2015-11, an amendment to ASC 330, Inventory, which requires entities to measure most inventory “at the lower of cost or net realizable value,” thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. The Company adopted the new guidance in the first quarter of fiscal 2018 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.
Reporting Comprehensive Income
In February 2018, the FASB issued ASU No. 2018-02, an amendment to ASC 220, Income Statement - Reporting Comprehensive Income, which allows for the reclassification from accumulated other comprehensive income to retained earnings for the disproportionate tax effects of the Tax Act. The Company early adopted this guidance in the fourth quarter of fiscal 2018 and reclassified on a prospective basis only, $3.3 million from accumulated other comprehensive income to retained earnings. This did not materially impact the Company’s financial position, results of operations or cash flows.
Tax
In March 2018, the FASB issued ASU No. 2018-05, an amendment to ASC 740, Income Taxes, which provides relief to entities in their calculation of the effects of the Tax Act by allowing them to record provisional amounts for certain income tax effects to address circumstances in which an entity does not have the necessary information available, prepared or analyzed to complete the accounting. These provisional amounts are subject to change as information and assumptions are updated throughout the measurement period, which may not extend beyond one year from the enactment date. The new guidance was effective immediately upon issuance, and the Company adopted the new guidance in the second quarter of fiscal 2018 and applied the new provision on a prospective basis.
Other Recent Updates to the Accounting Standards Codification
Revenue
In May 2014, the FASB issued ASU No. 2014-09, and added ASC 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries, jurisdictions and capital markets. The Company adopted the new guidance on October 1, 2018, and will apply the new provisions on a modified retrospective basis.
Management established an implementation team to evaluate the impact on the Company’s financial position, results of operations and cash flows upon adoption of ASC 606. This implementation team reviewed the revenue streams of all of its subsidiaries and formed conclusions to determine if any system, process, controls and organizational changes are necessary upon adoption. The assessment of the impact of this guidance included reviewing the Company’s accounting policies under ASC 605 and identifying potential differences after the adoption of ASC 606. The Company concluded that its tariff-based sales of natural gas will be within the scope of the new guidance and it does not anticipate any modification to the pattern of revenue recognition from such sales. Revenues from derivative instruments such as those related to the Company’s SREC sales and natural gas purchases and sales will continue to be accounted for under ASC 815 and thus are outside the scope of ASC 606. Additionally, NJNG revenues generated by the CIP have been determined to be alternative revenue programs under ASC 980 and are also outside the scope of ASC 606 as they are deemed to be a contract with the regulator. The Company also evaluated its renewable asset PPA arrangements and does not anticipate any modification to the pattern of revenue recognition of the related electricity, capacity and REC sales. Revenues from RECs sold as part of a bundled arrangement will be recognized in the same period as the related generation, consistent with current practice.
The Company has completed its evaluation of its revenue streams, and based on the assessment performed, has concluded that the new guidance will not have a material impact on its financial position, results of operations or cash flows upon adoption. Additionally, the Company did not implement significant changes to its business processes, systems or internal controls over financial reporting upon adoption. ASC 606 requires expanded disclosures, including the disclosure of performance obligations, disaggregated revenues and contract balances, which the Company will include in its financial statements beginning in the first quarter of fiscal 2019.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Financial Instruments
In January 2016, the FASB issued ASU No. 2016-01, an amendment to ASC 825, Financial Instruments, to address certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certain fair value changes for financial liabilities measured at fair value. It also simplifies the impairment assessment of equity investments without a readily determinable fair value by requiring a qualitative assessment. The guidance is effective for the Company beginning October 1, 2018. The amendment will be applied on a modified retrospective basis. The Company evaluated the amendment and noted that, upon adoption, subsequent changes to the fair value of the Company’s available for sale securities will be recorded in the Consolidated Statement of Operations as opposed to other comprehensive income. The Company will reclassify $3.4 million in accumulated other comprehensive income related to available for sale securities to the opening balance of retained earnings as of October 1, 2018. There will be no material impact to the Company’s financial position, results of operations or cash flows upon adoption.
In June 2016, the FASB issued ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. An entity will apply the amendment through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.
Leases
In February 2016, the FASB issued ASU No. 2016-02, an amendment to ASC 842, Leases, which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption.
In January 2018, the FASB issued ASU No. 2018-01, a further amendment to ASC 842, Leases, which was introduced by ASU No. 2016-02, as discussed above. This update provides an optional practical expedient that allows companies to not evaluate existing or expired land easements that were not previously accounted for under Topic 840 as leases. The Company expects to elect this practical expedient upon adoption. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted.
In July 2018, the FASB issued ASU No. 2018-11, which provides an optional transition method to ASC 842 that allows the Company to recognize a cumulative effect adjustment to the opening balance of retained earnings in the period of adoption. At this time, the Company does not plan to early adopt the new guidance and expects to transition on a modified retrospective basis. While the Company is currently evaluating the full impact of the standard and its related updates, it expects to recognize additional assets and liabilities arising from current operating leases to its financial position upon adoption. Current operating leases primarily consist of office and land leases related to the Company’s solar and wind assets.
Statement of Cash Flows
In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company beginning October 1, 2018. The amendment will be applied on a retrospective basis and the Company does not expect any material impacts to its statement of cash flows.
In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its statement of cash flows.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Intangibles
In August 2018, the FASB issued ASU No. 2018-15, an amendment to ASC 350, Intangibles - Goodwill and Other, which aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective or retrospective basis.
Business Combinations
In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on the accounting framework that is applied to acquisitions.
Gains and Losses from the Derecognition of Nonfinancial Assets
In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company as of October 1, 2018 and will be applied retrospectively with a cumulative effect adjustment at the date of adoption. The Company had a deferred gain of $6.8 million related to nonfinancial assets on the balance sheet, which will be recognized under the new accounting guidance as a cumulative effect adjustment to the opening balance of retained earnings as of October 1, 2018.
Compensation - Retirement Benefits
In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The amendment establishes a practical expedient that permits entities to use their previously disclosed service and other costs in their pension and other postretirement benefit plan footnotes in the prior comparative periods as the estimation basis when applying the retrospective presentation of these costs in the income statement. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis for income statement presentation, and on a prospective basis for changes to capitalization of costs. The changes related to the costs that will be eligible for capitalization and based on the components of net periodic benefit costs during fiscal year 2018, will not have a material impact on the Company's financial position, results of operations or cash flows upon adoption
In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures, and adds new disclosure requirements identified as relevant. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a retrospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on the Company's disclosures upon adoption.
Stock CompensationStatement of Cash Flows
In June 2014,August 2016, the FASB issued ASU No. 2014-12,2016-15, an amendment to ASC 718,230, Compensation - Stock CompensationStatement of Cash Flows, which clarifiesaddresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the accounting for performance awards when the terms of the award provide that a performance target couldCompany beginning October 1, 2018. The amendment will be achieved after the requisite service period. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospectiveretrospective basis which didand the Company does not impactexpect any material impacts to its financial position, resultsstatement of operations or cash flows upon adoption.flows.
Consolidation
In February 2015,November 2016, the FASB issued ASU No. 2015-02,2016-18, an amendment to ASC 810,230, ConsolidationStatement of Cash Flows, which changes the consolidation analysis required under GAAP and reevaluates whether limited partnerships and similar entities must be consolidated. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.
Interest
In April 2015, the FASB issued ASU No. 2015-03, an amendment to ASC 835, Interest - Imputation of Interest, which simplifies the presentation of debt issuance costs by requiring themrequires that any amounts that are deemed to be presentedrestricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the balance sheet as a deduction fromcash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the carrying amountstatement of cash flows. The guidance is effective for the liability. The amendment does not affect the recognition and measurement guidance for debt issuance costs. In August 2015, the FASB issued ASU No. 2015-15, which clarified that the amendment contained within ASU No. 2015-03 does not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis.
In addition, the following amounts on the Consolidated Balance Sheets have been adjusted, retrospectively, as of September 30, 2016.
|
| | | | | | | | | | | |
| (Thousands) | As Previously Reported | | Effect of Change | | As Adjusted |
| Assets | | | | | |
| Other noncurrent assets | $ | 68,708 |
| | $ | (8,512 | ) | | $ | 60,196 |
|
| Total noncurrent assets | $ | 712,166 |
| | $ | (8,512 | ) | | $ | 703,654 |
|
| Total assets | $ | 3,727,082 |
| | $ | (8,512 | ) | | $ | 3,718,570 |
|
| Capitalization and Liabilities | | | | | |
| Long-term debt | $ | 1,063,550 |
| | $ | (8,512 | ) | | $ | 1,055,038 |
|
| Total capitalization | $ | 2,230,141 |
| | $ | (8,512 | ) | | $ | 2,221,629 |
|
| Total capitalization and liabilities | $ | 3,727,082 |
| | $ | (8,512 | ) | | $ | 3,718,570 |
|
Intangibles
In April 2015, the FASB issued ASU No. 2015-05, an amendment to ASC 350, Intangibles - Goodwill and Other - Internal-Use Software, which clarifies the accounting for fees in a cloud computing arrangement. The amendment provides guidance on how an entity should evaluate the accounting for fees paid in a cloud computing arrangement to determine whether an arrangement includes the sale or license of software. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.
Other Recent Updates to the Accounting Standards Codification
Revenue
In May 2014, the FASB issued ASU No. 2014-09, and added Topic 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries, jurisdictions and capital markets. In August 2015, the FASB issued ASU No. 2015-14, which defers the implementation of the new guidance for one year. The new guidance will not be early adoptedbeginning October 1, 2018, and will be effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year. The Company continues to evaluate the provisions of ASC 606; however, basedapplied on a retrospective basis. Based on the review of customer contracts to date,Company's historical restricted cash balances, it isdoes not anticipating aexpect any material impactimpacts to its financial position, resultsstatement of operationscash flows.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
or cash flows upon adoption. The Company anticipates significant new disclosures as a result of the new standard and expects to transition to the new guidance using the modified retrospective approach. The Company is also monitoring industry specific developments that may have an impact on its financial position, results of operation and cash flows.
InventoryIntangibles
In July 2015,August 2018, the FASB issued ASU No. 2015-11,2018-15, an amendment to ASC 330,350, InventoryIntangibles - Goodwill and Other, which requires entitiesaligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to measure most inventory “at the lower of costdevelop or net realizable value,” thereby simplifying the current guidance under whichobtain internal-use software (and hosting arrangements that include an entity must measure inventory at the lower of cost or market.internal-use software license). The guidance is effective for the Company’s fiscal year ending September 30, 2018, and interim periods within that year.Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective or retrospective basis. The Company does not expect any impact on its financial position, results of operations and cash flows upon adoption.
Financial InstrumentsBusiness Combinations
In January 2016,2017, the FASB issued ASU No. 2016-01,2017-01, an amendment to ASC 825,805, Financial InstrumentsBusiness Combinations, clarifying the definition of a business in the ASC, which is intended to address certain aspectsreduce the complexity surrounding the assessment of the recognition, measurement, presentation and disclosure of financial instruments.a transaction as an asset acquisition or business combination. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certainamendment provides an initial fair value changes for financial liabilities measured at fair value. It also simplifiesscreen to reduce the impairment assessmentnumber of equity investments withouttransactions that would fit the definition of a readily determinable fair value by requiringbusiness, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a qualitative assessment.business. The guidance is effective for the Company’s fiscal year ending September 30, 2019,Company beginning October 1, 2018, and interim periods within that year. Upon adoption, the amendment will be applied on a modified retrospectiveprospective basis. The amendment could potentially have material impacts on future transactions that the Company evaluatedmay enter into by altering the Company’s conclusion on the accounting framework that is applied to acquisitions.
Gains and Losses from the Derecognition of Nonfinancial Assets
In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and notedLosses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company as of October 1, 2018 and will be applied retrospectively with a cumulative effect adjustment at the date of adoption. The Company had a deferred gain of $6.8 million related to nonfinancial assets on the balance sheet, which will be recognized under the new accounting guidance as a cumulative effect adjustment to the opening balance of retained earnings as of October 1, 2018.
Compensation - Retirement Benefits
In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that upon adoption, subsequentonly the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The amendment establishes a practical expedient that permits entities to use their previously disclosed service and other costs in their pension and other postretirement benefit plan footnotes in the prior comparative periods as the estimation basis when applying the retrospective presentation of these costs in the income statement. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis for income statement presentation, and on a prospective basis for changes to capitalization of costs. The changes related to the fair value of the Company’s available for sale securitiescosts that will be recorded ineligible for capitalization and based on the Consolidated Statementcomponents of Operations as opposed to other comprehensive income. The Company doesnet periodic benefit costs during fiscal year 2018, will not expect any otherhave a material impacts to itsimpact on the Company's financial position, results of operations or cash flows upon adoption.adoption
In June 2016,August 2018, the FASB issued ASU No. 2016-13,2018-14, an amendment to ASC 326,715, Financial InstrumentsCompensation - Credit Losses, Retirement Benefits, which changesremoves disclosures that no longer are considered cost-beneficial, clarifies the impairment model forspecific requirements of certain financial assets that have a contractual right to receive cash, including tradedisclosures, and loan receivables. Theadds new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred.disclosure requirements identified as relevant. The guidance is effective for the Company’s fiscal year ending September 30, 2021, and interim periods within that year,Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a retrospective basis. The Company is currently evaluatingcontinuing to evaluate the amendment to fully understand the impact on its financial position, results of operations and cash flowsthe Company's disclosures upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.adoption.
Leases
In February 2016, the FASB issued ASU No. 2016-02, an amendment to ASC 842, Leases, which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption. The guidance is effective for the Company’s fiscal year ending September 30, 2020, and interim periods within that year, with early adoption permitted. The Company continues to evaluate the provisions of ASC 842 and is actively monitoring industry specific developments including the exposure draft issued by the FASB that would introduce a land easement practical expedient to ASC 842. At this time the Company does not plan to early adopt the new guidance and expects to elect the practical expedient package in the new guidance during transition.
Statement of Cash Flows
In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, theCompany beginning October 1, 2018. The amendment will be applied on a retrospective basis. Thebasis and the Company does not expect any material impacts to its statement of cash flows upon adoption.flows.
In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company’s fiscal year ending September 30, 2019, with early adoption permitted. Upon adoption, the amendmentCompany beginning October 1, 2018, and will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its statement of cash flows.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
restricted cash balances, it does not expect any material impactsIntangibles
In August 2018, the FASB issued ASU No. 2018-15, an amendment to its financial position, results of operationsASC 350, Intangibles - Goodwill and Other, which aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or cash flows upon adoption.obtain internal-use software (and hosting arrangements that include an internal-use software license). The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective or retrospective basis.
Business Combinations
In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company’s fiscal year ending September 30, 2019,Company beginning October 1, 2018, and interim periods within that year, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on whatthe accounting to applyframework that is applied to acquisitions.
Gains and Losses from the Derecognition of Nonfinancial Assets
In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company’s fiscal year ending September 30, 2019,Company as of October 1, 2018 and interim periods within that year with early adoption permitted. ASU No. 2017-05 maywill be applied retrospectively for all periods presented or retrospectively with a cumulative-effectcumulative effect adjustment at the date of adoption. The Company has determined that to the extenthad a deferred gain existsof $6.8 million related to nonfinancial assets on the balance sheet, upon adoption, it wouldwhich will be recognized under the new accounting guidance as a cumulative effect adjustment to the opening balance of retained earnings for the earliest period presented.as of October 1, 2018.
Compensation - Retirement Benefits
In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The amendment establishes a practical expedient that permits entities to use their previously disclosed service and other costs in their pension and other postretirement benefit plan footnotes in the prior comparative periods as the estimation basis when applying the retrospective presentation of these costs in the income statement. The guidance is effective for the Company’s fiscal year ending September 30, 2019,Company beginning October 1, 2018, and interim periods within that year, with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis for income statement presentation, and on a prospective basis for changes to capitalization of costs. The changes related to the costs that will be eligible for capitalization and based on the components of net periodic benefit costs during fiscal year 2018, will not have a material impact on the Company's financial position, results of operations or cash flows upon adoption
In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures, and adds new disclosure requirements identified as relevant. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a prospectiveretrospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on its financial position, results of operations and cash flowsthe Company's disclosures upon adoption. The Company is also monitoring industry specific developments on the new guidance to determine the appropriate treatment of these changes in a rate regulated environment.
Stock Compensation
In May 2017, the FASB issued ASU No. 2017-09, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for changes to the terms or conditions of share-based payments. The guidance is effective for the Company’s fiscal year ending September 30, 2019,Company beginning October 1, 2018, and interim periods within that year, with early adoption permitted. Upon adoption, the amendments will be applied prospectively to awards modified on or after the adoption date. There was no material impact to the Company's financial position, results of operations or cash flows upon adoption.
In June 2018, the FASB issued ASU No. 2018-07, an amendment to ASC 718, Compensation - Stock Compensation, which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from non-employees. The guidance is effective for the Company beginning October 1, 2019, with early adoption permitted. The Company is currently evaluating the amendments to understandimpact of the impactamendment on itsthe Company’s financial position, results of operations and cash flows upon adoption.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Derivatives and Hedging
In August 2017, the FASB issued ASU No. 2017-12, an amendment to ASC 815, Derivatives and Hedging, which is intended to make targeted improvements to the accounting for hedging activities by better aligning an entity’s risk management activities and financial reporting for hedging relationships. These amendments modify the accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Additionally, the amendments are intended to simplify the application of the hedge accounting guidance and provide relief to companies by easing certain hedge documentation requirements. The guidance is effective for the Company’s fiscal year ending September 30, 2020, and interim periods within that year,Company beginning October 1, 2019, with early adoption permitted. Upon adoption, the transition requirements and elections will be applied to hedging relationships existing on the date of adoption. The Company does not currently apply hedge accounting to any of its risk management activities and thus does not expect the amendments to have any impact on its financial position, results of operations and cash flows upon adoption.
New Jersey Resources Corporation
Part IIFair Value
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
3. ACQUISITION
On July 27, 2017, NJR, through its wholly owned subsidiary NJRRS, signedIn August 2018, the FASB issued ASU No. 2018-13, an asset purchase agreement with Talenamendment to acquireASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of their retailfair value measurements. Disclosure requirements removed include the amount of and wholesale natural gas energy contract assets. The acquisition included sales agreements with large commercialreasons for transfers between Level 1 and industrial retail customers, pipeline and storage capacity agreements on various pipelines, and various wholesale transportation contracts. The final purchase price totaled $55.7 million upon satisfactionLevel 2 of certain conditions as set forth in the asset purchase agreement.
The following table summarizes the purchase price allocation for the fair value hierarchy, the policy for timing of transfers between levels and the assets acquired and liabilities assumed as of July 27, 2017:
|
| | | |
(Thousands) | Estimated Fair Value |
| Total purchase price consideration transferred | $ | 55,661 |
|
| Identifiable assets acquired | |
Wholesale energy contracts (1) | $ | 41,846 |
|
Retail energy contracts (2) | 13,815 |
|
| Net assets acquired | $ | 55,661 |
|
| |
(1) | Wholesale energy contracts are presented within Intangible assets, net on the Consolidated Balance Sheets. |
| |
(2) | Retail energy contracts are presented within the Derivatives, at fair value line items on the Consolidated Balance Sheets. |
The purchase price equaled the estimatedvaluation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the net assets acquireddate when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and therefore, no goodwill or bargain purchase was recorded as of September 30, 2017. Identifiable assets were recorded at their estimatedlosses for the period in other comprehensive income for recurring Level 3 fair value as determined by managementmeasurements held and were based uponthe range and weighted average of significant estimates and assumptions that are judgmental in nature, includingunobservable inputs used to develop Level 3 fair value measurements. The guidance is effective for the projected amount and timingCompany beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective or retrospective basis depending on the specific amendments’ transition requirements. The Company is currently evaluating the amendments to understand the impact on its financial position, results of future cash flows, a discount rate reflecting risk inherent in the futureoperations, cash flows and future natural gas prices. During fiscal 2017,disclosures upon adoption and will apply the Company incurred approximately $300,000 in acquisition related transaction costs, which are recorded in operations and maintenance expense on the Consolidated Statements of Operations.
The useful lives of the acquired assets are based upon the terms of the contractual arrangements. The acquired wholesale energy contracts have useful lives ranging from 1 to 9 years, and the acquired retail energy contracts have useful lives ranging from 0 to 4 years. The acquisition date fair value of the wholesale contracts is presented as an intangible asset on the Consolidated Balance Sheet and is amortized based upon the pattern of expected future cash flows. The related amortization expense totaled $762,000 during fiscal 2017, and is included in gas purchases on the Consolidated Statements of Operations. The acquired retail contracts consist of natural gas physical forward sales agreements and therefore are subsequently measured and accounted for in accordance with ASC 815, new guidance.Derivatives and Hedging. Accordingly, the acquisition date fair value of the retail contracts is presented within the Derivatives, at fair value line items on the Consolidated Balance Sheets and is relieved in subsequent periods as the underlying physical forward contracts settle. During fiscal 2017, operating revenues of approximately $20.5 million, and operating income of approximately $281,000 attributable to the acquisition are included in the Consolidated Statements of Operations.
As the assets were acquired from a non-public company that did not prepare financial information for the specific assets involved in the transaction, historical financial information was impracticable to obtain. As a result, pro forma results for the acquired assets are not presented.
4.3. 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 componentscomponents: the commodity portion, which represents the wholesale cost of natural gas, including the cost for interstate pipeline capacity to transport the gas to NJNG’s service territory,territory; and the delivery portion, which represents the transportation of the commodity portion through NJNG’s 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Under EDECA, the BPU is required to audit the state’s energy utilities every two years. The primary purpose of the audit is to ensure that utilities and their affiliates offering unregulated retail services do not have an unfair competitive advantage over nonaffiliated providers of similar retail services. A combined competitive services and management audit of NJNG commenced in August 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,regulation; therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility capital investments based on the BPU’s approval. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets, and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.
NJNG’s recovery of costs is facilitated through its base rates, BGSS and other regulatory tariff riders. NJNG is required to make an annual filing to the BPU by June 1 of each year for review of its BGSS, CIP and other programs and related rates. Annual rate changes are requested to be effective at the beginning of the following fiscal year. The current base rate includes a weighted average cost of capital of 6.9 percent and a return on common equity of 9.75 percent. In addition, NJNG is permitted to request approval of certain rate or program changes on an interim basis. All rate and program changes are subject to proper notification and BPU review and approval.
In September 2016, the BPU approved NJNG's base rate case, effective October 2016, which included an increase in base rates in the amount of $45 million. The base rate increase includes a return on common equity of 9.75 percent, a common equity ratio of 52.5 percent and a depreciation rate of 2.4 percent. The approval also included the rate mechanism and five-year extension of SAFE II, rate recovery of NJ RISE capital investment costs through June 30, 2016, recovery of NJNG’s SAFE I, NGV and LNG capital investments and recovery of other costs previously deferred in regulatory assets.
Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are comprised of the following:
|
| | | | | | |
| (Thousands) | 2017 | 2016 |
| Regulatory assets-current | | |
| Conservation Incentive Program | $ | 17,669 |
| $ | 36,957 |
|
| New Jersey Clean Energy Program | 14,202 |
| 14,232 |
|
| Underrecovered gas costs | 9,910 |
| — |
|
| Derivatives at fair value, net | 9,010 |
| 3,097 |
|
| Total current regulatory assets | $ | 50,791 |
| $ | 54,286 |
|
| Regulatory assets-noncurrent | | |
| Environmental remediation costs: | | |
| Expended, net of recoveries | $ | 28,547 |
| $ | 19,595 |
|
| Liability for future expenditures | 149,000 |
| 172,000 |
|
| Deferred income taxes | 21,795 |
| 20,273 |
|
| Derivatives at fair value, net | — |
| 23,384 |
|
| SAVEGREEN | 16,302 |
| 25,208 |
|
| Postemployment and other benefit costs | 141,433 |
| 157,027 |
|
| Deferred Superstorm Sandy costs | 13,030 |
| 15,201 |
|
| Other noncurrent regulatory assets | 5,812 |
| 8,606 |
|
| Total noncurrent regulatory assets | $ | 375,919 |
| $ | 441,294 |
|
| Regulatory liability-current | | |
| Derivatives at fair value, net | 78 |
| — |
|
| Overrecovered gas costs | — |
| 9,469 |
|
| Total current regulatory liabilities | $ | 78 |
| $ | 9,469 |
|
| Regulatory liabilities-noncurrent | | |
| Cost of removal obligation | $ | 7,902 |
| $ | 30,549 |
|
| New Jersey Clean Energy Program | 5,795 |
| 10,657 |
|
| Other noncurrent regulatory liabilities | 664 |
| 205 |
|
| Derivatives at fair value, net | 146 |
| — |
|
| Total noncurrent regulatory liabilities | $ | 14,507 |
| $ | 41,411 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are composed of the following:
|
| | | | | | |
| (Thousands) | 2018 | 2017 |
| Regulatory assets-current | | |
| New Jersey Clean Energy Program | $ | 14,052 |
| $ | 14,202 |
|
| Underrecovered gas costs | 4,137 |
| 9,910 |
|
| Derivatives at fair value, net | 108 |
| 9,010 |
|
| Conservation Incentive Program | — |
| 17,669 |
|
| Total current regulatory assets | $ | 18,297 |
| $ | 50,791 |
|
| Regulatory assets-noncurrent | | |
| Environmental remediation costs: | | |
| Expended, net of recoveries | $ | 33,017 |
| $ | 28,547 |
|
| Liability for future expenditures | 130,800 |
| 149,000 |
|
| Deferred income taxes | 17,225 |
| 21,795 |
|
| SAVEGREEN | 8,636 |
| 16,302 |
|
| Postemployment and other benefit costs | 136,716 |
| 141,433 |
|
| Deferred storm damage costs | 10,858 |
| 13,030 |
|
| Cost of removal | 22,339 |
| — |
|
| Other noncurrent regulatory assets | 9,001 |
| 5,812 |
|
| Total noncurrent regulatory assets | $ | 368,592 |
| $ | 375,919 |
|
| Regulatory liability-current | | |
| Conservation Incentive Program | $ | 6,994 |
| $ | — |
|
| Derivatives at fair value, net | 1,191 |
| 78 |
|
| Total current regulatory liabilities | $ | 8,185 |
| $ | 78 |
|
| Regulatory liabilities-noncurrent | | |
Tax Act impact (1) | $ | 205,410 |
| $ | — |
|
| Cost of removal | — |
| 7,902 |
|
| New Jersey Clean Energy Program | 1,902 |
| 5,795 |
|
| Other noncurrent regulatory liabilities | 1,827 |
| 810 |
|
| Total noncurrent regulatory liabilities | $ | 209,139 |
| $ | 14,507 |
|
| |
| (1) | Includes an adjustment related to the re-measurement of NJNG's net deferred tax liabilities to reflect the change in federal tax rates enacted in the Tax Act, which is net of sales tax collected from customers. For a more detailed discussion, see Note 12. Income Taxes. |
Recovery of regulatory assets is subject to BPU approval, and therefore, if there are any changes in regulatory positions that indicate recovery is not probable, the related cost would be charged to income in the period of such determination. The BPU’s decision and order approving NJNG’s new base rates resulted in no changes to the recovery of NJNG’s regulatory assets.
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 gross 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.
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 2018.2019. NJNG recovers the costs associated with its portion of the NJCEP obligation through its NJCEP rider.
Derivatives
Derivatives are utilized by NJNG to manage the price risk associatedrider, with its natural gas purchasing activities and to participate in certain BGSS incentive programs. The gains and losses associated with NJNG’s derivatives are recoverable through its BGSS, as noted above, without interest. See Note 5. Derivative Instruments.
Environmental Remediation Costs
NJNG is responsible for the cleanup of certain former gas manufacturing facilities. Actual expenditures are recovered from customers, with interest, over seven year rolling periods, through a RAC rate rider. Recovery for NJNG’s estimated future liability will be requested and/or recovered when actual expenditures are incurred. See Note 14. Commitments and Contingent Liabilities.
Deferred Income Taxes
In 1993, NJNG adopted the provisions of ASC 740, Income Taxes, which changed the method used to determine deferred tax assets and liabilities. Upon adoption, 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, as approved by the BPU, over a two to 10-year period depending upon the specific program incentive.
Postemployment and Other Benefit Costs
Postemployment and Other Benefit Costs represents NJNG’s underfunded postemployment benefit obligations that the Company began recognizing in fiscal 2006, as a result of changes in the accounting provisions of ASC 715, Compensation and Benefits, as well as a $2.4 million 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. In the September 2016 base rate case decision and order, the BPU approved the recovery of the tax charge over a seven-year amortization period. See Note 11. Employee Benefit Plans.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Deferred Superstorm Sandy Costs
In October 2012, portions of NJNG’s distribution system incurred significant damage as a result of Superstorm Sandy. NJNG filed a petition with the BPU in November 2012 requesting deferred accounting for uninsured incremental O&M costs associated with its restoration efforts, which was approved in May 2013. In October 2014, the BPU approved, as prudent and reasonable, the deferred O&M storm costs. The deferred Superstorm Sandy costs were approved for recovery through NJNG’s new base rates effective October 2016, over a seven-year amortization period.
Other Regulatory Assets
Other regulatory assets consists primarily of deferred costs associated with certain components of NJNG’s SBC, as discussed further below, 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, subject to BPU review and approval. Through September 30, 2016, NJNG was limited to recording a regulatory asset associated with PIM that did not exceed $700,000 per year. In addition, to the extent that project costs were lower than the approved PIM annual expense of $1.4 million, NJNG recorded a regulatory liability to be refunded as a credit to customers’ gas costs when the net cumulative liability exceeded $1 million. As of September 30, 2017, NJNG recorded $3.8 million of PIM in other regulatory assets. The deferred PIM costs were approved for recovery through NJNG’s new base rates effective October 2016, over a seven-year amortization period. As of October 1, 2016, NJNG will no longer defer costs associated with PIM.
Over and Underrecovered Gas Costs
NJNG recovers its cost of gas through the BGSS rate component of its customers’ bills. NJNG’s cost of 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 gas costs represent a regulatory liability that generally occurs when NJNG’s BGSS rates are higher than actual costs and requests approval to be returned to customers including interest, when applicable, in accordance with NJNG’s approved BGSS tariff. Conversely, underrecovered 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Derivatives
Derivatives are utilized by NJNG to manage the price risk associated with its natural gas purchasing activities and to participate in certain BGSS incentive programs. The gains and losses associated with NJNG’s derivatives are recoverable through its BGSS, as noted above, without interest. See Note 4. Derivative Instruments.
Conservation Incentive Program
The CIP permits NJNG to recover utility gross margin variations related to customer usage resulting from customer conservation efforts and mitigates the impact of weather on its margin. Such utility gross margin variations are recovered in the year following the end of the CIP usage year, without interest, and are subject to additional conditions, including an earnings test, a revenue test and an evaluation of BGSS related savings. This program has no expiration date.
Environmental Remediation Costs
NJNG is responsible for the cleanup of certain former gas manufacturing facilities. Actual expenditures are recovered from customers, with interest, over seven-year rolling periods, through a RAC rate rider. Recovery for NJNG’s estimated future liability will be requested and/or recovered when actual expenditures are incurred. See Note 13. 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, without interest, as approved by the BPU, over a two- to 10-year period depending upon the specific program incentive.
Postemployment and Other Benefit Costs
Postemployment and Other Benefit Costs represents NJNG’s underfunded postemployment benefit obligations, as well as a fiscal 2010 tax charge resulting from a change in the deductibility of federal subsidies associated with Medicare Part D, both of which are deferred as regulatory assets and are recoverable, without interest, in base rates. The BPU approved the recovery of the tax charge through NJNG’s base rates effective October 2016 over a seven-year amortization period. See Note 10. Employee Benefit Plans.
Deferred Storm Damage Costs
Portions of NJNG’s distribution system incurred significant damage as a result of Superstorm Sandy in October 2012. NJNG deferred the uninsured incremental O&M costs associated with its restoration efforts, which were approved for recovery by the BPU through NJNG’s base rates, without interest, effective October 2016 over a seven-year amortization period.
Cost of Removal Obligation
NJNG accrues and collects for cost of removal in base rates on its utility property, without interest. NJNG’sThese 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 in docket number GR15111304 dated September 23, 2016. 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 representsdepending on whether actual cost of removal is still subject to collection or amounts overcollected will be refunded back to customers. NJNG’s prior regulatory liability represented customer collections in excess of actual expenditures, which the Company will returnreturned to customers as a reduction to depreciation expense until itexpense.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Other Regulatory Assets
Other regulatory assets consist primarily of deferred costs associated with certain components of NJNG’s SBC, as discussed further in the regulatory proceedings section, and NJNG’s compliance with federal- and state-mandated PIM provisions. NJNG’s related costs to maintain the operational integrity of its distribution and transmission main are recoverable, without interest, subject to BPU review and approval. As of September 30, 2018, NJNG recorded $3.2 million of PIM in other regulatory assets, which is depleted.being recovered through base rates over a seven-year amortization period effective October 2016.
The Tax Act
On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. As a result, NJNG recorded a regulatory liability, which included the revaluation of its deferred income taxes and the accounting of the income tax effects on the revaluation. The revaluation was based on certain assumptions and estimations NJNG made with respect to its deferred taxes, as well as the effects from the Tax Act, and as such is subject to change if and when assumptions are updated. See Note 12. Income Taxes for a more detailed discussion on the Tax Act.
On January 31, 2018, the BPU issued an Order which directed New Jersey utilities to submit filings to the BPU by March 2, 2018, to propose the prospective change in base rates as a result of the Tax Act to be effective April 1, 2018, the method to return to customers the overcollection of taxes in base rates from January 1, 2018, through March 31, 2018 and an outline of the method by which the excess deferred taxes would be returned to customers. The excess deferred taxes are primarily related to timing differences associated with utility plant depreciation and are subject to IRS normalization rules, which require amortization over the remaining life of the utility plant.
On March 1, 2018, NJNG submitted its required filing to the BPU proposing a $19.7 million base rate reduction and customer refunds of approximately $31 million, which is inclusive of state sales tax and interest at the Company’s short-term debt rate as specified in the Company’s last base rate case. On March 26, 2018, the BPU approved, on an interim basis, the $19.7 million rate reduction, effective April 1, 2018. On May 22, 2018, the BPU approved final rates and also customer refunds of the $31 million. These credits were returned to customer accounts in June 2018.
The following is a description of certain regulatory proceedings during fiscal 20162017 and 2017:2018:
BGSS and CIP
BGSS rates are normally revised on an annual basis. In addition, to manage the fluctuations in wholesale natural gas costs, NJNG has the ability to make two interim filings during each fiscal year to increase residential and small commercial customer BGSS rates on a self-implementing and provisional basis. NJNG is also permitted to refund or credit back a portion of the commodity costs to customers at any time given five daysdays’ 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:
June 2015 BGSS/CIP filing — In February 2016, the BPU approved NJNG’s proposal to continue its existing BGSS rate and to increase its CIP rates resulting in a $1.1 million annual recovery increase, effective October 2015. NJNG also provided bill credits to residential and small commercial customers from November 2015 through February 2016, as a result of the decline in the wholesale price of natural gas, which totaled $61.6 million.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
June 2016 BGSS/CIP filing — In September 2016, the BPU approved NJNG'sNJNG’s filing to increase its CIP rates resulting in a $43.9 million annual recovery increase and to decrease its annual BGSS rate for residential and small commercial customers resulting in a $22.6 million annual recovery decrease effective October 2016. This petition also included proposed bill credits to residential and small commercial customers during the months of November 2016 through February 2017, as a result of a decline in the wholesale price of natural gas. In September 2016, NJNG notified the BPU that the estimated bill credits would be approximately $48 million; however, customer usage was lower due to warmer weather during winter months and therefore, aA total of $42 million in bill credits were issued during fiscal 2017.
June 2017 BGSS/CIP filing — On September 22, 2017,In March 2018, the BPU provisionally approved NJNG'sNJNG’s petition on a final basis to maintain its BGSS rate for residential and small commercial customers, increase its balancing charge rate, which will resultresulted in a $3.7 million increase to the annual revenues credited to BGSS, and decrease its CIP rates, which will resultresulted in a $16.2 million annual recovery decrease that was effective October 2017.
May 2018 BGSS/CIP filing — On September 17, 2018, the BPU provisionally approved NJNG’s annual petition to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well as changes to the CIP rates, which will result in a $30.9 million annual recovery decrease effective October 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 and the FRM program (through October 2015).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. In October 2015, the BPU issued an order approving the continuation of the BGSS Incentive Programs with modification to the storage incentive program, beginning with the 2015 storage injection period, and termination of the FRM Program, effective November 2015.
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 energy efficiency upgrades to promote energy efficiency incentives 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 twothree- to 10-year period through a tariff rider mechanism.
As of September 30, 2017,2018, the BPU has approved total SAVEGREEN investments of approximately $219.3$354.3 million, including $135 million that was approved on September 17, 2018, for a continuation of which, $149.7existing EE programs and the implementation of new programs through December 2021.
SAVEGREEN investments and costs are filed with the BPU on an annual basis. Since inception, $162 million in grants, rebates and loans have been provided to customers, with a total annual recovery of approximately $20$16.1 million. The recovery includes a weighted average cost of capital on the unamortized balance that ranges from 6.69 percent to 7.76 percent, with a return on equity of 9.75 percent to 7.7610.3 percent, with a return on equity of 10.3 percent. SAVEGREEN investments and costs are filed with the BPU on an annual basis. In June 2016, the BPU approved NJNG's petition to extend its current program, which was set to expire on July 31, 2017, to December 31, 2018. In October 2016, the BPU approved NJNG's filing to maintain its existing recovery rate.respectively. On October 20, 2017, the BPU approved NJNG's filing to16, 2018, NJNG requested a decrease in its EE recovery rate reflecting costs incurred through September 30, 2018, which will result in an annual decrease of $3.9$8.8 million, anticipated to be effective NovemberJanuary 1, 2017.2019.
Societal Benefits Clause
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:
2015 SBC filings — In September 2015, the BPU approved the annual USF compliance filing decreasing the statewide USF rate, resulting in an annual $3.9 million decrease to USF recoveries, effective October 2015. In June 2016, the BPU approved NJNG's additional filing to recover remediation expenses incurred through June 30, 2015, increase the RAC with an annual recovery of $9.4 million and to decrease the NJCEP factor, effective July 9, 2016.
20162017 SBC filing — In September 2016, the BPU approved NJNG's annual USF compliance filing proposing to increase the statewide USF rate, resulting in a $1.3 million annual increase in USF recoveries, effective October 2016.
2017 SBC filing — On September 22, 2017, the BPU approved NJNG'sNJNG’s annual USF compliance filing to decrease the statewide USF rate, which will result in a $2.6 million annual decrease, effective October 1, 2017. On November 17, 2017, NJNG filed it'sJuly 25, 2018, the BPU approved NJNG's annual SBC applicationfiling requesting to recover remediation expenses incurred through June 30, 2017, a reduction in the RAC, which willresulted in an annual decrease the annual recovery to $7of $2.4 million, and to increase the NJCEP factor, which will result in an annual increase of $1.8 million, effective AprilSeptember 1, 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued) 2018 SBC filing — On September 17, 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which will result in a $1 million annual increase, effective October 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, an increase in the RAC, which will result in an annual increase of $1.4 million, and an increase to the NJCEP factor, which will result in an annual increase of approximately $1.9 million, effective April 1, 2019.
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 gas distribution system, including SAFE and NJ RISE.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
SAFE/NJ RISE
In October 2012, the BPU approved NJNG’s petition to implementThe SAFE I, investing up to $130 million, exclusive of AFUDC, over a four-year period to replaceprogram replaces portions of NJNG’s gas distribution unprotected steel, cast iron infrastructure and associated services to improve the safety and reliability of the gas distribution system.
SAFE I was approved to invest up to $130 million, exclusive of AFUDC, over a four-year period. The recovery of SAFE I capital investments and the corresponding rate mechanism and five-year extension of SAFE II were approved through NJNG’s base rate case effective October 2016. The estimated cost for SAFE II is approximatelywas approved to invest up to $200 million, excluding AFUDC, and related costs to be recovered areover a five-year period. NJNG will recover approximately $157.5 million.million through annual rate filings, with the remainder recovered through subsequent rate cases. As a condition of approval of the extension,program, NJNG is required to file a base rate case no later than November 2019.
In July 2014, the BPU approved NJ RISE which consists of six capital investment projects estimated to cost $102.5 million over a five-year period, excluding AFUDC, for gas distribution storm hardeningstorm-hardening and mitigation projects, along with incremental depreciation expense. In October 2015, the BPU approved a base rate increase to recover capital costs through July 2015, resulting in a $390,000 annual recovery increase, effective November 2015, and earnedNJ RISE includes a weighted average cost of capital ofthat ranges from 6.74 percent includingto 6.9 percent and a return on equity of 9.75 percent.
NJ RISE investments through June 30, 2016, were approved for recovery through NJNG’s new base rates effective October 2016. Requests for recovery of future NJ RISE capital costs will occur in conjunction with SAFE II, commencing with the rate recovery filing that was submitted in March 2017, with a weighted cost of capital of 6.9 percent, including a return on equity of 9.75 percent.II.
On March 30,In September 2017, NJNG filed itsthe BPU approved NJNG’s annual petition with the BPU requesting a base rate increase for the recovery of NJ RISE and SAFE II capital investment costs related to the period ending June 30, 2017, based on estimates, pursuant to the September 2016 base rate case. On July 20, 2017, NJNG filedwith an update to this petition with actuals, requesting a $4.1 million annual increase in recoveries, which was approved by the BPU,of $4.1 million effective October 1, 2017.
NGV refueling stations
In June 2012, On September 17, 2018, the BPU approved NJNG’s petition requesting a pilot programbase rate increase of $6.8 million annually for NJNG to invest up to $10 million to build NGV refueling stations. NJNG has opened all threethe recovery of its NGV stationsSAFE II and NJ RISE capital investment costs related to the public and its capital investments were approved for recovery through the new base rates,12 months ending June 30, 2018 effective October 2016.1, 2018.
SRL
The SRL is an approximateapproximately 30-mile, 30-inch transmission main designed to support improved system integrity and reliability in the southern portion of NJNG’s service territory, estimated to cost between $180 million and $200$215 million. In January 2016, the BPU issued an order approving NJNG’s modified proposed SRL pipeline installation, operation and route selection. In March 2016, the BPU issued an order designating the SRL route and exempting the SRL from municipal land use ordinances, regulations, permits and license requirements. In February 2017, the New Jersey Department of Environmental Protection issued a permit authorizing construction of the SRL within the jurisdiction of the Coastal Area Facility Review Act as well as a Freshwater Wetlands permit. OnIn September 14, 2017, the NJ Pinelands Commission approved construction of NJNG’s SRL. All approvals and permits have been appealed by third parties.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Other Regulatory Initiatives
In May 2016, NJNG included a proposal in its base rate case to recover certain capital costs and incremental operation and maintenance costs related to a March 2016 BPU Order regarding new cyber security requirements. Costs associated with this initiative were approved for recovery through NJNG’s base rates effective October 2016.
In June 2016, NJNG’s liquefaction project became operational, allowing NJNG to convert natural gas into LNG and to fill NJNG’s existing LNG storage tanks. Costs for this project along with other plant upgrades were approximately $36.5 million. Costs associated with both initiativesthis initiative were approved for recovery through NJNG’s new base rates effective October 2016.
5.4. DERIVATIVE INSTRUMENTS
The Company is subject 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 may utilize foreign currency derivatives to hedge Canadian dollar denominated gas purchases and/or sales. Therefore, the Company’s primary underlying risks include commodity prices, interest rates and foreign currency. These contracts, with a few exceptions as described below, are accounted for as derivatives. 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 6.5. Fair Value.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Energy Services
Energy Services chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, and thereforeNPNS. The changes in the fair value of these derivatives are recorded as a component of gas purchases or operating revenues, as appropriate for Energy Services, on the Consolidated Statements of Operations as unrealized gains or (losses).losses. For Energy Services at settlement, realized gains and (losses)losses on all financial derivative instruments are recognized as a component of gas purchases and realized gains and (losses)losses on all physical derivatives follow the presentation of the related unrealized gains and (losses)losses as a component of either gas purchases or operating revenues.
Energy Services also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the U.S. dollar. Energy Services may utilize foreign currency derivatives to lock in the exchange rate 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 gas purchase agreements. For transactions occurring on or before December 31, 2015, Energy Services designates its foreign exchange contracts as cash flow hedges, and the effective portion of the hedges are recorded in OCI. Effective January 1, 2016, on a prospective basis, the Company has elected not to designate its foreign currency derivatives as accounting hedges. Accordingly, changes in the fair value of foreign exchange contracts entered into from January 1, 2016, are recognized in gas purchases on the Consolidated Statements of Operations.
As a result of Energy Services entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed 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 periodcurrent-period earnings.
Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. For transactions occurring on or before December 31, 2015, the Company elected NPNS accounting treatment on SREC forward and futures contracts. Effective January 1, 2016, on a prospective basis, Energy Services no longer elects NPNS accounting treatment on SREC contracts entered into from January 1, 2016, and 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. NPNS is a contract-by-contract election and, where it makes sense to do so, we can and may elect certain contracts to be normal.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 amortized in current periodcurrent-period earnings based on the current BPU BGSS factor and therm sales. Effective January 1, 2016, on a prospective basis, NJNG no longer elects NPNS accounting treatment on all of its physical commodity contracts entered into from January 1, 2016. However, since NPNS is a contract-by-contract election, where it makes sense to do so, weNJNG can and may elect certain contracts to be 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 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.
In an April 2014 BPU Order, NJNG received regulatory approval to enter into interest rate risk management transactions related to long-term debt securities. New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Home Services and Other
On June 1, 2015, NJNGJanuary 26, 2018, NJR entered into a treasury lock transaction to fix a benchmark treasuryvariable-for-fixed interest rate of 3.26 percent associated with a forecasted $125swap on its existing $100 million debt issuance expected in May 2018. This forecasted debt issuancevariable rate term loan, which fixed the variable rate at 2.84 percent. The swap will terminate on August 16, 2019, which coincides with the maturity of NJNG’s existing $125 million, 5.6 percent notes due May 15, 2018.the debt. The change in the fair value of NJNG’s treasury lock agreementthe interest rate swap is recorded as a component of regulatory assets or liabilitiesinterest expense on the Consolidated Balance Sheets since NJNG believes that the market value upon settlement will be recovered in future rates. Upon settlement, any gain or loss will be amortized into earnings over the lifeStatements of the future underlying debt issuance.Operations.
Fair Value of Derivatives
The following table reflects the fair value of the Company’s derivative assets and liabilities recognized on the Consolidated Balance Sheets as of September 30:
| | | | | Fair Value | | Fair Value |
| | | | 2017 | | 2016 | | | 2018 | | 2017 |
| (Thousands) | Balance Sheet Location | Asset Derivatives | Liability Derivatives | Asset Derivatives | Liability Derivatives | Balance Sheet Location | Asset Derivatives | Liability Derivatives | Asset Derivatives | Liability Derivatives |
| Derivatives not designated as hedging instruments: | Derivatives not designated as hedging instruments: | | | | | | | | | Derivatives not designated as hedging instruments: | | | | | | | | |
| NJNG: | | | | | | | | | |
| Natural Gas Distribution: | | | | | | | | | |
| Physical commodity contracts | Derivatives - current | | $ | 151 |
| | $ | 72 |
| | $ | 235 |
| | $ | 1,154 |
| Derivatives - current | | $ | 85 |
| | $ | 192 |
| | $ | 151 |
| | $ | 72 |
|
| Financial commodity contracts | Derivatives - current | | — |
| | 1,149 |
| | 805 |
| | 2,979 |
| Derivatives - current | | 94 |
| | — |
| | — |
| | 1,149 |
|
| | Derivatives - noncurrent | | — |
| | — |
| | 75 |
| | 386 |
| |
| Interest rate contracts | Derivatives - current | | — |
| | 8,467 |
| | — |
| | — |
| |
| Interest rate contracts | Derivatives - noncurrent | | — |
| | — |
| | — |
| | 23,073 |
| |
Interest rate contracts (1) | | Derivatives - current | | — |
| | — |
| | — |
| | 8,467 |
|
| Energy Services: | | | | | | | | | | | | | | | | |
| Physical commodity contracts | Derivatives - current | | 14,588 |
| | 16,589 |
| | 5,994 |
| | 11,660 |
| Derivatives - current | | 7,667 |
| | 18,158 |
| | 14,588 |
| | 16,589 |
|
| | Derivatives - noncurrent | | 7,127 |
| | 8,710 |
| | 3,987 |
| | 1,212 |
| Derivatives - noncurrent | | 3,930 |
| | 11,316 |
| | 7,127 |
| | 8,710 |
|
| Financial commodity contracts | Derivatives - current | | 15,302 |
| | 20,267 |
| | 22,929 |
| | 45,255 |
| Derivatives - current | | 19,169 |
| | 28,176 |
| | 15,302 |
| | 20,267 |
|
| | Derivatives - noncurrent | | 2,033 |
| | 2,620 |
| | 1,165 |
| | 581 |
| Derivatives - noncurrent | | 6,630 |
| | 11,548 |
| | 2,033 |
| | 2,620 |
|
| Foreign currency contracts | Derivatives - current | | 40 |
| | — |
| | 1 |
| | 32 |
| Derivatives - current | | — |
| | 126 |
| | 40 |
| | — |
|
| | Derivatives - noncurrent | | 4 |
| | — |
| | — |
| | — |
| Derivatives - noncurrent | | — |
| | 118 |
| | 4 |
| | — |
|
| Home Services and Other: | | | | | | | | | |
| Interest rate contracts | | Derivatives - current | | 381 |
| | — |
| | — |
| | — |
|
| Total fair value of derivatives | | $ | 39,245 |
| | $ | 57,874 |
| | $ | 35,191 |
| | $ | 86,332 |
| | $ | 37,956 |
| | $ | 69,634 |
| | $ | 39,245 |
| | $ | 57,874 |
|
| |
| (1) | Includes treasury lock which was settled in March 2018. See Note 8. Debt for more information. |
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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral as well asand the net amounts the Company could present on the Consolidated Balance Sheets but elects not to.
| | | (Thousands) | Amounts Presented in Balance Sheets (1) | Offsetting Derivative Instruments (2) | Financial Collateral Received/Pledged (3) | Net Amounts (4) | Amounts Presented in Balance Sheets (1) | Offsetting Derivative Instruments (2) | Financial Collateral Received/Pledged (3) | Net Amounts (4) |
| As of September 30, 2018: | | | | | | | | | |
| Derivative assets: | | | | | | | | | |
| Energy Services | | | | | | | | | |
| Physical commodity contracts | | | $ | 11,597 |
| | $ | (3,944 | ) | | $ | (200 | ) | | $ | 7,453 |
|
| Financial commodity contracts | | | 25,799 |
| | (18,775 | ) | | — |
| | 7,024 |
|
| Total Energy Services | | | $ | 37,396 |
| | $ | (22,719 | ) | | $ | (200 | ) | | $ | 14,477 |
|
| Natural Gas Distribution | | | | | | | | | |
| Physical commodity contracts | | | $ | 85 |
| | $ | (3 | ) | | $ | — |
| | $ | 82 |
|
| Financial commodity contracts | | | 94 |
| | — |
| | (94 | ) | | — |
|
| Total Natural Gas Distribution | | | $ | 179 |
| | $ | (3 | ) | | $ | (94 | ) | | $ | 82 |
|
| Home Services and Other | | | | | | | | | |
| Interest rate contracts | | | $ | 381 |
| | $ | — |
| | $ | — |
| | $ | 381 |
|
| Total Home Services and Other | | | $ | 381 |
| | $ | — |
| | $ | — |
| | $ | 381 |
|
| Derivative liabilities: | | | | | | | | | |
| Energy Services | | | | | | | | | |
| Physical commodity contracts | | | $ | 29,474 |
| | $ | (3,944 | ) | | $ | — |
| | $ | 25,530 |
|
| Financial commodity contracts | | | 39,724 |
| | (18,775 | ) | | (20,949 | ) | | — |
|
| Foreign currency contracts | | | 244 |
| | — |
| | — |
| | 244 |
|
| Total Energy Services | | | $ | 69,442 |
| | $ | (22,719 | ) | | $ | (20,949 | ) | | $ | 25,774 |
|
| Natural Gas Distribution | | | | | | | | | |
| Physical commodity contracts | | | $ | 192 |
| | $ | (3 | ) | | $ | — |
| | $ | 189 |
|
| Total Natural Gas Distribution | | | $ | 192 |
| | $ | (3 | ) | | $ | — |
| | $ | 189 |
|
| As of September 30, 2017: | | | | | | | | | | | | | | | | |
| Derivative assets: | | | | | | | | | | | | | | | | |
| Energy Services | | | | | | | | | | | | | | | | |
| Physical commodity contracts | | $ | 21,715 |
| | $ | (2,173 | ) | | $ | (200 | ) | | $ | 19,342 |
| | $ | 21,715 |
| | $ | (2,173 | ) | | $ | (200 | ) | | $ | 19,342 |
|
| Financial commodity contracts | | 17,335 |
| | (14,121 | ) | | — |
| | 3,214 |
| | 17,335 |
| | (14,121 | ) | | — |
| | 3,214 |
|
| Foreign currency contracts | | 44 |
| | — |
| | — |
| | 44 |
| | 44 |
| | — |
| | — |
| | 44 |
|
| Total Energy Services | | $ | 39,094 |
| | $ | (16,294 | ) | | $ | (200 | ) | | $ | 22,600 |
| | $ | 39,094 |
| | $ | (16,294 | ) | | $ | (200 | ) | | $ | 22,600 |
|
| NJNG | | | | | | | | | |
| Natural Gas Distribution | | | | | | | | | |
| Physical commodity contracts | | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
| | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
|
| Financial commodity contracts | | — |
| | — |
| | — |
| | — |
| |
| Interest rate contracts | | — |
| | — |
| | — |
| | — |
| |
| Total NJNG | | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
| |
| Total Natural Gas Distribution | | | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
|
| Derivative liabilities: | | | | | | | | | | | | | | | | |
| Energy Services | | | | | | | | | | | | | | | | |
| Physical commodity contracts | | $ | 25,299 |
| | $ | (2,173 | ) | | $ | — |
| | $ | 23,126 |
| | $ | 25,299 |
| | $ | (2,173 | ) | | $ | — |
| | $ | 23,126 |
|
| Financial commodity contracts | | 22,887 |
| | (14,121 | ) | | (8,766 | ) | | — |
| | 22,887 |
| | (14,121 | ) | | (8,766 | ) | | — |
|
| Foreign currency contracts | | — |
| | — |
| | — |
| | — |
| |
| Total Energy Services | | $ | 48,186 |
| | $ | (16,294 | ) | | $ | (8,766 | ) | | $ | 23,126 |
| | $ | 48,186 |
| | $ | (16,294 | ) | | $ | (8,766 | ) | | $ | 23,126 |
|
| NJNG | | | | | | | | | |
| Natural Gas Distribution | | | | | | | | | |
| Physical commodity contracts | | $ | 72 |
| | $ | (20 | ) | | $ | — |
| | $ | 52 |
| | $ | 72 |
| | $ | (20 | ) | | $ | — |
| | $ | 52 |
|
| Financial commodity contracts | | 1,149 |
| | — |
| | (1,149 | ) | | — |
| | 1,149 |
| | — |
| | (1,149 | ) | | — |
|
| Interest rate contracts | | 8,467 |
| | — |
| | — |
| | 8,467 |
| | 8,467 |
| | — |
| | — |
| | 8,467 |
|
| Total NJNG | | $ | 9,688 |
| | $ | (20 | ) | | $ | (1,149 | ) | | $ | 8,519 |
| |
| As of September 30, 2016: | | | | | | | | | |
| Derivative assets: | | | | | | | | | |
| Energy Services | | | | | | | | | |
| Physical commodity contracts | | $ | 9,981 |
| | $ | (2,837 | ) | | $ | (755 | ) | | $ | 6,389 |
| |
| Financial commodity contracts | | 24,094 |
| | (17,945 | ) | | (6,149 | ) | | — |
| |
| Foreign currency contracts | | 1 |
| | (1 | ) | | — |
| | — |
| |
| Total Energy Services | | $ | 34,076 |
| | $ | (20,783 | ) | | $ | (6,904 | ) | | $ | 6,389 |
| |
| NJNG | | | | | | | | | |
| Physical commodity contracts | | $ | 235 |
| | $ | (31 | ) | | $ | — |
| | $ | 204 |
| |
| Financial commodity contracts | | 880 |
| | (880 | ) | | — |
| | — |
| |
| Interest rate contracts | | — |
| | — |
| | — |
| | — |
| |
| Total NJNG | | $ | 1,115 |
| | $ | (911 | ) | | $ | — |
| | $ | 204 |
| |
| Derivative liabilities: | | | | | | | | | |
| Energy Services | | | | | | | | | |
| Physical commodity contracts | | $ | 12,872 |
| | $ | (2,837 | ) | | $ | 1,200 |
| | $ | 11,235 |
| |
| Financial commodity contracts | | 45,836 |
| | (17,945 | ) | | (27,891 | ) | | — |
| |
| Foreign currency contracts | | 32 |
| | (1 | ) | | — |
| | 31 |
| |
| Total Energy Services | | $ | 58,740 |
| | $ | (20,783 | ) | | $ | (26,691 | ) | | $ | 11,266 |
| |
| NJNG | | | | | | | | | |
| Physical commodity contracts | | $ | 1,154 |
| | $ | (31 | ) | | $ | — |
| | $ | 1,123 |
| |
| Financial commodity contracts | | 3,365 |
| | (880 | ) | | (2,485 | ) | | — |
| |
| Interest rate contracts | | 23,073 |
| | — |
| | — |
| | 23,073 |
| |
| Total NJNG | | $ | 27,592 |
| | $ | (911 | ) | | $ | (2,485 | ) | | $ | 24,196 |
| |
| Total Natural Gas Distribution | | | $ | 9,688 |
| | $ | (20 | ) | | $ | (1,149 | ) | | $ | 8,519 |
|
| |
| (1) | Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20. |
| |
| (2) | Offsetting derivative instruments include 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. |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical 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 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, createscreate volatility in the results of Energy Services, although the Company’s intended economic results relating to the entire transaction are unaffected.
The following table reflects the effect of derivative instruments on the Consolidated Statements of Operations as of September 30:
|
| | | | | | | | | | | | |
| (Thousands) | Location of gain (loss) recognized in income on derivatives | Amount of gain (loss) recognized in income on derivatives |
| Derivatives not designated as hedging instruments: | 2017 | | 2016 | | 2015 |
| Energy Services: | | | | | | |
| Physical commodity contracts | Operating revenues | $ | 8,912 |
| | $ | 33,034 |
| | $ | 32,568 |
|
| Physical commodity contracts | Gas purchases | (27,461 | ) | | (45,637 | ) | | (34,438 | ) |
| Financial commodity contracts | Gas purchases | 26,563 |
| | 45,579 |
| | 109,082 |
|
| Foreign currency contracts | Gas purchases | 41 |
| | (34 | ) | | — |
|
| Total unrealized and realized gains (losses) | $ | 8,055 |
| | $ | 32,942 |
| | $ | 107,212 |
|
Energy Services designated its foreign exchange contracts, entered into prior to January 1, 2016, as cash flow hedges and, as a result, 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 AOCI to gas purchases on the Consolidated Statements of Operations.
The following table reflects the effect of derivative instruments designated as cash flow hedges on OCI as of September 30:
| | | (Thousands) | Amount of Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion) | Amount of Gain or (Loss) Reclassified from OCI into Income (Effective Portion) | Amount of Gain or (Loss) Recognized on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing) | Location of gain (loss) recognized in income on derivatives | Amount of gain (loss) recognized in income on derivatives |
| Derivatives in cash flow hedging relationships: | 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | |
| Derivatives not designated as hedging instruments: | | Derivatives not designated as hedging instruments: | 2018 | | 2017 | | 2016 |
| Energy Services: | | | | | | | |
| Physical commodity contracts | | Operating revenues | $ | (9,311 | ) | | $ | 8,912 |
| | $ | 33,034 |
|
| Physical commodity contracts | | Gas purchases | (197 | ) | | (27,461 | ) | | (45,637 | ) |
| Financial commodity contracts | | Gas purchases | (24,622 | ) | | 26,563 |
| | 45,579 |
|
| Foreign currency contracts | $ | — |
| $ | (27 | ) | $ | — |
| $ | 27 |
| $ | — |
| $ | — |
| Gas purchases | (379 | ) | | 41 |
| | (34 | ) |
| Home Services and Other: | | | | | | | |
| Interest rate contracts | | Interest expense | 334 |
| | — |
| | — |
|
| Total unrealized and realized gains (losses) | | Total unrealized and realized gains (losses) | $ | (34,175 | ) | | $ | 8,055 |
| | $ | 32,942 |
|
NJNG’s derivative contracts are part of the Company’s risk management activities that relate to its natural gas purchases, BGSS incentive programs and debt financing. These transactions are entered into pursuant to regulatory approval and, at settlement, the resulting gains and/or losses are payable to or recoverable from utility customers. Any changes in the value of NJNG’s financial derivatives are deferred in regulatory assets or liabilities resulting in no impact to earnings.
The following table reflects the (losses) gains associated with NJNG’s derivative instruments as of September 30:
| | | (Thousands) | 2017 | | 2016 | | 2015 | 2018 | | 2017 | | 2016 |
| NJNG: | | | | | | |
| Natural Gas Distribution: | | | | | | |
| Physical commodity contracts | $ | (12,303 | ) | | $ | (15,756 | ) | | $ | — |
| $ | 1,232 |
| | $ | (12,303 | ) | | $ | (15,756 | ) |
| Financial commodity contracts | 5,595 |
| | (7,984 | ) | | (33,428 | ) | 1,844 |
| | 5,595 |
| | (7,984 | ) |
| Interest rate contracts | 14,606 |
| | (18,845 | ) | | (4,228 | ) | 8,467 |
| | 14,606 |
| | (18,845 | ) |
| Total unrealized and realized (losses) gains | $ | 7,898 |
| | $ | (42,585 | ) | | $ | (37,656 | ) | $ | 11,543 |
| | $ | 7,898 |
| | $ | (42,585 | ) |
NJNG and Energy Services had the following outstanding long (short) derivatives as of September 30:
|
| | | | | | | |
| | | | Volume (Bcf) |
| | | | 2018 | | 2017 |
| Natural Gas Distribution | Futures | | 27.9 |
| | 18.2 |
|
| | Physical | | 23.1 |
| | 32.1 |
|
| Energy Services | Futures | | (7.0 | ) | | (16.4 | ) |
| | Physical | | 51.2 |
| | (13.1 | ) |
Not included in the previous table are Energy Services’ gross notional amount of foreign currency transactions of approximately $8.5 million, interest rate contracts, as previously discussed, and 698,700 SRECs at Energy Services that are open as of September 30, 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
NJNG and Energy Services had the following outstanding long (short) derivatives as of September 30:
|
| | | | | | | |
| | | | Volume (Bcf) |
| | | | 2017 | | 2016 |
| NJNG | Futures | | 18.2 |
| | 23.6 |
|
| | Physical | | 32.1 |
| | 9.2 |
|
| Energy Services | Futures | | (16.4 | ) | | (79.1 | ) |
| | Financial Options | | — |
| | 1.2 |
|
| | Physical | | (13.1 | ) | | 94.6 |
|
Not included in the previous table are Energy Services’ gross notional amount of foreign currency transactions of approximately $4.5 million, NJNG’s treasury lock agreement, as previously discussed, and 283,000 SRECs at Energy Services that are open as of September 30, 2017.
Broker Margin
Futures exchanges have contract specificcontract-specific performance bond requirements, also known as margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin, thatwhich is posted upon the initiation of a position, maintenance margin, thatwhich is usually expressed as a percent of initial margin, and variation margin, thatwhich fluctuates based on the daily marked-to-market relative to maintenance margin requirements. The Company maintains separate broker margin accounts for NJNGthe Natural Gas Distribution and Energy Services.Services segments. The balances as of September 30, by company,segment, are as follows:
| | | (Thousands) | Balance Sheet Location | 2017 | 2016 | Balance Sheet Location | 2018 | 2017 |
| NJNG | Broker margin - Current assets | $ | 2,661 |
| $ | 4,822 |
| |
| Natural Gas Distribution | | Broker margin - Current assets | $ | 2,038 |
| $ | 2,661 |
|
| Energy Services | Broker margin - Current assets | $ | 23,166 |
| $ | 42,822 |
| Broker margin - Current assets | $ | 51,681 |
| $ | 23,166 |
|
Due to CME rulebook changes that took effect in January 2017, variation margin is being treated as a settlement payment, rather than collateral. As a result, the Company is now required to present variation margin net with the related derivative assets and/or liabilities on the Consolidated Balance Sheets for any derivatives the Company clears through the CME. This change is being applied on a prospective basis. In September 30, 2016, prior to the rule change, the Company reported the variation margin as a separate unit of account within restricted broker margin on the Consolidated Balance Sheets. There was no impact to the Company’s derivative gains or losses in the Consolidated Statements of Operations as a result of the CME rule amendment.
Wholesale Credit Risk
NJNG, Energy Services and Clean Energy Ventures are exposed to credit risk as a result of their sales/wholesale and retail marketing activities. As a result of the inherent volatility in the prices of natural gas commodities, derivatives, SRECs, electricity and RECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty fails to perform the obligations under its contract (e.g., fails to deliver or pay for natural gas, SRECs, electricity or RECs), 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 S&P or Moody’s. In these cases, the counterparty’s or guarantor’s financial statements are reviewed, and similar methodologies and ratios used by S&P 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of September 30, 2017.The2018.The amounts presented below have not been reduced by any collateral received or netting and exclude accounts receivable for NJNG retail natural gas sales and services and Clean Energy Ventures residential solar installations.
| | | (Thousands) | Gross Credit Exposure | Gross Credit Exposure |
| Investment grade | | $ | 136,804 |
| | | $ | 179,982 |
| |
| Noninvestment grade | | 16,889 |
| | | 43,486 |
| |
| Internally-rated investment grade | | 16,378 |
| | | 30,786 |
| |
| Internally-rated noninvestment grade | | 68,498 |
| | | 25,750 |
| |
| Total | | $ | 238,569 |
| | | $ | 280,004 |
| |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Conversely, certain of NJNG’s and Energy Services’ derivative instruments are linked to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG’s credit rating were to fall below its current level. NJNG’s credit rating, with respect to S&P, reflects the overall corporate credit profile of the Company. Specifically, most, but not all, of these additional payments will be triggered if NJNG’s debt is downgraded by the major credit agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings, but are based on certain financial metrics.
Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company’s credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on September 30, 2018 and 2017, is approximately $124,000 and 2016, is $8.7 million and $23.1 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on September 30, 20172018 and 2016,2017, the Company would have been required to post an additional $8.6 million$33,000 and $23.1$8.6 million, respectively, to its counterparties. These amounts differ from the respective net derivative liabilities reflected on the Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.
6.5. FAIR VALUE
Fair Value of Assets and Liabilities
The fair value of cash and cash equivalents, accounts receivable, current loan receivables, accounts payable, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. Non-current loan receivables are recorded based on what the Company expects to receive, which approximates fair value. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.
As of September 30, the estimated fair value of long-term debt at NJNG and NJR, including current maturities, excluding capital leases, debt issuance costs and solar asset financing obligations, is as follows:follows (1):
| | | (Thousands) | 2017 | 2016 | 2018 | 2017 |
| NJNG | | |
Carrying value (1) (2) | $ | 672,045 |
| $ | 707,845 |
| |
| Carrying value | | $ | 672,045 |
| $ | 672,045 |
|
| Fair market value | $ | 673,051 |
| $ | 731,615 |
| $ | 669,162 |
| $ | 673,051 |
|
| NJR | | |
Carrying value (3) | $ | 425,000 |
| $ | 375,000 |
| $ | 500,000 |
| $ | 425,000 |
|
| Fair market value | $ | 434,625 |
| $ | 399,462 |
| $ | 488,889 |
| $ | 434,625 |
|
| |
| (1) | Excludes Seecapital leases of $39.7 million and $42.2 millionNote 8. Debt as of fSeptember 30, 2017or a reconciliation to long-term and 2016short-term debt, respectively..
|
| |
(2) | Excludes debt issuance costs of $6.3 million and $7.7 million as of September 30, 2017 and 2016, respectively.
|
| |
(3) | Excludes debt issuance costs of $770,000 and $853,000 as of September 30, 2017 and 2016, respectively.
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The Company utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate, for the maturity of the specific issue and the Company’s credit rating. As of September 30, 20172018 and 2016,2017, the Company disclosed its debt within Level 2 of the fair value hierarchy.
Fair Value Hierarchy
The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs.
The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and includes the following:
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
| |
| 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 internally to as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM. |
| |
| Level 2 | Other significant observable inputs, such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG’s treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is: |
widely accepted and public;
non-proprietary and sourced from an independent third party; and
observable and published.
These additional adjustments are generally not considered to be significant to the ultimate recognized values.
| |
| Level 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 Energy Services consist mainly of futures, options and swaps. The Company primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market,market; therefore, the primary sources for its price inputs are CME, NYMEX and ICE. Energy Services uses Platts and Natural Gas Exchange for Canadian delivery points. However, Energy Services also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the transportation cost to the final delivery location is not significant to the overall valuation. If required, Energy Services’ policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or other pricing services.
The Company also has available for sale securities and other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Assets and liabilities measured at fair value on a recurring basis are summarized as follows:
|
| | | | | | | | | | | | | | | | | | |
| | Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Significant Unobservable Inputs | |
| (Thousands) | (Level 1) | (Level 2) | (Level 3) | Total |
| As of September 30, 2017: | | | | | | | | | | |
| Assets | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 21,866 |
| | | $ | — |
| | $ | 21,866 |
|
| Financial commodity contracts | | 17,335 |
| | | — |
| | | — |
| | 17,335 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | 44 |
| | | — |
| | 44 |
|
| Available for sale equity securities | | 65,752 |
| | | — |
| | | — |
| | 65,752 |
|
| Money market funds | | 112 |
| | | — |
| | | — |
| | 112 |
|
| Other | | 1,090 |
| | | — |
| | | — |
| | 1,090 |
|
| Total assets at fair value | | $ | 84,289 |
| | | $ | 21,910 |
| | | $ | — |
| | $ | 106,199 |
|
| Liabilities | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 25,371 |
| | | $ | — |
| | $ | 25,371 |
|
| Financial commodity contracts | | 24,036 |
| | | — |
| | | — |
| | 24,036 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | — |
| | | — |
| | — |
|
| Interest rate contracts | | — |
| | | 8,467 |
| | | — |
| | 8,467 |
|
| Total liabilities at fair value | | $ | 24,036 |
| | | $ | 33,838 |
| | | $ | — |
| | $ | 57,874 |
|
| As of September 30, 2016: | | | | | | | | | | |
| Assets | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 10,216 |
| | | $ | — |
| | $ | 10,216 |
|
| Financial commodity contracts | | 24,974 |
| | | — |
| | | — |
| | 24,974 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | 1 |
| | | — |
| | 1 |
|
| Available for sale equity securities | | 55,789 |
| | | — |
| | | — |
| | 55,789 |
|
| Money market funds | | 34,072 |
| | | — |
| | | — |
| | 34,072 |
|
| Other | | 1,444 |
| | | — |
| | | — |
| | 1,444 |
|
| Total assets at fair value | | $ | 116,279 |
| | | $ | 10,217 |
| | | $ | — |
| | $ | 126,496 |
|
| Liabilities | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 14,026 |
| | | $ | — |
| | $ | 14,026 |
|
| Financial commodity contracts | | 49,201 |
| | | — |
| | | — |
| | 49,201 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | 32 |
| | | — |
| | 32 |
|
| Interest rate contracts | | — |
| | | 23,073 |
| | | — |
| | 23,073 |
|
| Total liabilities at fair value | | $ | 49,201 |
| | | $ | 37,131 |
| | | $ | — |
| | $ | 86,332 |
|
Assets measured at fair value on a non-recurring basis are summarized as follows:
| | | | Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Significant Unobservable Inputs | | Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Significant Unobservable Inputs | |
| (Thousands) | (Level 1) | (Level 2) | (Level 3) | Total | (Level 1) | (Level 2) | (Level 3) | Total |
| As of September 30, 2018: | | | | | | | | | |
| Assets | | | | | | | | | |
| Physical commodity contracts | | | $ | — |
| | $ | 11,682 |
| | $ | — |
| | $ | 11,682 |
|
| Financial commodity contracts | | | 18,868 |
| | 7,025 |
| | — |
| | 25,893 |
|
| Financial commodity contracts - foreign exchange | | | — |
| | — |
| | — |
| | — |
|
| Interest rate contract | | | — |
| | 381 |
| | — |
| | 381 |
|
| Available for sale equity securities | | | 32,917 |
| | — |
| | — |
| | 32,917 |
|
Other (1) | | | 1,217 |
| | — |
| | — |
| | 1,217 |
|
| Total assets at fair value | | | $ | 53,002 |
| | $ | 19,088 |
| | $ | — |
| | $ | 72,090 |
|
| Liabilities | | | | | | | | | |
| Physical commodity contracts | | | $ | — |
| | $ | 29,666 |
| | $ | — |
| | $ | 29,666 |
|
| Financial commodity contracts | | | 39,724 |
| | — |
| | — |
| | 39,724 |
|
| Financial commodity contracts - foreign exchange | | | — |
| | 244 |
| | — |
| | 244 |
|
| Total liabilities at fair value | | | $ | 39,724 |
| | $ | 29,910 |
| | $ | — |
| | $ | 69,634 |
|
| As of September 30, 2017: | | | | | | | | | | | | | | | | |
| Assets | | | | | | | | | | | | | | | | |
Acquired wholesale energy contracts (1) | | $ | — |
| | $ | 41,084 |
| | $ | — |
| | $ | 41,084 |
| |
| Physical commodity contracts | | | $ | — |
| | $ | 21,866 |
| | $ | — |
| | $ | 21,866 |
|
| Financial commodity contracts | | | 17,335 |
| |
| |
|
| | 17,335 |
|
| Financial commodity contracts - foreign exchange | | | — |
| | 44 |
| | — |
| | 44 |
|
| Available for sale equity securities | | | 65,752 |
| | — |
| | — |
| | 65,752 |
|
Other (1) | | | 1,202 |
| | — |
| | — |
| | 1,202 |
|
| Total assets at fair value | | $ | — |
| | $ | 41,084 |
| | $ | — |
| | $ | 41,084 |
| | $ | 84,289 |
| | $ | 21,910 |
| | $ | — |
| | $ | 106,199 |
|
| Liabilities | | | | | | | | | |
| Physical commodity contracts | | | $ | — |
| | $ | 25,371 |
| | $ | — |
| | $ | 25,371 |
|
| Financial commodity contracts | | | 24,036 |
| | — |
| | — |
| | 24,036 |
|
| Interest rate contract | | | — |
| | 8,467 |
| | — |
| | 8,467 |
|
| Total liabilities at fair value | | | $ | 24,036 |
| | $ | 33,838 |
| | $ | — |
| | $ | 57,874 |
|
| |
| (1) | Included in intangible asset on the Consolidated Balance Sheets, see Note 3. Acquisition for more information regarding the acquired contracts.
Includes money market funds. |
During the second quarter of fiscal 2018, the Company evaluated the decrease in fair value of its available for sale securities on a nonrecurring basis and determined that the decline was other-than-temporary. Accordingly, the Company recognized an other-than-temporary impairment of $17.8 million, which was determined using quoted market prices for identical publicly traded equity securities on an active exchange. As of March 31, 2018, the Company’s available for sale securities had a fair value of $28.2 million.See the Company’s discussion of available for sale securities in Note 2. Summary of Significant Accounting Policies for more information regarding the impairment.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
7.6. INVESTMENTS IN EQUITY INVESTEES
As of September 30, the Company’s investments in equity method investees includes the following:
| | | (Thousands) | 2017 | 2016 | 2018 | 2017 |
Steckman Ridge (1) | $ | 120,262 |
| $ | 123,155 |
| $ | 117,001 |
| $ | 120,262 |
|
| PennEast | 52,323 |
| 17,993 |
| 73,865 |
| 52,323 |
|
| Total | $ | 172,585 |
| $ | 141,148 |
| $ | 190,866 |
| $ | 172,585 |
|
(1)Includes loans with a total outstanding principal balance of $70.4 million for both fiscal 20172018 and 2016,2017, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.
The Company, through its subsidiary NJR Pipeline Company, is an investor in PennEast, which is expected to construct and operate a 120-mile pipeline that will extend from northeast Pennsylvania to western New Jersey and is estimatedJersey. PennEast has advised that it currently expects the pipeline to be completed and operational in 2019.2019; however, the project could be delayed beyond 2019 due to factors that are beyond PennEast’s ability to control or estimate precisely, including potential delays in obtaining (or the inability to obtain) governmental and regulatory approvals and land-use rights, and unforeseen construction delays.
NJNG and Energy Services have entered into storage and park and loan agreements with Steckman Ridge. In addition, NJNG has entered into a precedent capacity agreement with PennEast. See Note 16.15. Related Party Transactions for more information on these intercompany transactions.
8.7. EARNINGS PER SHARE
The following table presents the calculation of the Company’s basic and diluted earnings per share for the fiscal years ended September 30:
| | | (Thousands, except per share amounts) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Net income, as reported | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| Basic earnings per share | | |
| Weighted average shares of common stock outstanding-basic | 86,321 |
| 85,884 |
| 85,186 |
| 87,689 |
| 86,321 |
| 85,884 |
|
| Basic earnings per common share | $1.53 | $1.53 | $2.12 | $2.66 | $1.53 |
| Diluted earnings per share | | |
| Weighted average shares of common stock outstanding-basic | 86,321 |
| 85,884 |
| 85,186 |
| 87,689 |
| 86,321 |
| 85,884 |
|
Incremental shares (1) | 823 |
| 847 |
| 1,079 |
| 626 |
| 823 |
| 847 |
|
| Weighted average shares of common stock outstanding-diluted | 87,144 |
| 86,731 |
| 86,265 |
| 88,315 |
| 87,144 |
| 86,731 |
|
Diluted earnings per common share (2) | $1.52 | $1.52 | $2.10 | $2.64 | $1.52 |
| |
| (1) | Incremental shares consist primarily of unvested stock awards and performance units. |
| |
| (2) | There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for fiscal 20172018, 20162017 and 20152016. |
9.8. DEBT
NJNG and NJR finance working capital requirements and capital expenditures through the issuance of various long-term debt and other financing arrangements, including unsecured credit and private placement debt shelf facilities. Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Long-term DebtSale-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 at the end of the term or repurchase the asset. Proceeds from sale-leaseback transactions are accounted for as financings and are included in long-term debt on the Consolidated Balance Sheets. During fiscal 2018 and 2017, NJNG received $7.8 million and $9.6 million, respectively, in connection with the sale-leaseback of its natural gas meters with terms ranging from seven to 11 years.
In addition, for certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third parties and the concurrent leaseback of the assets. For sale-leaseback transactions where the Company has concluded that the terms of the arrangement create a continuing involvement in the asset and the asset is
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
considered integral equipment, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the 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.
Clean Energy Ventures received $71.5 million and $32.9 million in proceeds related to the sale of commercial solar assets during fiscal 2018 and 2017, respectively. Clean Energy Ventures simultaneously entered into agreements to lease the assets back over six to 15-year terms. The Company will continue to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects have been transferred to the buyer; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. Clean Energy Ventures did not enter into sale-leaseback during fiscal 2016 and therefore recognized the full ITC in income tax (benefit) provision on the Consolidated Statements of Operations when the assets were placed in service.
Environmental Contingencies
Loss contingencies are recorded as liabilities when it is probable a liability has been incurred and the amount of the loss is reasonably estimable in accordance with accounting standards for contingencies. Estimating probable losses requires an analysis of uncertainties that often depend upon judgments about potential actions by third parties. Accruals for loss contingencies are recorded based on an analysis of potential results.
With respect to environmental liabilities and related costs, NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination. See Note 13. Commitments and Contingent Liabilities for more details.
Pension and Postemployment Plans
The Company has two noncontributory defined pension plans covering eligible employees, including officers. Benefits are based on each employee’s years of service and compensation. The Company’s funding policy is to contribute annually to these plans at least the minimum amount required under the Employee Retirement Income Security Act, as amended, and not more than can be deducted for federal income tax purposes. Plan assets consist of equity securities, fixed-income securities and short-term investments. The Company made a discretionary contribution of $30 million during the first quarter of fiscal 2016 to improve the funded status of the pension plans based on the current actuarial assumptions, which included the adoption of the most recent mortality table. The Company made no discretionary contributions to the pension plans in fiscal 2018 and 2017.
The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds. The Company contributed $6.2 million, $6 million and $3.2 million in aggregate to these plans in fiscal 2018, 2017 and 2016, respectively, which is recorded in postemployment employee benefit liability on the Consolidated Balance Sheets.
See Note 10. Employee Benefit Plans, for a more detailed description of the Company’s pension and postemployment plans.
Asset Retirement Obligations
The Company recognizes AROs related to the costs associated with cutting and capping NJNG’s main and service gas distribution mains, which is required by New Jersey law when taking such gas distribution mains out of service. The Company also recognizes AROs associated with Clean Energy Ventures’ solar and wind assets when there are decommissioning provisions in lease agreements that require removal of the asset at the end of the lease term.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
AROs are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations. Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets.
Estimating future removal costs requires management to make significant judgments because most of the removal obligations span long time frames and removal may be conditioned upon future events. Asset removal technologies are also constantly changing, which makes it difficult to estimate removal costs. Accordingly, inherent in the estimate of AROs 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 assign probabilities based on management’s reasonable judgment and knowledge of industry practice. Accordingly, AROs are subject to change.
Accumulated Other Comprehensive Income
The following table presents the long-term debtchanges in the components of the Companyaccumulated other comprehensive income, net of related tax effects, as of September 30:30:
|
| | | | | | | | |
| (Thousands) | 2017 | 2016 |
| NJNG | | | |
| First mortgage bonds: | Maturity date: | | |
| 4.50% | Series II | August 1, 2023 | $ | — |
| $ | 10,300 |
|
| 4.60% | Series JJ | August 1, 2024 | — |
| 10,500 |
|
| 4.90% | Series KK | October 1, 2040 | — |
| 15,000 |
|
| 5.60% | Series LL | May 15, 2018 | 125,000 |
| 125,000 |
|
| Variable | Series MM | September 1, 2027 | 9,545 |
| 9,545 |
|
| Variable | Series NN | August 1, 2035 | 41,000 |
| 41,000 |
|
| Variable | Series OO | August 1, 2041 | 46,500 |
| 46,500 |
|
| 3.15% | Series PP | April 15, 2028 | 50,000 |
| 50,000 |
|
| 3.58% | Series QQ | March 13, 2024 | 70,000 |
| 70,000 |
|
| 4.61% | Series RR | March 13, 2044 | 55,000 |
| 55,000 |
|
| 2.82% | Series SS | April 15, 2025 | 50,000 |
| 50,000 |
|
| 3.66% | Series TT | April 15, 2045 | 100,000 |
| 100,000 |
|
| 3.63% | Series UU | June 21, 2046 | 125,000 |
| 125,000 |
|
| Capital lease obligation-buildings | June 1, 2021 | 11,617 |
| 14,262 |
|
| Capital lease obligation-meters | Various dates | 28,042 |
| 27,895 |
|
| Less: Debt issuance costs | | (6,262 | ) | (7,659 | ) |
| Less: Current maturities of long-term debt | | (135,800 | ) | (11,452 | ) |
| Total NJNG long-term debt | 569,642 |
| 730,891 |
|
| NJR | | | |
| 6.05% | Unsecured senior notes | September 24, 2017 | — |
| 50,000 |
|
| 2.51% | Unsecured senior notes | September 15, 2018 | 25,000 |
| 25,000 |
|
| 3.25% | Unsecured senior notes | September 17, 2022 | 50,000 |
| 50,000 |
|
| 3.48% | Unsecured senior notes | November 7, 2024 | 100,000 |
| 100,000 |
|
| 3.20% | Unsecured senior notes | August 18, 2023 | 50,000 |
| 50,000 |
|
| 3.54% | Unsecured senior notes | August 18, 2026 | 100,000 |
| 100,000 |
|
| Variable | Term loan | August 16, 2019 | 100,000 |
| — |
|
| Less: Debt issuance costs | | (770 | ) | (853 | ) |
| Less: Current maturities of long-term debt | | (25,000 | ) | (50,000 | ) |
| Total NJR long-term debt | 399,230 |
| 324,147 |
|
| Clean Energy Ventures | | |
| Solar asset financing obligation | Various dates | 32,790 |
| — |
|
| Less: Current maturities of long-term debt | (4,582 | ) | — |
|
| Total Clean Energy Ventures long-term debt | 28,208 |
| — |
|
| Total long-term debt | $ | 997,080 |
| $ | 1,055,038 |
|
|
| | | | | | | | | | | |
| (Thousands) | Unrealized gain (loss) on available for sale securities | Adjustment to postemployment benefit obligation | Total |
| Balance as of September 30, 2016 | $ | 4,198 |
| | $ | (19,353 | ) | | $ | (15,155 | ) |
| Other comprehensive income, net of tax | | | | | |
| Other comprehensive income, before reclassifications, net of tax of $(6,593), $(2,619), $(9,212) | 10,019 |
| | 3,783 |
| | 13,802 |
|
| Amounts reclassified from accumulated other comprehensive (loss) income, net of tax of $2,192, $(868), $1,324 | (3,173 | ) | | 1,270 |
| (1) | (1,903 | ) |
| Net current-period other comprehensive income, net of tax of $(4,401), $(3,487), $(7,888) | 6,846 |
| | 5,053 |
| | 11,899 |
|
| Balance at September 30, 2017 | $ | 11,044 |
| | $ | (14,300 | ) | | $ | (3,256 | ) |
| Other comprehensive income, net of tax | | | | | |
| Other comprehensive (loss) income, before reclassifications, net of tax of $6,973, $(125), $6,848 | (19,245 | ) | | 464 |
| | (18,781 | ) |
| Amounts reclassified from accumulated other comprehensive income, net of tax of $(858), $(448), $(1,306) | 11,647 |
| | 1,056 |
| (1) | 12,703 |
|
| Net current-period other comprehensive (loss) income, net of tax of $6,115, $(573), $5,542 | (7,598 | ) | | 1,520 |
| | (6,078 | ) |
Reclassifications of certain income tax effects to retained earnings (2)
| — |
| | (3,276 | ) | | (3,276 | ) |
| Balance at September 30, 2018 | $ | 3,446 |
| | $ | (16,056 | ) | | $ | (12,610 | ) |
| |
| (1) | Included in the computation of net periodic pension cost, a component of O&M expense on the Consolidated Statements of Operations. For more details, see Note 10. Employee Benefit Plans. |
| |
| (2) | Due to the adoption of ASU No. 2018-02, an amendment to ASC 740, Income Taxes. See Note 2. Summary of Significant Accounting Policies- Recently Adopted Updates to the Accounting Standards Codification section for more details. |
Foreign Currency Transactions
The market area of Energy Services includes Canadian delivery points and as a result, Energy Services incurs certain natural gas commodity costs and demand fees denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of gas purchases on the Consolidated Statements of Operations. Gains and losses recognized for the fiscal years ended September 30, 2018, 2017 and 2016, are considered immaterial.
Reclassification
Annual long-term debt redemption requirements, excludingCertain prior period amounts related to the amortization of acquired wholesale energy contracts on the Consolidated Statements of Cash Flows and in the deferred tax table in Note 12. Income Taxes for the fiscal year ended September 30, 2017, were reclassified to conform to the current period presentation.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Recently Adopted Updates to the Accounting Standards Codification
Inventory
In July 2015, the FASB issued ASU No. 2015-11, an amendment to ASC 330, Inventory, which requires entities to measure most inventory “at the lower of cost or net realizable value,” thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. The Company adopted the new guidance in the first quarter of fiscal 2018 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.
Reporting Comprehensive Income
In February 2018, the FASB issued ASU No. 2018-02, an amendment to ASC 220, Income Statement - Reporting Comprehensive Income, which allows for the reclassification from accumulated other comprehensive income to retained earnings for the disproportionate tax effects of the Tax Act. The Company early adopted this guidance in the fourth quarter of fiscal 2018 and reclassified on a prospective basis only, $3.3 million from accumulated other comprehensive income to retained earnings. This did not materially impact the Company’s financial position, results of operations or cash flows.
Tax
In March 2018, the FASB issued ASU No. 2018-05, an amendment to ASC 740, Income Taxes, which provides relief to entities in their calculation of the effects of the Tax Act by allowing them to record provisional amounts for certain income tax effects to address circumstances in which an entity does not have the necessary information available, prepared or analyzed to complete the accounting. These provisional amounts are subject to change as information and assumptions are updated throughout the measurement period, which may not extend beyond one year from the enactment date. The new guidance was effective immediately upon issuance, and the Company adopted the new guidance in the second quarter of fiscal 2018 and applied the new provision on a prospective basis.
Other Recent Updates to the Accounting Standards Codification
Revenue
In May 2014, the FASB issued ASU No. 2014-09, and added ASC 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries, jurisdictions and capital leases, debt issuance costsmarkets. The Company adopted the new guidance on October 1, 2018, and solarwill apply the new provisions on a modified retrospective basis.
Management established an implementation team to evaluate the impact on the Company’s financial position, results of operations and cash flows upon adoption of ASC 606. This implementation team reviewed the revenue streams of all of its subsidiaries and formed conclusions to determine if any system, process, controls and organizational changes are necessary upon adoption. The assessment of the impact of this guidance included reviewing the Company’s accounting policies under ASC 605 and identifying potential differences after the adoption of ASC 606. The Company concluded that its tariff-based sales of natural gas will be within the scope of the new guidance and it does not anticipate any modification to the pattern of revenue recognition from such sales. Revenues from derivative instruments such as those related to the Company’s SREC sales and natural gas purchases and sales will continue to be accounted for under ASC 815 and thus are outside the scope of ASC 606. Additionally, NJNG revenues generated by the CIP have been determined to be alternative revenue programs under ASC 980 and are also outside the scope of ASC 606 as they are deemed to be a contract with the regulator. The Company also evaluated its renewable asset financingPPA arrangements and does not anticipate any modification to the pattern of revenue recognition of the related electricity, capacity and REC sales. Revenues from RECs sold as part of a bundled arrangement will be recognized in the same period as the related generation, consistent with current practice.
The Company has completed its evaluation of its revenue streams, and based on the assessment performed, has concluded that the new guidance will not have a material impact on its financial position, results of operations or cash flows upon adoption. Additionally, the Company did not implement significant changes to its business processes, systems or internal controls over financial reporting upon adoption. ASC 606 requires expanded disclosures, including the disclosure of performance obligations, disaggregated revenues and contract balances, which the Company will include in its financial statements beginning in the first quarter of fiscal 2019.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Financial Instruments
In January 2016, the FASB issued ASU No. 2016-01, an amendment to ASC 825, Financial Instruments, to address certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certain fair value changes for financial liabilities measured at fair value. It also simplifies the impairment assessment of equity investments without a readily determinable fair value by requiring a qualitative assessment. The guidance is effective for the Company beginning October 1, 2018. The amendment will be applied on a modified retrospective basis. The Company evaluated the amendment and noted that, upon adoption, subsequent changes to the fair value of the Company’s available for sale securities will be recorded in the Consolidated Statement of Operations as opposed to other comprehensive income. The Company will reclassify $3.4 million in accumulated other comprehensive income related to available for sale securities to the opening balance of retained earnings as of October 1, 2018. There will be no material impact to the Company’s financial position, results of operations or cash flows upon adoption.
In June 2016, the FASB issued ASU No. 2016-13, an amendment to ASC 326, September 30Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. An entity will apply the amendment through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.
Leases
In February 2016, the FASB issued ASU No. 2016-02, an amendment to ASC 842, Leases, are as follows:which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption.
|
| | | | | | |
| (Thousands) | NJNG | NJR |
| 2018 | $ | 125,000 |
| $ | 25,000 |
|
| 2019 | $ | — |
| $ | 100,000 |
|
| 2020 | $ | — |
| $ | — |
|
| 2021 | $ | — |
| $ | — |
|
| 2022 | $ | — |
| $ | 50,000 |
|
| Thereafter | $ | 547,045 |
| $ | 250,000 |
|
In July 2018, the FASB issued ASU No. 2018-11, which provides an optional transition method to ASC 842 that allows the Company to recognize a cumulative effect adjustment to the opening balance of retained earnings in the period of adoption. At this time, the Company does not plan to early adopt the new guidance and expects to transition on a modified retrospective basis. While the Company is currently evaluating the full impact of the standard and its related updates, it expects to recognize additional assets and liabilities arising from current operating leases to its financial position upon adoption. Current operating leases primarily consist of office and land leases related to the Company’s solar and wind assets.
Statement of Cash Flows
In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company beginning October 1, 2018. The amendment will be applied on a retrospective basis and the Company does not expect any material impacts to its statement of cash flows.
In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its statement of cash flows.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
NJNGIntangibles
First Mortgage BondsIn August 2018, the FASB issued ASU No. 2018-15, an amendment to ASC 350, Intangibles - Goodwill and Other, which aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective or retrospective basis.
Business Combinations
In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on the accounting framework that is applied to acquisitions.
Gains and Losses from the Derecognition of Nonfinancial Assets
In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company as of October 1, 2018 and will be applied retrospectively with a cumulative effect adjustment at the date of adoption. The Company had a deferred gain of $6.8 million related to nonfinancial assets on the balance sheet, which will be recognized under the new accounting guidance as a cumulative effect adjustment to the opening balance of retained earnings as of October 1, 2018.
Compensation - Retirement Benefits
In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The amendment establishes a practical expedient that permits entities to use their previously disclosed service and other costs in their pension and other postretirement benefit plan footnotes in the prior comparative periods as the estimation basis when applying the retrospective presentation of these costs in the income statement. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis for income statement presentation, and on a prospective basis for changes to capitalization of costs. The changes related to the costs that will be eligible for capitalization and based on the components of net periodic benefit costs during fiscal year 2018, will not have a material impact on the Company's financial position, results of operations or cash flows upon adoption
In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures, and adds new disclosure requirements identified as relevant. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a retrospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on the Company's disclosures upon adoption.
Stock Compensation
In May 2017, the FASB issued ASU No. 2017-09, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for changes to the terms or conditions of share-based payments. The guidance is effective for the Company beginning October 1, 2018, and will be applied prospectively to awards modified on or after the adoption date. There was no material impact to the Company's financial position, results of operations or cash flows upon adoption.
In June 2018, the FASB issued ASU No. 2018-07, an amendment to ASC 718, Compensation - Stock Compensation, which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from non-employees. The guidance is effective for the Company beginning October 1, 2019, with early adoption permitted. The Company is currently evaluating the impact of the amendment on the Company’s financial position, results of operations and cash flows upon adoption.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Derivatives and Hedging
In August 2017, the FASB issued ASU No. 2017-12, an amendment to ASC 815, Derivatives and Hedging, which is intended to make targeted improvements to the accounting for hedging activities by better aligning an entity’s risk management activities and financial reporting for hedging relationships. These amendments modify the accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Additionally, the amendments are intended to simplify the application of the hedge accounting guidance and provide relief to companies by easing certain hedge documentation requirements. The guidance is effective for the Company beginning October 1, 2019, with early adoption permitted. Upon adoption, the transition requirements and elections will be applied to hedging relationships existing on the date of adoption. The Company does not currently apply hedge accounting to any of its risk management activities and thus does not expect the amendments to have any impact on its financial position, results of operations and cash flows upon adoption.
Fair Value
In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective or retrospective basis depending on the specific amendments’ transition requirements. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption and will apply the new guidance.
3. 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 gas to NJNG’s service territory; and the delivery portion, which represents the transportation of the commodity portion through NJNG’s gas distribution system to the end-use customer. NJNG does not earn utility gross margin on the commodity portion of its natural gas sales. NJNG earns utility gross margin through the delivery of natural gas to its customers, regardless of whether it or a third-party supplier provides the wholesale natural gas commodity.
Under EDECA, the BPU is required to audit the state’s energy utilities every two years. The primary purpose of the audit is to ensure that utilities and their affiliates offering unregulated retail services do not have an unfair competitive advantage over nonaffiliated providers of similar retail services. A combined competitive services and management audit of NJNG commenced in August 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 Trustee entered intoearn a reasonable return on its utility capital investments based on the Mortgage Indenture, dated September 1, 2014, which secures allBPU’s approval. The impact of the outstanding First Mortgage Bonds issuedratemaking process and decisions authorized by NJNG. The Mortgage Indenture provides a direct first mortgage lien upon substantially allthe BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets, and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.
NJNG’s recovery of costs is facilitated through its base rates, BGSS and other regulatory tariff riders. NJNG is required to make an annual filing to the BPU by June 1 of each year for review of its BGSS, CIP and other programs and related rates. Annual rate changes are requested to be effective at the beginning of the operating propertiesfollowing fiscal year. The current base rate includes a weighted average cost of capital of 6.9 percent and franchisesa return on common equity of 9.75 percent. In addition, NJNG (other than excepted property,is permitted to request approval of certain rate or program changes on an interim basis. All rate and program changes are subject to proper notification and BPU review and approval.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are composed of the following:
|
| | | | | | |
| (Thousands) | 2018 | 2017 |
| Regulatory assets-current | | |
| New Jersey Clean Energy Program | $ | 14,052 |
| $ | 14,202 |
|
| Underrecovered gas costs | 4,137 |
| 9,910 |
|
| Derivatives at fair value, net | 108 |
| 9,010 |
|
| Conservation Incentive Program | — |
| 17,669 |
|
| Total current regulatory assets | $ | 18,297 |
| $ | 50,791 |
|
| Regulatory assets-noncurrent | | |
| Environmental remediation costs: | | |
| Expended, net of recoveries | $ | 33,017 |
| $ | 28,547 |
|
| Liability for future expenditures | 130,800 |
| 149,000 |
|
| Deferred income taxes | 17,225 |
| 21,795 |
|
| SAVEGREEN | 8,636 |
| 16,302 |
|
| Postemployment and other benefit costs | 136,716 |
| 141,433 |
|
| Deferred storm damage costs | 10,858 |
| 13,030 |
|
| Cost of removal | 22,339 |
| — |
|
| Other noncurrent regulatory assets | 9,001 |
| 5,812 |
|
| Total noncurrent regulatory assets | $ | 368,592 |
| $ | 375,919 |
|
| Regulatory liability-current | | |
| Conservation Incentive Program | $ | 6,994 |
| $ | — |
|
| Derivatives at fair value, net | 1,191 |
| 78 |
|
| Total current regulatory liabilities | $ | 8,185 |
| $ | 78 |
|
| Regulatory liabilities-noncurrent | | |
Tax Act impact (1) | $ | 205,410 |
| $ | — |
|
| Cost of removal | — |
| 7,902 |
|
| New Jersey Clean Energy Program | 1,902 |
| 5,795 |
|
| Other noncurrent regulatory liabilities | 1,827 |
| 810 |
|
| Total noncurrent regulatory liabilities | $ | 209,139 |
| $ | 14,507 |
|
| |
| (1) | Includes an adjustment related to the re-measurement of NJNG's net deferred tax liabilities to reflect the change in federal tax rates enacted in the Tax Act, which is net of sales tax collected from customers. For a more detailed discussion, see Note 12. Income Taxes. |
Recovery of regulatory assets is subject to BPU approval, and therefore, if there are any changes in regulatory positions that indicate recovery is not probable, the related cost would be charged to income in the period of such as cash on hand, choses-in-action, securities, rent,determination.
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 2019. NJNG recovers the costs associated with its portion of the NJCEP obligation through its NJCEP rider, with interest.
Over and Underrecovered Gas Costs
NJNG recovers its cost of gas through the BGSS rate component of its customers’ bills. NJNG’s cost of gas includes the purchased cost of the natural gas meterscommodity, fees paid to pipelines and certain materials, supplies, appliancesstorage facilities, adjustments as a result of BGSS incentive programs and vehicles), subject onlyhedging transactions. Overrecovered gas costs represent a regulatory liability that generally occurs when NJNG’s BGSS rates are higher than actual costs and requests approval to certain permitted encumbrances. The Mortgage Indenture contains provisions subjecting after-acquired property (otherbe returned to customers including interest, when applicable, in accordance with NJNG’s approved BGSS tariff. Conversely, underrecovered gas costs generally occur during periods when NJNG’s BGSS rates are lower than excepted propertyactual costs, in which case NJNG records a regulatory asset and subjectrequests amounts to pre-existing liens, if any, atbe recovered from customers in the time of acquisition) to the lien thereof.future.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Derivatives
Derivatives are utilized by NJNG to manage the price risk associated with its natural gas purchasing activities and to participate in certain BGSS incentive programs. The gains and losses associated with NJNG’s Mortgage Indenturederivatives are recoverable through its BGSS, as noted above, without interest. See Note 4. Derivative Instruments.
Conservation Incentive Program
The CIP permits NJNG to recover utility gross margin variations related to customer usage resulting from customer conservation efforts and mitigates the impact of weather on its margin. Such utility gross margin variations are recovered in the year following the end of the CIP usage year, without interest, and are subject to additional conditions, including an earnings test, a revenue test and an evaluation of BGSS related savings. This program has no longer containsexpiration date.
Environmental Remediation Costs
NJNG is responsible for the cleanup of certain former gas manufacturing facilities. Actual expenditures are recovered from customers, with interest, over seven-year rolling periods, through a restrictionRAC rate rider. Recovery for NJNG’s estimated future liability will be requested and/or recovered when actual expenditures are incurred. See Note 13. 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 NJNG's abilitythe unamortized balance through a tariff rider, without interest, as approved by the BPU, over a two- to pay dividends. 10-year period depending upon the specific program incentive.
Postemployment and Other Benefit Costs
Postemployment and Other Benefit Costs represents NJNG’s underfunded postemployment benefit obligations, as well as a fiscal 2010 tax charge resulting from a change in the deductibility of federal subsidies associated with Medicare Part D, both of which are deferred as regulatory assets and are recoverable, without interest, in base rates. The BPU approved the recovery of the tax charge through NJNG’s base rates effective October 2016 over a seven-year amortization period. See Note 10. Employee Benefit Plans.
Deferred Storm Damage Costs
Portions of NJNG’s distribution system incurred significant damage as a result of Superstorm Sandy in October 2012. NJNG deferred the uninsured incremental O&M costs associated with its restoration efforts, which were approved for recovery by the BPU through NJNG’s base rates, without interest, effective October 2016 over a seven-year amortization period.
Cost of Removal
NJNG accrues and collects for cost of removal in base rates on its utility property, without interest. These costs are recorded in accumulated depreciation for regulatory reporting purposes, and actual costs of removal, without interest, will be recovered in subsequent rates, pursuant to the BPU order in docket number GR15111304 dated September 23, 2016. Consistent with GAAP, amounts recorded within accumulated depreciation for regulatory accounting purposes are reclassified out of accumulated depreciation to either a regulatory asset or a regulatory liability depending on whether actual cost of removal is still subject to collection or amounts overcollected will be refunded back to customers. NJNG’s prior regulatory liability represented customer collections in excess of actual expenditures, which the Company returned to customers as a reduction to depreciation expense.
New Jersey Administrative Code 14:4-4.7 states that a public utility cannot issue dividends,Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Other Regulatory Assets
Other regulatory assets consist primarily of deferred costs associated with certain components of NJNG’s SBC, as discussed further in the regulatory proceedings section, and NJNG’s compliance with federal- and state-mandated PIM provisions. NJNG’s related costs to maintain the operational integrity of its distribution and transmission main are recoverable, without regulatory approval, if its equityinterest, subject to total capitalization ratio falls below 30 percent.BPU review and approval. As of September 30, 2018, NJNG recorded $3.2 million of PIM in other regulatory assets, which is being recovered through base rates over a seven-year amortization period effective October 2016.
The Tax Act
On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. As a result, NJNG recorded a regulatory liability, which included the revaluation of its deferred income taxes and the accounting of the income tax effects on the revaluation. The revaluation was based on certain assumptions and estimations NJNG made with respect to its deferred taxes, as well as the effects from the Tax Act, and as such is subject to change if and when assumptions are updated. See , NJNG’s equityNote 12. Income Taxes for a more detailed discussion on the Tax Act.
On January 31, 2018, the BPU issued an Order which directed New Jersey utilities to total capitalization ratiosubmit filings to the BPU by March 2, 2018, to propose the prospective change in base rates as a result of the Tax Act to be effective April 1, 2018, the method to return to customers the overcollection of taxes in base rates from January 1, 2018, through March 31, 2018 and an outline of the method by which the excess deferred taxes would be returned to customers. The excess deferred taxes are primarily related to timing differences associated with utility plant depreciation and are subject to IRS normalization rules, which require amortization over the remaining life of the utility plant.
On March 1, 2018, NJNG submitted its required filing to the BPU proposing a $19.7 million base rate reduction and customer refunds of approximately $31 million, which is 55.6 percentinclusive of state sales tax and interest at the Company’s short-term debt rate as specified in the Company’s last base rate case. On March 26, 2018, the BPU approved, on an interim basis, the $19.7 million rate reduction, effective April 1, 2018. On May 22, 2018, the BPU approved final rates and also customer refunds of the $31 million. These credits were returned to customer accounts in June 2018.
The following is a description of certain regulatory proceedings during fiscal 2017 and 2018:
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 issue upmake two interim filings during each fiscal year to $960 million of FMB under the termsincrease 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 Mortgage Indenture.commodity costs to customers at any time given five days’ notice when the natural gas commodity costs decrease in comparison to amounts projected or to amounts previously collected from customers. Concurrent with the annual BGSS filing, NJNG files for an annual review of its CIP. NJNG’s annual BGSS and CIP filings are summarized as follows:
June 2016 BGSS/CIP filing — In September 2016, the BPU approved NJNG’s filing to increase its CIP rates resulting in a $43.9 million annual recovery increase and to decrease its annual BGSS rate for residential and small commercial customers resulting in a $22.6 million annual recovery decrease effective October 2016. This petition also included bill credits to residential and small commercial customers during the months of November 2016 through February 2017, as a result of a decline in the wholesale price of natural gas. A total of $42 million in bill credits were issued during fiscal 2017.
June 2017 BGSS/CIP filing — In March 2018, the BPU approved NJNG’s petition on a final basis to maintain its BGSS rate for residential and small commercial customers, increase its balancing charge rate, which resulted in a $3.7 million increase to the annual revenues credited to BGSS, and decrease its CIP rates, which resulted in a $16.2 million annual recovery decrease that was effective October 2017.
May 2018 BGSS/CIP filing — On September 17, 2018, the BPU provisionally approved NJNG’s annual petition to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well as changes to the CIP rates, which will result in a $30.9 million annual recovery decrease effective October 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
BGSS Incentive Programs
NJNG has variable rate EDA Bonds withis eligible to receive financial incentives for reducing BGSS costs through a total principal amountseries of $97 millionutility gross margin-sharing programs that include off-system sales, capacity release and maturity dates ranging from September 2027storage incentive programs. The Company is permitted to August 2041. The EDA Bondsannually 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 not subjectdesigned to optional tenderencourage the installation of high efficiency heating and cooling equipment and other energy efficiency upgrades to promote energy efficiency incentives to its residential and commercial customers while they bear interest at a LIBOR index rate. Asstimulating state and local economies through the creation of September 30, 2017, the interest ratejobs. Depending on the EDA Bonds was 1.42 percent.
In June 2016,specific initiative or approval, NJNG entered intorecovers costs associated with the programs over a Note Purchase Agreement, under which NJNG issued $125 million of its 3.63 percent senior notes due June 2046. The notes are secured by an equal principal amount of NJNG’s FMB (series UU) issued under NJNG’s Mortgage Indenture. The proceeds of the notes will be used for general corporate purposes, including, but not limitedthree- to refinancing or retiring short-term debt and funding capital expenditures.
On January 17, 2017, the Company completed the purchase of three FMBs in lieu of redemption with an aggregate principal amount totaling $35.8 million. The FMBs bore interest at rates ranging from 4.5 percent to 4.9 percent. The bonds purchased in lieu of redemption are being held by the Company to provide an opportunity to evaluate remarketing alternatives.10-year period through a tariff rider mechanism.
As of September 30, 2017, NJNG's $1252018, the BPU has approved total SAVEGREEN investments of approximately $354.3 million, 5.6including $135 million that was approved on September 17, 2018, for a continuation of existing EE programs and the implementation of new programs through December 2021.
SAVEGREEN investments and costs are filed with the BPU on an annual basis. Since inception, $162 million in grants, rebates and loans have been provided to customers, with a total annual recovery of approximately $16.1 million. The recovery includes a weighted average cost of capital that ranges from 6.69 percent senior notes,to 7.76 percent, with a return on equity of 9.75 percent to 10.3 percent, respectively. On October 16, 2018, NJNG requested a decrease in its EE recovery rate reflecting costs incurred through September 30, 2018, which will matureresult in Mayan annual decrease of $8.8 million, anticipated to be effective January 1, 2019.
Societal Benefits Clause
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:
2017 SBC filing — In September 2017, the BPU approved NJNG’s annual USF compliance filing to decrease the statewide USF rate, which will result in a $2.6 million annual decrease, effective October 1, 2017. On July 25, 2018, the BPU approved NJNG's annual SBC filing requesting to recover remediation expenses incurred through June 30, 2017, a reduction in the RAC, which resulted in an annual decrease of $2.4 million, and to increase the NJCEP factor, which will result in an annual increase of $1.8 million, effective September 1, 2018.
2018 SBC filing — On September 17, 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which will result in a $1 million annual increase, effective October 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, an increase in the RAC, which will result in an annual increase of $1.4 million, and an increase to the NJCEP factor, which will result in an annual increase of approximately $1.9 million, effective April 1, 2019.
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 gas distribution system, including SAFE and NJ RISE.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
SAFE/NJ RISE
The SAFE program replaces portions of NJNG’s gas distribution unprotected steel, cast iron infrastructure and associated services to improve the safety and reliability of the gas distribution system. SAFE I was approved to invest up to $130 million, exclusive of AFUDC, over a four-year period. The recovery of SAFE I capital investments and the corresponding rate mechanism were classifiedapproved through NJNG’s base rate case effective October 2016. SAFE II was approved to invest up to $200 million, excluding AFUDC, over a five-year period. NJNG will recover approximately $157.5 million through annual rate filings, with the remainder recovered through subsequent rate cases. As a condition of approval of the program, NJNG is required to file a base rate case no later than November 2019.
NJ RISE consists of six capital investment projects estimated to cost $102.5 million over a five-year period, excluding AFUDC, for gas distribution storm-hardening and mitigation projects, along with incremental depreciation expense. NJ RISE includes a weighted average cost of capital that ranges from 6.74 percent to 6.9 percent and a return on equity of 9.75 percent. NJ RISE investments through June 30, 2016, were approved for recovery through NJNG’s new base rates effective October 2016. Requests for recovery of future NJ RISE capital costs will occur in conjunction with SAFE II.
In September 2017, the BPU approved NJNG’s annual petition requesting a base rate increase for the recovery of NJ RISE and SAFE II capital investment costs with an annual increase of $4.1 million effective October 1, 2017. On September 17, 2018, the BPU approved NJNG’s petition requesting a base rate increase of $6.8 million annually for the recovery of SAFE II and NJ RISE capital investment costs related to the 12 months ending June 30, 2018 effective October 1, 2018.
SRL
The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system integrity and reliability in the southern portion of NJNG’s service territory, estimated to cost between $180 million and $215 million. In March 2016, the BPU issued an order designating the SRL route and exempting the SRL from municipal land use ordinances, regulations, permits and license requirements. In February 2017, the New Jersey Department of Environmental Protection issued a permit authorizing construction of the SRL within the jurisdiction of the Coastal Area Facility Review Act as well as a Freshwater Wetlands permit. In September 2017, the NJ Pinelands Commission approved construction of NJNG’s SRL. All approvals and permits have been appealed by third parties.
Other Regulatory Initiatives
In May 2016, NJNG included a proposal in its base rate case to recover certain capital costs and incremental operation and maintenance costs related to a March 2016 BPU Order regarding new cyber security requirements. Costs associated with this initiative were approved for recovery through NJNG’s base rates effective October 2016.
In June 2016, NJNG’s liquefaction project became operational, allowing NJNG to convert natural gas into LNG and to fill NJNG’s existing LNG storage tanks. Costs for this project along with other plant upgrades were approximately $36.5 million. Costs associated with this initiative were approved for recovery through NJNG’s base rates effective October 2016.
4. DERIVATIVE INSTRUMENTS
The Company is subject 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 may utilize foreign currency derivatives to hedge Canadian dollar denominated gas purchases and/or sales. Therefore, the Company’s primary underlying risks include commodity prices, interest rates and foreign currency. These contracts, with a few exceptions as described below, are accounted for as derivatives. 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 5. Fair Value.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Energy Services
Energy Services chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS. The changes in the fair value of these derivatives are recorded as a component of gas purchases or operating revenues, as appropriate for Energy Services, on the Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of 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 gas purchases or operating revenues.
Energy Services also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the U.S. dollar. Energy Services may utilize foreign currency derivatives to lock in the exchange rate 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 gas purchase agreements.
As a result of Energy Services entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Consolidated Balance Sheets, with changes in value recognized in current-period earnings.
Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. For transactions occurring on or before December 31, 2015, the Company elected NPNS accounting treatment on SREC forward and futures contracts. Effective January 1, 2016, on a prospective basis, Energy Services no longer elects NPNS accounting treatment on SREC contracts entered into from January 1, 2016, and 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. NPNS is a contract-by-contract election and, where it makes sense to do so, we can and may elect certain contracts to be normal.
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 amortized in current-period earnings based on the current BPU BGSS factor and therm sales. Effective January 1, 2016, on a prospective basis, NJNG no longer elects NPNS accounting treatment on all of its physical commodity contracts entered into from January 1, 2016. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect certain contracts to be 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 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Home Services and Other
On January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on its existing $100 million variable rate term loan, which fixed the variable rate at 2.84 percent. The swap will terminate on August 16, 2019, which coincides with the maturity of long-termthe debt. The change in the fair value of the interest rate swap is recorded as interest expense on the Consolidated Statements of Operations.
Fair Value of Derivatives
The following table reflects the fair value of the Company’s derivative assets and liabilities recognized on the Consolidated Balance Sheets as of September 30:
|
| | | | | | | | | | | | | | | | | |
| | | | Fair Value |
| | | | 2018 | | 2017 |
| (Thousands) | Balance Sheet Location | Asset Derivatives | Liability Derivatives | Asset Derivatives | Liability Derivatives |
| Derivatives not designated as hedging instruments: | | | | | | | | |
| Natural Gas Distribution: | | | | | | | | | |
| Physical commodity contracts | Derivatives - current | | $ | 85 |
| | $ | 192 |
| | $ | 151 |
| | $ | 72 |
|
| Financial commodity contracts | Derivatives - current | | 94 |
| | — |
| | — |
| | 1,149 |
|
Interest rate contracts (1) | Derivatives - current | | — |
| | — |
| | — |
| | 8,467 |
|
| Energy Services: | | | | | | | | | |
| Physical commodity contracts | Derivatives - current | | 7,667 |
| | 18,158 |
| | 14,588 |
| | 16,589 |
|
| | Derivatives - noncurrent | | 3,930 |
| | 11,316 |
| | 7,127 |
| | 8,710 |
|
| Financial commodity contracts | Derivatives - current | | 19,169 |
| | 28,176 |
| | 15,302 |
| | 20,267 |
|
| | Derivatives - noncurrent | | 6,630 |
| | 11,548 |
| | 2,033 |
| | 2,620 |
|
| Foreign currency contracts | Derivatives - current | | — |
| | 126 |
| | 40 |
| | — |
|
| | Derivatives - noncurrent | | — |
| | 118 |
| | 4 |
| | — |
|
| Home Services and Other: | | | | | | | | | |
| Interest rate contracts | Derivatives - current | | 381 |
| | — |
| | — |
| | — |
|
| Total fair value of derivatives | | | $ | 37,956 |
| | $ | 69,634 |
| | $ | 39,245 |
| | $ | 57,874 |
|
| |
| (1) | Includes treasury lock which was settled in March 2018. See Note 8. Debt for more information. |
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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral and the net amounts the Company could present on the Consolidated Balance Sheets but elects not to.
|
| | | | | | | | | | | | | | | | |
| (Thousands) | Amounts Presented in Balance Sheets (1) | Offsetting Derivative Instruments (2) | Financial Collateral Received/Pledged (3) | Net Amounts (4) |
| As of September 30, 2018: | | | | | | | | |
| Derivative assets: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 11,597 |
| | $ | (3,944 | ) | | $ | (200 | ) | | $ | 7,453 |
|
| Financial commodity contracts | | 25,799 |
| | (18,775 | ) | | — |
| | 7,024 |
|
| Total Energy Services | | $ | 37,396 |
| | $ | (22,719 | ) | | $ | (200 | ) | | $ | 14,477 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 85 |
| | $ | (3 | ) | | $ | — |
| | $ | 82 |
|
| Financial commodity contracts | | 94 |
| | — |
| | (94 | ) | | — |
|
| Total Natural Gas Distribution | | $ | 179 |
| | $ | (3 | ) | | $ | (94 | ) | | $ | 82 |
|
| Home Services and Other | | | | | | | | |
| Interest rate contracts | | $ | 381 |
| | $ | — |
| | $ | — |
| | $ | 381 |
|
| Total Home Services and Other | | $ | 381 |
| | $ | — |
| | $ | — |
| | $ | 381 |
|
| Derivative liabilities: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 29,474 |
| | $ | (3,944 | ) | | $ | — |
| | $ | 25,530 |
|
| Financial commodity contracts | | 39,724 |
| | (18,775 | ) | | (20,949 | ) | | — |
|
| Foreign currency contracts | | 244 |
| | — |
| | — |
| | 244 |
|
| Total Energy Services | | $ | 69,442 |
| | $ | (22,719 | ) | | $ | (20,949 | ) | | $ | 25,774 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 192 |
| | $ | (3 | ) | | $ | — |
| | $ | 189 |
|
| Total Natural Gas Distribution | | $ | 192 |
| | $ | (3 | ) | | $ | — |
| | $ | 189 |
|
| As of September 30, 2017: | | | | | | | | |
| Derivative assets: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 21,715 |
| | $ | (2,173 | ) | | $ | (200 | ) | | $ | 19,342 |
|
| Financial commodity contracts | | 17,335 |
| | (14,121 | ) | | — |
| | 3,214 |
|
| Foreign currency contracts | | 44 |
| | — |
| | — |
| | 44 |
|
| Total Energy Services | | $ | 39,094 |
| | $ | (16,294 | ) | | $ | (200 | ) | | $ | 22,600 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
|
| Total Natural Gas Distribution | | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
|
| Derivative liabilities: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 25,299 |
| | $ | (2,173 | ) | | $ | — |
| | $ | 23,126 |
|
| Financial commodity contracts | | 22,887 |
| | (14,121 | ) | | (8,766 | ) | | — |
|
| Total Energy Services | | $ | 48,186 |
| | $ | (16,294 | ) | | $ | (8,766 | ) | | $ | 23,126 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 72 |
| | $ | (20 | ) | | $ | — |
| | $ | 52 |
|
| Financial commodity contracts | | 1,149 |
| | — |
| | (1,149 | ) | | — |
|
| Interest rate contracts | | 8,467 |
| | — |
| | — |
| | 8,467 |
|
| Total Natural Gas Distribution | | $ | 9,688 |
| | $ | (20 | ) | | $ | (1,149 | ) | | $ | 8,519 |
|
| |
| (1) | Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20. |
| |
| (2) | Offsetting derivative instruments include 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. |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical 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 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, create volatility in the results of Energy Services, although the Company’s intended economic results relating to the entire transaction are unaffected.
The following table reflects the effect of derivative instruments on the Consolidated Statements of Operations as of September 30:
|
| | | | | | | | | | | | |
| (Thousands) | Location of gain (loss) recognized in income on derivatives | Amount of gain (loss) recognized in income on derivatives |
| Derivatives not designated as hedging instruments: | 2018 | | 2017 | | 2016 |
| Energy Services: | | | | | | |
| Physical commodity contracts | Operating revenues | $ | (9,311 | ) | | $ | 8,912 |
| | $ | 33,034 |
|
| Physical commodity contracts | Gas purchases | (197 | ) | | (27,461 | ) | | (45,637 | ) |
| Financial commodity contracts | Gas purchases | (24,622 | ) | | 26,563 |
| | 45,579 |
|
| Foreign currency contracts | Gas purchases | (379 | ) | | 41 |
| | (34 | ) |
| Home Services and Other: | | | | | | |
| Interest rate contracts | Interest expense | 334 |
| | — |
| | — |
|
| Total unrealized and realized gains (losses) | $ | (34,175 | ) | | $ | 8,055 |
| | $ | 32,942 |
|
NJNG’s derivative contracts are part of the Company’s risk management activities that relate to its natural gas purchases, BGSS incentive programs and debt financing. These transactions are entered into pursuant to regulatory approval and, at settlement, the resulting gains and/or losses are payable to or recoverable from utility customers. Any changes in the value of NJNG’s financial derivatives are deferred in regulatory assets or liabilities resulting in no impact to earnings.
The following table reflects the (losses) gains associated with NJNG’s derivative instruments as of September 30:
|
| | | | | | | | | | | |
| (Thousands) | 2018 | | 2017 | | 2016 |
| Natural Gas Distribution: | | | | | |
| Physical commodity contracts | $ | 1,232 |
| | $ | (12,303 | ) | | $ | (15,756 | ) |
| Financial commodity contracts | 1,844 |
| | 5,595 |
| | (7,984 | ) |
| Interest rate contracts | 8,467 |
| | 14,606 |
| | (18,845 | ) |
| Total unrealized and realized (losses) gains | $ | 11,543 |
| | $ | 7,898 |
| | $ | (42,585 | ) |
NJNG and Energy Services had the following outstanding long (short) derivatives as of September 30:
|
| | | | | | | |
| | | | Volume (Bcf) |
| | | | 2018 | | 2017 |
| Natural Gas Distribution | Futures | | 27.9 |
| | 18.2 |
|
| | Physical | | 23.1 |
| | 32.1 |
|
| Energy Services | Futures | | (7.0 | ) | | (16.4 | ) |
| | Physical | | 51.2 |
| | (13.1 | ) |
Not included in the previous table are Energy Services’ gross notional amount of foreign currency transactions of approximately $8.5 million, interest rate contracts, as previously discussed, and 698,700 SRECs at Energy Services that are open as of September 30, 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Broker Margin
Futures exchanges have contract-specific performance bond requirements, also known as margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin, which is posted upon the initiation of a position, maintenance margin, which is usually expressed as a percent of initial margin, and variation margin, which fluctuates based on the daily marked-to-market relative to maintenance margin requirements. The Company maintains separate broker margin accounts for the Natural Gas Distribution and Energy Services segments. The balances as of September 30, by segment, are as follows:
|
| | | | | | | |
| (Thousands) | Balance Sheet Location | 2018 | 2017 |
| Natural Gas Distribution | Broker margin - Current assets | $ | 2,038 |
| $ | 2,661 |
|
| Energy Services | Broker margin - Current assets | $ | 51,681 |
| $ | 23,166 |
|
Due to CME rulebook changes that took effect in January 2017, variation margin is being treated as a settlement payment, rather than collateral. As a result, the Company is now required to present variation margin net with the related derivative assets and/or liabilities on the Consolidated Balance Sheets for any derivatives the Company clears through the CME.
Wholesale Credit Risk
NJNG, Energy Services and Clean Energy Ventures are exposed to credit risk as a result of their sales/wholesale and retail marketing activities. As a result of the inherent volatility in the prices of natural gas commodities, derivatives, SRECs, electricity and RECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty fails to perform the obligations under its contract (e.g., fails to deliver or pay for natural gas, SRECs, electricity or RECs), 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 S&P or Moody’s. In these cases, the counterparty’s or guarantor’s financial statements are reviewed, and similar methodologies and ratios used by S&P and/or Moody’s are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.
The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of September 30, 2018.The amounts presented below have not been reduced by any collateral received or netting and exclude accounts receivable for NJNG retail natural gas sales and services and Clean Energy Ventures residential solar installations.
|
| | | | | |
| (Thousands) | Gross Credit Exposure |
| Investment grade | | $ | 179,982 |
| |
| Noninvestment grade | | 43,486 |
| |
| Internally-rated investment grade | | 30,786 |
| |
| Internally-rated noninvestment grade | | 25,750 |
| |
| Total | | $ | 280,004 |
| |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Conversely, certain of NJNG’s and Energy Services’ derivative instruments are linked to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG’s credit rating were to fall below its current level. NJNG’s credit rating, with respect to S&P, reflects the overall corporate credit profile of the Company. Specifically, most, but not all, of these additional payments will be triggered if NJNG’s debt is downgraded by the major credit agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings, but are based on certain financial metrics.
Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company’s credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on September 30, 2018 and 2017, is approximately $124,000 and $8.7 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on September 30, 2018 and 2017, the Company would have been required to post an additional $33,000 and $8.6 million, respectively, to its counterparties. 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.
5. FAIR VALUE
Fair Value of Assets and Liabilities
The fair value of cash and cash equivalents, accounts receivable, current loan receivables, accounts payable, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. Non-current loan receivables are recorded based on what the Company expects to receive, which approximates fair value. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.
As of September 30, the estimated fair value of long-term debt at NJNG and NJR, including current maturities, excluding capital leases, debt issuance costs and solar asset financing obligations, is as follows (1):
|
| | | | | | |
| (Thousands) | 2018 | 2017 |
| NJNG | | |
| Carrying value | $ | 672,045 |
| $ | 672,045 |
|
| Fair market value | $ | 669,162 |
| $ | 673,051 |
|
| NJR | | |
| Carrying value | $ | 500,000 |
| $ | 425,000 |
|
| Fair market value | $ | 488,889 |
| $ | 434,625 |
|
| |
| (1) | SeeNote 8. Debt for a reconciliation to long-term and short-term debt. |
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, 2018 and 2017, the Company disclosed its debt within Level 2 of the fair value hierarchy.
Fair Value Hierarchy
The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs.
The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and includes the following:
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
| |
| 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 internally to as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM. |
| |
| Level 2 | Other significant observable inputs, such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is: |
widely accepted and public;
non-proprietary and sourced from an independent third party; and
observable and published.
These additional adjustments are generally not considered to be significant to the ultimate recognized values.
| |
| Level 3 | Inputs derived from a significant amount of unobservable market data. These include the Company’s best estimate of fair value and are derived primarily through the use of internal valuation methodologies. |
Financial derivative portfolios of NJNG and Energy Services consist mainly of futures, options and swaps. The Company primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market; therefore, the primary sources for its price inputs are CME, NYMEX and ICE. Energy Services uses Platts and Natural Gas Exchange for Canadian delivery points. However, Energy Services also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the transportation cost to the final delivery location is not significant to the overall valuation. If required, Energy Services’ policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or other pricing services.
The Company also has available for sale securities and 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Assets and liabilities measured at fair value on a recurring basis are summarized as follows:
|
| | | | | | | | | | | | | | | | | | |
| | Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Significant Unobservable Inputs | |
| (Thousands) | (Level 1) | (Level 2) | (Level 3) | Total |
| As of September 30, 2018: | | | | | | | | | | |
| Assets | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 11,682 |
| | | $ | — |
| | $ | 11,682 |
|
| Financial commodity contracts | | 18,868 |
| | | 7,025 |
| | | — |
| | 25,893 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | — |
| | | — |
| | — |
|
| Interest rate contract | | — |
| | | 381 |
| | | — |
| | 381 |
|
| Available for sale equity securities | | 32,917 |
| | | — |
| | | — |
| | 32,917 |
|
Other (1) | | 1,217 |
| | | — |
| | | — |
| | 1,217 |
|
| Total assets at fair value | | $ | 53,002 |
| | | $ | 19,088 |
| | | $ | — |
| | $ | 72,090 |
|
| Liabilities | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 29,666 |
| | | $ | — |
| | $ | 29,666 |
|
| Financial commodity contracts | | 39,724 |
| | | — |
| | | — |
| | 39,724 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | 244 |
| | | — |
| | 244 |
|
| Total liabilities at fair value | | $ | 39,724 |
| | | $ | 29,910 |
| | | $ | — |
| | $ | 69,634 |
|
| As of September 30, 2017: | | | | | | | | | | |
| Assets | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 21,866 |
| | | $ | — |
| | $ | 21,866 |
|
| Financial commodity contracts | | 17,335 |
| | |
| | |
|
| | 17,335 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | 44 |
| | | — |
| | 44 |
|
| Available for sale equity securities | | 65,752 |
| | | — |
| | | — |
| | 65,752 |
|
Other (1) | | 1,202 |
| | | — |
| | | — |
| | 1,202 |
|
| Total assets at fair value | | $ | 84,289 |
| | | $ | 21,910 |
| | | $ | — |
| | $ | 106,199 |
|
| Liabilities | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 25,371 |
| | | $ | — |
| | $ | 25,371 |
|
| Financial commodity contracts | | 24,036 |
| | | — |
| | | — |
| | 24,036 |
|
| Interest rate contract | | — |
| | | 8,467 |
| | | — |
| | 8,467 |
|
| Total liabilities at fair value | | $ | 24,036 |
| | | $ | 33,838 |
| | | $ | — |
| | $ | 57,874 |
|
| |
| (1) | Includes money market funds. |
During the second quarter of fiscal 2018, the Company evaluated the decrease in fair value of its available for sale securities on a nonrecurring basis and determined that the decline was other-than-temporary. Accordingly, the Company recognized an other-than-temporary impairment of $17.8 million, which was determined using quoted market prices for identical publicly traded equity securities on an active exchange. As of March 31, 2018, the Company’s available for sale securities had a fair value of $28.2 million.See the Company’s discussion of available for sale securities in Note 2. Summary of Significant Accounting Policies for more information regarding the impairment.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
6. INVESTMENTS IN EQUITY INVESTEES
As of September 30, the Company’s investments in equity method investees includes the following:
|
| | | | | | |
| (Thousands) | 2018 | 2017 |
Steckman Ridge (1) | $ | 117,001 |
| $ | 120,262 |
|
| PennEast | 73,865 |
| 52,323 |
|
| Total | $ | 190,866 |
| $ | 172,585 |
|
(1)Includes loans with a total outstanding principal balance of $70.4 million for both fiscal 2018 and 2017, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.
The Company, through its subsidiary NJR Pipeline Company, is an investor in PennEast, which is expected to construct and operate a 120-mile pipeline that will extend from northeast Pennsylvania to western New Jersey. PennEast has advised that it currently expects the pipeline to be completed and operational in 2019; however, the project could be delayed beyond 2019 due to factors that are beyond PennEast’s ability to control or estimate precisely, including potential delays in obtaining (or the inability to obtain) governmental and regulatory approvals and land-use rights, and unforeseen construction delays.
NJNG and Energy Services have entered into storage and park and loan agreements with Steckman Ridge. In addition, NJNG has entered into a precedent capacity agreement with PennEast. See Note 15. Related Party Transactions for more information on these intercompany transactions.
7. EARNINGS PER SHARE
The following table presents the calculation of the Company’s basic and diluted earnings per share for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Thousands, except per share amounts) | 2018 | 2017 | 2016 |
| Net income, as reported | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| Basic earnings per share | | | |
| Weighted average shares of common stock outstanding-basic | 87,689 |
| 86,321 |
| 85,884 |
|
| Basic earnings per common share | $2.66 | $1.53 | $1.53 |
| Diluted earnings per share | | | |
| Weighted average shares of common stock outstanding-basic | 87,689 |
| 86,321 |
| 85,884 |
|
Incremental shares (1) | 626 |
| 823 |
| 847 |
|
| Weighted average shares of common stock outstanding-diluted | 88,315 |
| 87,144 |
| 86,731 |
|
Diluted earnings per common share (2) | $2.64 | $1.52 | $1.52 |
| |
| (1) | Incremental shares consist primarily of unvested stock awards and performance units. |
| |
| (2) | There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for fiscal 2018, 2017 and 2016. |
8. DEBT
NJNG and NJR finance working capital requirements and capital expenditures through the issuance of various long-term debt and other financing arrangements, including unsecured credit and private placement debt shelf facilities. Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Sale-Leasebacks
NJNG utilizes sale-leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease at the end of the term or repurchase the asset. Proceeds from sale-leaseback transactions are accounted for as financings and are included in long-term debt on the Consolidated Balance Sheets. During fiscal 2018 and 2017, NJNG received $7.8 million and $9.6 million, respectively, in connection with the sale-leaseback of its natural gas meters with terms ranging from seven to 11 years.
In addition, for certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third parties and the concurrent leaseback of the assets. For sale-leaseback transactions where the Company has concluded that the terms of the arrangement create a continuing involvement in the asset and the asset is
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
considered integral equipment, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the 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.
Clean Energy Ventures received $71.5 million and $32.9 million in proceeds related to the sale of commercial solar assets during fiscal 2018 and 2017, respectively. Clean Energy Ventures simultaneously entered into agreements to lease the assets back over six to 15-year terms. The Company will continue to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects have been transferred to the buyer; however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. Clean Energy Ventures did not enter into sale-leaseback during fiscal 2016 and therefore recognized the full ITC in income tax (benefit) provision on the Consolidated Statements of Operations when the assets were placed in service.
Environmental Contingencies
Loss contingencies are recorded as liabilities when it is probable a liability has been incurred and the amount of the loss is reasonably estimable in accordance with accounting standards for contingencies. Estimating probable losses requires an analysis of uncertainties that often depend upon judgments about potential actions by third parties. Accruals for loss contingencies are recorded based on an analysis of potential results.
With respect to environmental liabilities and related costs, NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination. See Note 13. Commitments and Contingent Liabilities for more details.
Pension and Postemployment Plans
The Company has two noncontributory defined pension plans covering eligible employees, including officers. Benefits are based on each employee’s years of service and compensation. The Company’s funding policy is to contribute annually to these plans at least the minimum amount required under the Employee Retirement Income Security Act, as amended, and not more than can be deducted for federal income tax purposes. Plan assets consist of equity securities, fixed-income securities and short-term investments. The Company made a discretionary contribution of $30 million during the first quarter of fiscal 2016 to improve the funded status of the pension plans based on the current actuarial assumptions, which included the adoption of the most recent mortality table. The Company made no discretionary contributions to the pension plans in fiscal 2018 and 2017.
The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds. The Company contributed $6.2 million, $6 million and $3.2 million in aggregate to these plans in fiscal 2018, 2017 and 2016, respectively, which is recorded in postemployment employee benefit liability on the Consolidated Balance Sheets.
See Note 10. Employee Benefit Plans, for a more detailed description of the Company’s pension and postemployment plans.
Asset Retirement Obligations
The Company recognizes AROs related to the costs associated with cutting and capping NJNG’s main and service gas distribution mains, which is required by New Jersey law when taking such gas distribution mains out of service. The Company also recognizes AROs associated with Clean Energy Ventures’ solar and wind assets when there are decommissioning provisions in lease agreements that require removal of the asset at the end of the lease term.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
AROs are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations. Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets.
Estimating future removal costs requires management to make significant judgments because most of the removal obligations span long time frames and removal may be conditioned upon future events. Asset removal technologies are also constantly changing, which makes it difficult to estimate removal costs. Accordingly, inherent in the estimate of AROs 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 assign probabilities based on management’s reasonable judgment and knowledge of industry practice. Accordingly, AROs are subject to change.
Accumulated Other Comprehensive Income
The following table presents the changes in the components of accumulated other comprehensive income, net of related tax effects, as of September 30:
|
| | | | | | | | | | | |
| (Thousands) | Unrealized gain (loss) on available for sale securities | Adjustment to postemployment benefit obligation | Total |
| Balance as of September 30, 2016 | $ | 4,198 |
| | $ | (19,353 | ) | | $ | (15,155 | ) |
| Other comprehensive income, net of tax | | | | | |
| Other comprehensive income, before reclassifications, net of tax of $(6,593), $(2,619), $(9,212) | 10,019 |
| | 3,783 |
| | 13,802 |
|
| Amounts reclassified from accumulated other comprehensive (loss) income, net of tax of $2,192, $(868), $1,324 | (3,173 | ) | | 1,270 |
| (1) | (1,903 | ) |
| Net current-period other comprehensive income, net of tax of $(4,401), $(3,487), $(7,888) | 6,846 |
| | 5,053 |
| | 11,899 |
|
| Balance at September 30, 2017 | $ | 11,044 |
| | $ | (14,300 | ) | | $ | (3,256 | ) |
| Other comprehensive income, net of tax | | | | | |
| Other comprehensive (loss) income, before reclassifications, net of tax of $6,973, $(125), $6,848 | (19,245 | ) | | 464 |
| | (18,781 | ) |
| Amounts reclassified from accumulated other comprehensive income, net of tax of $(858), $(448), $(1,306) | 11,647 |
| | 1,056 |
| (1) | 12,703 |
|
| Net current-period other comprehensive (loss) income, net of tax of $6,115, $(573), $5,542 | (7,598 | ) | | 1,520 |
| | (6,078 | ) |
Reclassifications of certain income tax effects to retained earnings (2)
| — |
| | (3,276 | ) | | (3,276 | ) |
| Balance at September 30, 2018 | $ | 3,446 |
| | $ | (16,056 | ) | | $ | (12,610 | ) |
| |
| (1) | Included in the computation of net periodic pension cost, a component of O&M expense on the Consolidated Statements of Operations. For more details, see Note 10. Employee Benefit Plans. |
| |
| (2) | Due to the adoption of ASU No. 2018-02, an amendment to ASC 740, Income Taxes. See Note 2. Summary of Significant Accounting Policies- Recently Adopted Updates to the Accounting Standards Codification section for more details. |
Foreign Currency Transactions
The market area of Energy Services includes Canadian delivery points and as a result, Energy Services incurs certain natural gas commodity costs and demand fees denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of gas purchases on the Consolidated Statements of Operations. Gains and losses recognized for the fiscal years ended September 30, 2018, 2017 and 2016, are considered immaterial.
Reclassification
Certain prior period amounts related to the amortization of acquired wholesale energy contracts on the Consolidated Statements of Cash Flows and in the deferred tax table in Note 12. Income Taxes for the fiscal year ended September 30, 2017, were reclassified to conform to the current period presentation.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Recently Adopted Updates to the Accounting Standards Codification
Inventory
In July 2015, the FASB issued ASU No. 2015-11, an amendment to ASC 330, Inventory, which requires entities to measure most inventory “at the lower of cost or net realizable value,” thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. The Company adopted the new guidance in the first quarter of fiscal 2018 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.
Reporting Comprehensive Income
In February 2018, the FASB issued ASU No. 2018-02, an amendment to ASC 220, Income Statement - Reporting Comprehensive Income, which allows for the reclassification from accumulated other comprehensive income to retained earnings for the disproportionate tax effects of the Tax Act. The Company early adopted this guidance in the fourth quarter of fiscal 2018 and reclassified on a prospective basis only, $3.3 million from accumulated other comprehensive income to retained earnings. This did not materially impact the Company’s financial position, results of operations or cash flows.
Tax
In March 2018, the FASB issued ASU No. 2018-05, an amendment to ASC 740, Income Taxes, which provides relief to entities in their calculation of the effects of the Tax Act by allowing them to record provisional amounts for certain income tax effects to address circumstances in which an entity does not have the necessary information available, prepared or analyzed to complete the accounting. These provisional amounts are subject to change as information and assumptions are updated throughout the measurement period, which may not extend beyond one year from the enactment date. The new guidance was effective immediately upon issuance, and the Company adopted the new guidance in the second quarter of fiscal 2018 and applied the new provision on a prospective basis.
Other Recent Updates to the Accounting Standards Codification
Revenue
In May 2014, the FASB issued ASU No. 2014-09, and added ASC 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries, jurisdictions and capital markets. The Company adopted the new guidance on October 1, 2018, and will apply the new provisions on a modified retrospective basis.
Management established an implementation team to evaluate the impact on the Company’s financial position, results of operations and cash flows upon adoption of ASC 606. This implementation team reviewed the revenue streams of all of its subsidiaries and formed conclusions to determine if any system, process, controls and organizational changes are necessary upon adoption. The assessment of the impact of this guidance included reviewing the Company’s accounting policies under ASC 605 and identifying potential differences after the adoption of ASC 606. The Company concluded that its tariff-based sales of natural gas will be within the scope of the new guidance and it does not anticipate any modification to the pattern of revenue recognition from such sales. Revenues from derivative instruments such as those related to the Company’s SREC sales and natural gas purchases and sales will continue to be accounted for under ASC 815 and thus are outside the scope of ASC 606. Additionally, NJNG revenues generated by the CIP have been determined to be alternative revenue programs under ASC 980 and are also outside the scope of ASC 606 as they are deemed to be a contract with the regulator. The Company also evaluated its renewable asset PPA arrangements and does not anticipate any modification to the pattern of revenue recognition of the related electricity, capacity and REC sales. Revenues from RECs sold as part of a bundled arrangement will be recognized in the same period as the related generation, consistent with current practice.
The Company has completed its evaluation of its revenue streams, and based on the assessment performed, has concluded that the new guidance will not have a material impact on its financial position, results of operations or cash flows upon adoption. Additionally, the Company did not implement significant changes to its business processes, systems or internal controls over financial reporting upon adoption. ASC 606 requires expanded disclosures, including the disclosure of performance obligations, disaggregated revenues and contract balances, which the Company will include in its financial statements beginning in the first quarter of fiscal 2019.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Financial Instruments
In January 2016, the FASB issued ASU No. 2016-01, an amendment to ASC 825, Financial Instruments, to address certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certain fair value changes for financial liabilities measured at fair value. It also simplifies the impairment assessment of equity investments without a readily determinable fair value by requiring a qualitative assessment. The guidance is effective for the Company beginning October 1, 2018. The amendment will be applied on a modified retrospective basis. The Company evaluated the amendment and noted that, upon adoption, subsequent changes to the fair value of the Company’s available for sale securities will be recorded in the Consolidated Statement of Operations as opposed to other comprehensive income. The Company will reclassify $3.4 million in accumulated other comprehensive income related to available for sale securities to the opening balance of retained earnings as of October 1, 2018. There will be no material impact to the Company’s financial position, results of operations or cash flows upon adoption.
In June 2016, the FASB issued ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. An entity will apply the amendment through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.
Leases
In February 2016, the FASB issued ASU No. 2016-02, an amendment to ASC 842, Leases, which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption.
In January 2018, the FASB issued ASU No. 2018-01, a further amendment to ASC 842, Leases, which was introduced by ASU No. 2016-02, as discussed above. This update provides an optional practical expedient that allows companies to not evaluate existing or expired land easements that were not previously accounted for under Topic 840 as leases. The Company expects to elect this practical expedient upon adoption. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted.
In July 2018, the FASB issued ASU No. 2018-11, which provides an optional transition method to ASC 842 that allows the Company to recognize a cumulative effect adjustment to the opening balance of retained earnings in the period of adoption. At this time, the Company does not plan to early adopt the new guidance and expects to transition on a modified retrospective basis. While the Company is currently evaluating the full impact of the standard and its related updates, it expects to recognize additional assets and liabilities arising from current operating leases to its financial position upon adoption. Current operating leases primarily consist of office and land leases related to the Company’s solar and wind assets.
Statement of Cash Flows
In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company beginning October 1, 2018. The amendment will be applied on a retrospective basis and the Company does not expect any material impacts to its statement of cash flows.
In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its statement of cash flows.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Intangibles
In August 2018, the FASB issued ASU No. 2018-15, an amendment to ASC 350, Intangibles - Goodwill and Other, which aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective or retrospective basis.
Business Combinations
In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on the accounting framework that is applied to acquisitions.
Gains and Losses from the Derecognition of Nonfinancial Assets
In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company as of October 1, 2018 and will be applied retrospectively with a cumulative effect adjustment at the date of adoption. The Company had a deferred gain of $6.8 million related to nonfinancial assets on the balance sheet, which will be recognized under the new accounting guidance as a cumulative effect adjustment to the opening balance of retained earnings as of October 1, 2018.
Compensation - Retirement Benefits
In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The amendment establishes a practical expedient that permits entities to use their previously disclosed service and other costs in their pension and other postretirement benefit plan footnotes in the prior comparative periods as the estimation basis when applying the retrospective presentation of these costs in the income statement. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis for income statement presentation, and on a prospective basis for changes to capitalization of costs. The changes related to the costs that will be eligible for capitalization and based on the components of net periodic benefit costs during fiscal year 2018, will not have a material impact on the Company's financial position, results of operations or cash flows upon adoption
In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures, and adds new disclosure requirements identified as relevant. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a retrospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on the Company's disclosures upon adoption.
Stock Compensation
In May 2017, the FASB issued ASU No. 2017-09, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for changes to the terms or conditions of share-based payments. The guidance is effective for the Company beginning October 1, 2018, and will be applied prospectively to awards modified on or after the adoption date. There was no material impact to the Company's financial position, results of operations or cash flows upon adoption.
In June 2018, the FASB issued ASU No. 2018-07, an amendment to ASC 718, Compensation - Stock Compensation, which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from non-employees. The guidance is effective for the Company beginning October 1, 2019, with early adoption permitted. The Company is currently evaluating the impact of the amendment on the Company’s financial position, results of operations and cash flows upon adoption.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Derivatives and Hedging
In August 2017, the FASB issued ASU No. 2017-12, an amendment to ASC 815, Derivatives and Hedging, which is intended to make targeted improvements to the accounting for hedging activities by better aligning an entity’s risk management activities and financial reporting for hedging relationships. These amendments modify the accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Additionally, the amendments are intended to simplify the application of the hedge accounting guidance and provide relief to companies by easing certain hedge documentation requirements. The guidance is effective for the Company beginning October 1, 2019, with early adoption permitted. Upon adoption, the transition requirements and elections will be applied to hedging relationships existing on the date of adoption. The Company does not currently apply hedge accounting to any of its risk management activities and thus does not expect the amendments to have any impact on its financial position, results of operations and cash flows upon adoption.
Fair Value
In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective or retrospective basis depending on the specific amendments’ transition requirements. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption and will apply the new guidance.
3. 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 gas to NJNG’s service territory; and the delivery portion, which represents the transportation of the commodity portion through NJNG’s gas distribution system to the end-use customer. NJNG does not earn utility gross margin on the commodity portion of its natural gas sales. NJNG earns utility gross margin through the delivery of natural gas to its customers, regardless of whether it or a third-party supplier provides the wholesale natural gas commodity.
Under EDECA, the BPU is required to audit the state’s energy utilities every two years. The primary purpose of the audit is to ensure that utilities and their affiliates offering unregulated retail services do not have an unfair competitive advantage over nonaffiliated providers of similar retail services. A combined competitive services and management audit of NJNG commenced in August 2013. A draft management audit report was accepted by the BPU on July 23, 2014, for public comment. To date, NJNG has implemented all audit recommendations with the approval of BPU staff and is waiting for final BPU approval.
NJNG is subject to cost-based regulation; therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility capital investments based on the BPU’s approval. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets, and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.
NJNG’s recovery of costs is facilitated through its base rates, BGSS and other regulatory tariff riders. NJNG is required to make an annual filing to the BPU by June 1 of each year for review of its BGSS, CIP and other programs and related rates. Annual rate changes are requested to be effective at the beginning of the following fiscal year. The current base rate includes a weighted average cost of capital of 6.9 percent and a return on common equity of 9.75 percent. In addition, NJNG is permitted to request approval of certain rate or program changes on an interim basis. All rate and program changes are subject to proper notification and BPU review and approval.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Regulatory assets and liabilities included on the Consolidated Balance Sheets as of September 30, are composed of the following:
|
| | | | | | |
| (Thousands) | 2018 | 2017 |
| Regulatory assets-current | | |
| New Jersey Clean Energy Program | $ | 14,052 |
| $ | 14,202 |
|
| Underrecovered gas costs | 4,137 |
| 9,910 |
|
| Derivatives at fair value, net | 108 |
| 9,010 |
|
| Conservation Incentive Program | — |
| 17,669 |
|
| Total current regulatory assets | $ | 18,297 |
| $ | 50,791 |
|
| Regulatory assets-noncurrent | | |
| Environmental remediation costs: | | |
| Expended, net of recoveries | $ | 33,017 |
| $ | 28,547 |
|
| Liability for future expenditures | 130,800 |
| 149,000 |
|
| Deferred income taxes | 17,225 |
| 21,795 |
|
| SAVEGREEN | 8,636 |
| 16,302 |
|
| Postemployment and other benefit costs | 136,716 |
| 141,433 |
|
| Deferred storm damage costs | 10,858 |
| 13,030 |
|
| Cost of removal | 22,339 |
| — |
|
| Other noncurrent regulatory assets | 9,001 |
| 5,812 |
|
| Total noncurrent regulatory assets | $ | 368,592 |
| $ | 375,919 |
|
| Regulatory liability-current | | |
| Conservation Incentive Program | $ | 6,994 |
| $ | — |
|
| Derivatives at fair value, net | 1,191 |
| 78 |
|
| Total current regulatory liabilities | $ | 8,185 |
| $ | 78 |
|
| Regulatory liabilities-noncurrent | | |
Tax Act impact (1) | $ | 205,410 |
| $ | — |
|
| Cost of removal | — |
| 7,902 |
|
| New Jersey Clean Energy Program | 1,902 |
| 5,795 |
|
| Other noncurrent regulatory liabilities | 1,827 |
| 810 |
|
| Total noncurrent regulatory liabilities | $ | 209,139 |
| $ | 14,507 |
|
| |
| (1) | Includes an adjustment related to the re-measurement of NJNG's net deferred tax liabilities to reflect the change in federal tax rates enacted in the Tax Act, which is net of sales tax collected from customers. For a more detailed discussion, see Note 12. Income Taxes. |
Recovery of regulatory assets is subject to BPU approval, and therefore, if there are any changes in regulatory positions that indicate recovery is not probable, the related cost would be charged to income in the period of such determination.
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 2019. NJNG recovers the costs associated with its portion of the NJCEP obligation through its NJCEP rider, with interest.
Over and Underrecovered Gas Costs
NJNG recovers its cost of gas through the BGSS rate component of its customers’ bills. NJNG’s cost of 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 gas costs represent a regulatory liability that generally occurs when NJNG’s BGSS rates are higher than actual costs and requests approval to be returned to customers including interest, when applicable, in accordance with NJNG’s approved BGSS tariff. Conversely, underrecovered 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Derivatives
Derivatives are utilized by NJNG to manage the price risk associated with its natural gas purchasing activities and to participate in certain BGSS incentive programs. The gains and losses associated with NJNG’s derivatives are recoverable through its BGSS, as noted above, without interest. See Note 4. Derivative Instruments.
Conservation Incentive Program
The CIP permits NJNG to recover utility gross margin variations related to customer usage resulting from customer conservation efforts and mitigates the impact of weather on its margin. Such utility gross margin variations are recovered in the year following the end of the CIP usage year, without interest, and are subject to additional conditions, including an earnings test, a revenue test and an evaluation of BGSS related savings. This program has no expiration date.
Environmental Remediation Costs
NJNG is responsible for the cleanup of certain former gas manufacturing facilities. Actual expenditures are recovered from customers, with interest, over seven-year rolling periods, through a RAC rate rider. Recovery for NJNG’s estimated future liability will be requested and/or recovered when actual expenditures are incurred. See Note 13. 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, without interest, as approved by the BPU, over a two- to 10-year period depending upon the specific program incentive.
Postemployment and Other Benefit Costs
Postemployment and Other Benefit Costs represents NJNG’s underfunded postemployment benefit obligations, as well as a fiscal 2010 tax charge resulting from a change in the deductibility of federal subsidies associated with Medicare Part D, both of which are deferred as regulatory assets and are recoverable, without interest, in base rates. The BPU approved the recovery of the tax charge through NJNG’s base rates effective October 2016 over a seven-year amortization period. See Note 10. Employee Benefit Plans.
Deferred Storm Damage Costs
Portions of NJNG’s distribution system incurred significant damage as a result of Superstorm Sandy in October 2012. NJNG deferred the uninsured incremental O&M costs associated with its restoration efforts, which were approved for recovery by the BPU through NJNG’s base rates, without interest, effective October 2016 over a seven-year amortization period.
Cost of Removal
NJNG accrues and collects for cost of removal in base rates on its utility property, without interest. These costs are recorded in accumulated depreciation for regulatory reporting purposes, and actual costs of removal, without interest, will be recovered in subsequent rates, pursuant to the BPU order in docket number GR15111304 dated September 23, 2016. Consistent with GAAP, amounts recorded within accumulated depreciation for regulatory accounting purposes are reclassified out of accumulated depreciation to either a regulatory asset or a regulatory liability depending on whether actual cost of removal is still subject to collection or amounts overcollected will be refunded back to customers. NJNG’s prior regulatory liability represented customer collections in excess of actual expenditures, which the Company returned to customers as a reduction to depreciation expense.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Other Regulatory Assets
Other regulatory assets consist primarily of deferred costs associated with certain components of NJNG’s SBC, as discussed further in the regulatory proceedings section, and NJNG’s compliance with federal- and state-mandated PIM provisions. NJNG’s related costs to maintain the operational integrity of its distribution and transmission main are recoverable, without interest, subject to BPU review and approval. As of September 30, 2018, NJNG recorded $3.2 million of PIM in other regulatory assets, which is being recovered through base rates over a seven-year amortization period effective October 2016.
The Tax Act
On December 22, 2017, the Tax Act was signed into law, which resulted in a reduction in the federal corporate tax rate. As a result, NJNG recorded a regulatory liability, which included the revaluation of its deferred income taxes and the accounting of the income tax effects on the revaluation. The revaluation was based on certain assumptions and estimations NJNG made with respect to its deferred taxes, as well as the effects from the Tax Act, and as such is subject to change if and when assumptions are updated. See Note 12. Income Taxes for a more detailed discussion on the Tax Act.
On January 31, 2018, the BPU issued an Order which directed New Jersey utilities to submit filings to the BPU by March 2, 2018, to propose the prospective change in base rates as a result of the Tax Act to be effective April 1, 2018, the method to return to customers the overcollection of taxes in base rates from January 1, 2018, through March 31, 2018 and an outline of the method by which the excess deferred taxes would be returned to customers. The excess deferred taxes are primarily related to timing differences associated with utility plant depreciation and are subject to IRS normalization rules, which require amortization over the remaining life of the utility plant.
On March 1, 2018, NJNG submitted its required filing to the BPU proposing a $19.7 million base rate reduction and customer refunds of approximately $31 million, which is inclusive of state sales tax and interest at the Company’s short-term debt rate as specified in the Company’s last base rate case. On March 26, 2018, the BPU approved, on an interim basis, the $19.7 million rate reduction, effective April 1, 2018. On May 22, 2018, the BPU approved final rates and also customer refunds of the $31 million. These credits were returned to customer accounts in June 2018.
The following is a description of certain regulatory proceedings during fiscal 2017 and 2018:
BGSS and CIP
BGSS rates are normally revised on an annual basis. In addition, to manage the fluctuations in wholesale natural gas costs, NJNG has the ability to make two interim filings during each fiscal year to increase residential and small commercial customer BGSS rates on a self-implementing and provisional basis. NJNG is also permitted to refund or credit back a portion of the commodity costs to customers at any time given five days’ notice when the natural gas commodity costs decrease in comparison to amounts projected or to amounts previously collected from customers. Concurrent with the annual BGSS filing, NJNG files for an annual review of its CIP. NJNG’s annual BGSS and CIP filings are summarized as follows:
June 2016 BGSS/CIP filing — In September 2016, the BPU approved NJNG’s filing to increase its CIP rates resulting in a $43.9 million annual recovery increase and to decrease its annual BGSS rate for residential and small commercial customers resulting in a $22.6 million annual recovery decrease effective October 2016. This petition also included bill credits to residential and small commercial customers during the months of November 2016 through February 2017, as a result of a decline in the wholesale price of natural gas. A total of $42 million in bill credits were issued during fiscal 2017.
June 2017 BGSS/CIP filing — In March 2018, the BPU approved NJNG’s petition on a final basis to maintain its BGSS rate for residential and small commercial customers, increase its balancing charge rate, which resulted in a $3.7 million increase to the annual revenues credited to BGSS, and decrease its CIP rates, which resulted in a $16.2 million annual recovery decrease that was effective October 2017.
May 2018 BGSS/CIP filing — On September 17, 2018, the BPU provisionally approved NJNG’s annual petition to maintain its BGSS rate for residential and small commercial customers and increase its balancing charge rate, resulting in a $10.3 million increase to the annual revenues credited to BGSS, as well as changes to the CIP rates, which will result in a $30.9 million annual recovery decrease effective October 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 energy efficiency upgrades to promote energy efficiency incentives to its residential and commercial customers while stimulating state and local economies through the creation of jobs. Depending on the specific initiative or approval, NJNG recovers costs associated with the programs over a three- to 10-year period through a tariff rider mechanism.
As of September 30, 2018, the BPU has approved total SAVEGREEN investments of approximately $354.3 million, including $135 million that was approved on September 17, 2018, for a continuation of existing EE programs and the implementation of new programs through December 2021.
SAVEGREEN investments and costs are filed with the BPU on an annual basis. Since inception, $162 million in grants, rebates and loans have been provided to customers, with a total annual recovery of approximately $16.1 million. The recovery includes a weighted average cost of capital that ranges from 6.69 percent to 7.76 percent, with a return on equity of 9.75 percent to 10.3 percent, respectively. On October 16, 2018, NJNG requested a decrease in its EE recovery rate reflecting costs incurred through September 30, 2018, which will result in an annual decrease of $8.8 million, anticipated to be effective January 1, 2019.
Societal Benefits Clause
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:
2017 SBC filing — In September 2017, the BPU approved NJNG’s annual USF compliance filing to decrease the statewide USF rate, which will result in a $2.6 million annual decrease, effective October 1, 2017. On July 25, 2018, the BPU approved NJNG's annual SBC filing requesting to recover remediation expenses incurred through June 30, 2017, a reduction in the RAC, which resulted in an annual decrease of $2.4 million, and to increase the NJCEP factor, which will result in an annual increase of $1.8 million, effective September 1, 2018.
2018 SBC filing — On September 17, 2018, the BPU approved NJNG’s annual USF compliance filing to increase the statewide USF rate, which will result in a $1 million annual increase, effective October 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, an increase in the RAC, which will result in an annual increase of $1.4 million, and an increase to the NJCEP factor, which will result in an annual increase of approximately $1.9 million, effective April 1, 2019.
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 gas distribution system, including SAFE and NJ RISE.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
SAFE/NJ RISE
The SAFE program replaces portions of NJNG’s gas distribution unprotected steel, cast iron infrastructure and associated services to improve the safety and reliability of the gas distribution system. SAFE I was approved to invest up to $130 million, exclusive of AFUDC, over a four-year period. The recovery of SAFE I capital investments and the corresponding rate mechanism were approved through NJNG’s base rate case effective October 2016. SAFE II was approved to invest up to $200 million, excluding AFUDC, over a five-year period. NJNG will recover approximately $157.5 million through annual rate filings, with the remainder recovered through subsequent rate cases. As a condition of approval of the program, NJNG is required to file a base rate case no later than November 2019.
NJ RISE consists of six capital investment projects estimated to cost $102.5 million over a five-year period, excluding AFUDC, for gas distribution storm-hardening and mitigation projects, along with incremental depreciation expense. NJ RISE includes a weighted average cost of capital that ranges from 6.74 percent to 6.9 percent and a return on equity of 9.75 percent. NJ RISE investments through June 30, 2016, were approved for recovery through NJNG’s new base rates effective October 2016. Requests for recovery of future NJ RISE capital costs will occur in conjunction with SAFE II.
In September 2017, the BPU approved NJNG’s annual petition requesting a base rate increase for the recovery of NJ RISE and SAFE II capital investment costs with an annual increase of $4.1 million effective October 1, 2017. On September 17, 2018, the BPU approved NJNG’s petition requesting a base rate increase of $6.8 million annually for the recovery of SAFE II and NJ RISE capital investment costs related to the 12 months ending June 30, 2018 effective October 1, 2018.
SRL
The SRL is an approximately 30-mile, 30-inch transmission main designed to support improved system integrity and reliability in the southern portion of NJNG’s service territory, estimated to cost between $180 million and $215 million. In March 2016, the BPU issued an order designating the SRL route and exempting the SRL from municipal land use ordinances, regulations, permits and license requirements. In February 2017, the New Jersey Department of Environmental Protection issued a permit authorizing construction of the SRL within the jurisdiction of the Coastal Area Facility Review Act as well as a Freshwater Wetlands permit. In September 2017, the NJ Pinelands Commission approved construction of NJNG’s SRL. All approvals and permits have been appealed by third parties.
Other Regulatory Initiatives
In May 2016, NJNG included a proposal in its base rate case to recover certain capital costs and incremental operation and maintenance costs related to a March 2016 BPU Order regarding new cyber security requirements. Costs associated with this initiative were approved for recovery through NJNG’s base rates effective October 2016.
In June 2016, NJNG’s liquefaction project became operational, allowing NJNG to convert natural gas into LNG and to fill NJNG’s existing LNG storage tanks. Costs for this project along with other plant upgrades were approximately $36.5 million. Costs associated with this initiative were approved for recovery through NJNG’s base rates effective October 2016.
4. DERIVATIVE INSTRUMENTS
The Company is subject 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 may utilize foreign currency derivatives to hedge Canadian dollar denominated gas purchases and/or sales. Therefore, the Company’s primary underlying risks include commodity prices, interest rates and foreign currency. These contracts, with a few exceptions as described below, are accounted for as derivatives. 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 5. Fair Value.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Energy Services
Energy Services chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS. The changes in the fair value of these derivatives are recorded as a component of gas purchases or operating revenues, as appropriate for Energy Services, on the Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of 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 gas purchases or operating revenues.
Energy Services also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the U.S. dollar. Energy Services may utilize foreign currency derivatives to lock in the exchange rate 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 gas purchase agreements.
As a result of Energy Services entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Consolidated Balance Sheets, with changes in value recognized in current-period earnings.
Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. For transactions occurring on or before December 31, 2015, the Company elected NPNS accounting treatment on SREC forward and futures contracts. Effective January 1, 2016, on a prospective basis, Energy Services no longer elects NPNS accounting treatment on SREC contracts entered into from January 1, 2016, and 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. NPNS is a contract-by-contract election and, where it makes sense to do so, we can and may elect certain contracts to be normal.
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 amortized in current-period earnings based on the current BPU BGSS factor and therm sales. Effective January 1, 2016, on a prospective basis, NJNG no longer elects NPNS accounting treatment on all of its physical commodity contracts entered into from January 1, 2016. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect certain contracts to be 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 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Home Services and Other
On January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on its existing $100 million variable rate term loan, which fixed the variable rate at 2.84 percent. The swap will terminate on August 16, 2019, which coincides with the maturity of the debt. The change in the fair value of the interest rate swap is recorded as interest expense on the Consolidated Statements of Operations.
Fair Value of Derivatives
The following table reflects the fair value of the Company’s derivative assets and liabilities recognized on the Consolidated Balance Sheets as of September 30:
|
| | | | | | | | | | | | | | | | | |
| | | | Fair Value |
| | | | 2018 | | 2017 |
| (Thousands) | Balance Sheet Location | Asset Derivatives | Liability Derivatives | Asset Derivatives | Liability Derivatives |
| Derivatives not designated as hedging instruments: | | | | | | | | |
| Natural Gas Distribution: | | | | | | | | | |
| Physical commodity contracts | Derivatives - current | | $ | 85 |
| | $ | 192 |
| | $ | 151 |
| | $ | 72 |
|
| Financial commodity contracts | Derivatives - current | | 94 |
| | — |
| | — |
| | 1,149 |
|
Interest rate contracts (1) | Derivatives - current | | — |
| | — |
| | — |
| | 8,467 |
|
| Energy Services: | | | | | | | | | |
| Physical commodity contracts | Derivatives - current | | 7,667 |
| | 18,158 |
| | 14,588 |
| | 16,589 |
|
| | Derivatives - noncurrent | | 3,930 |
| | 11,316 |
| | 7,127 |
| | 8,710 |
|
| Financial commodity contracts | Derivatives - current | | 19,169 |
| | 28,176 |
| | 15,302 |
| | 20,267 |
|
| | Derivatives - noncurrent | | 6,630 |
| | 11,548 |
| | 2,033 |
| | 2,620 |
|
| Foreign currency contracts | Derivatives - current | | — |
| | 126 |
| | 40 |
| | — |
|
| | Derivatives - noncurrent | | — |
| | 118 |
| | 4 |
| | — |
|
| Home Services and Other: | | | | | | | | | |
| Interest rate contracts | Derivatives - current | | 381 |
| | — |
| | — |
| | — |
|
| Total fair value of derivatives | | | $ | 37,956 |
| | $ | 69,634 |
| | $ | 39,245 |
| | $ | 57,874 |
|
| |
| (1) | Includes treasury lock which was settled in March 2018. See Note 8. Debt for more information. |
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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral and the net amounts the Company could present on the Consolidated Balance Sheets but elects not to.
|
| | | | | | | | | | | | | | | | |
| (Thousands) | Amounts Presented in Balance Sheets (1) | Offsetting Derivative Instruments (2) | Financial Collateral Received/Pledged (3) | Net Amounts (4) |
| As of September 30, 2018: | | | | | | | | |
| Derivative assets: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 11,597 |
| | $ | (3,944 | ) | | $ | (200 | ) | | $ | 7,453 |
|
| Financial commodity contracts | | 25,799 |
| | (18,775 | ) | | — |
| | 7,024 |
|
| Total Energy Services | | $ | 37,396 |
| | $ | (22,719 | ) | | $ | (200 | ) | | $ | 14,477 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 85 |
| | $ | (3 | ) | | $ | — |
| | $ | 82 |
|
| Financial commodity contracts | | 94 |
| | — |
| | (94 | ) | | — |
|
| Total Natural Gas Distribution | | $ | 179 |
| | $ | (3 | ) | | $ | (94 | ) | | $ | 82 |
|
| Home Services and Other | | | | | | | | |
| Interest rate contracts | | $ | 381 |
| | $ | — |
| | $ | — |
| | $ | 381 |
|
| Total Home Services and Other | | $ | 381 |
| | $ | — |
| | $ | — |
| | $ | 381 |
|
| Derivative liabilities: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 29,474 |
| | $ | (3,944 | ) | | $ | — |
| | $ | 25,530 |
|
| Financial commodity contracts | | 39,724 |
| | (18,775 | ) | | (20,949 | ) | | — |
|
| Foreign currency contracts | | 244 |
| | — |
| | — |
| | 244 |
|
| Total Energy Services | | $ | 69,442 |
| | $ | (22,719 | ) | | $ | (20,949 | ) | | $ | 25,774 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 192 |
| | $ | (3 | ) | | $ | — |
| | $ | 189 |
|
| Total Natural Gas Distribution | | $ | 192 |
| | $ | (3 | ) | | $ | — |
| | $ | 189 |
|
| As of September 30, 2017: | | | | | | | | |
| Derivative assets: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 21,715 |
| | $ | (2,173 | ) | | $ | (200 | ) | | $ | 19,342 |
|
| Financial commodity contracts | | 17,335 |
| | (14,121 | ) | | — |
| | 3,214 |
|
| Foreign currency contracts | | 44 |
| | — |
| | — |
| | 44 |
|
| Total Energy Services | | $ | 39,094 |
| | $ | (16,294 | ) | | $ | (200 | ) | | $ | 22,600 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
|
| Total Natural Gas Distribution | | $ | 151 |
| | $ | (20 | ) | | $ | — |
| | $ | 131 |
|
| Derivative liabilities: | | | | | | | | |
| Energy Services | | | | | | | | |
| Physical commodity contracts | | $ | 25,299 |
| | $ | (2,173 | ) | | $ | — |
| | $ | 23,126 |
|
| Financial commodity contracts | | 22,887 |
| | (14,121 | ) | | (8,766 | ) | | — |
|
| Total Energy Services | | $ | 48,186 |
| | $ | (16,294 | ) | | $ | (8,766 | ) | | $ | 23,126 |
|
| Natural Gas Distribution | | | | | | | | |
| Physical commodity contracts | | $ | 72 |
| | $ | (20 | ) | | $ | — |
| | $ | 52 |
|
| Financial commodity contracts | | 1,149 |
| | — |
| | (1,149 | ) | | — |
|
| Interest rate contracts | | 8,467 |
| | — |
| | — |
| | 8,467 |
|
| Total Natural Gas Distribution | | $ | 9,688 |
| | $ | (20 | ) | | $ | (1,149 | ) | | $ | 8,519 |
|
| |
| (1) | Derivative assets and liabilities are presented on a gross basis in the balance sheet as the Company does not elect balance sheet offsetting under ASC 210-20. |
| |
| (2) | Offsetting derivative instruments include 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. |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical 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 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, create volatility in the results of Energy Services, although the Company’s intended economic results relating to the entire transaction are unaffected.
The following table reflects the effect of derivative instruments on the Consolidated Statements of Operations as of September 30:
|
| | | | | | | | | | | | |
| (Thousands) | Location of gain (loss) recognized in income on derivatives | Amount of gain (loss) recognized in income on derivatives |
| Derivatives not designated as hedging instruments: | 2018 | | 2017 | | 2016 |
| Energy Services: | | | | | | |
| Physical commodity contracts | Operating revenues | $ | (9,311 | ) | | $ | 8,912 |
| | $ | 33,034 |
|
| Physical commodity contracts | Gas purchases | (197 | ) | | (27,461 | ) | | (45,637 | ) |
| Financial commodity contracts | Gas purchases | (24,622 | ) | | 26,563 |
| | 45,579 |
|
| Foreign currency contracts | Gas purchases | (379 | ) | | 41 |
| | (34 | ) |
| Home Services and Other: | | | | | | |
| Interest rate contracts | Interest expense | 334 |
| | — |
| | — |
|
| Total unrealized and realized gains (losses) | $ | (34,175 | ) | | $ | 8,055 |
| | $ | 32,942 |
|
NJNG’s derivative contracts are part of the Company’s risk management activities that relate to its natural gas purchases, BGSS incentive programs and debt financing. These transactions are entered into pursuant to regulatory approval and, at settlement, the resulting gains and/or losses are payable to or recoverable from utility customers. Any changes in the value of NJNG’s financial derivatives are deferred in regulatory assets or liabilities resulting in no impact to earnings.
The following table reflects the (losses) gains associated with NJNG’s derivative instruments as of September 30:
|
| | | | | | | | | | | |
| (Thousands) | 2018 | | 2017 | | 2016 |
| Natural Gas Distribution: | | | | | |
| Physical commodity contracts | $ | 1,232 |
| | $ | (12,303 | ) | | $ | (15,756 | ) |
| Financial commodity contracts | 1,844 |
| | 5,595 |
| | (7,984 | ) |
| Interest rate contracts | 8,467 |
| | 14,606 |
| | (18,845 | ) |
| Total unrealized and realized (losses) gains | $ | 11,543 |
| | $ | 7,898 |
| | $ | (42,585 | ) |
NJNG and Energy Services had the following outstanding long (short) derivatives as of September 30:
|
| | | | | | | |
| | | | Volume (Bcf) |
| | | | 2018 | | 2017 |
| Natural Gas Distribution | Futures | | 27.9 |
| | 18.2 |
|
| | Physical | | 23.1 |
| | 32.1 |
|
| Energy Services | Futures | | (7.0 | ) | | (16.4 | ) |
| | Physical | | 51.2 |
| | (13.1 | ) |
Not included in the previous table are Energy Services’ gross notional amount of foreign currency transactions of approximately $8.5 million, interest rate contracts, as previously discussed, and 698,700 SRECs at Energy Services that are open as of September 30, 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Broker Margin
Futures exchanges have contract-specific performance bond requirements, also known as margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin, which is posted upon the initiation of a position, maintenance margin, which is usually expressed as a percent of initial margin, and variation margin, which fluctuates based on the daily marked-to-market relative to maintenance margin requirements. The Company maintains separate broker margin accounts for the Natural Gas Distribution and Energy Services segments. The balances as of September 30, by segment, are as follows:
|
| | | | | | | |
| (Thousands) | Balance Sheet Location | 2018 | 2017 |
| Natural Gas Distribution | Broker margin - Current assets | $ | 2,038 |
| $ | 2,661 |
|
| Energy Services | Broker margin - Current assets | $ | 51,681 |
| $ | 23,166 |
|
Due to CME rulebook changes that took effect in January 2017, variation margin is being treated as a settlement payment, rather than collateral. As a result, the Company is now required to present variation margin net with the related derivative assets and/or liabilities on the Consolidated Balance Sheets for any derivatives the Company clears through the CME.
Wholesale Credit Risk
NJNG, Energy Services and Clean Energy Ventures are exposed to credit risk as a result of their sales/wholesale and retail marketing activities. As a result of the inherent volatility in the prices of natural gas commodities, derivatives, SRECs, electricity and RECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty fails to perform the obligations under its contract (e.g., fails to deliver or pay for natural gas, SRECs, electricity or RECs), 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 S&P or Moody’s. In these cases, the counterparty’s or guarantor’s financial statements are reviewed, and similar methodologies and ratios used by S&P and/or Moody’s are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.
The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of September 30, 2018.The amounts presented below have not been reduced by any collateral received or netting and exclude accounts receivable for NJNG retail natural gas sales and services and Clean Energy Ventures residential solar installations.
|
| | | | | |
| (Thousands) | Gross Credit Exposure |
| Investment grade | | $ | 179,982 |
| |
| Noninvestment grade | | 43,486 |
| |
| Internally-rated investment grade | | 30,786 |
| |
| Internally-rated noninvestment grade | | 25,750 |
| |
| Total | | $ | 280,004 |
| |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Conversely, certain of NJNG’s and Energy Services’ derivative instruments are linked to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG’s credit rating were to fall below its current level. NJNG’s credit rating, with respect to S&P, reflects the overall corporate credit profile of the Company. Specifically, most, but not all, of these additional payments will be triggered if NJNG’s debt is downgraded by the major credit agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings, but are based on certain financial metrics.
Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company’s credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position on September 30, 2018 and 2017, is approximately $124,000 and $8.7 million, respectively, for which the Company had not posted collateral. If all thresholds related to the credit-risk-related contingent features underlying these agreements had been invoked on September 30, 2018 and 2017, the Company would have been required to post an additional $33,000 and $8.6 million, respectively, to its counterparties. 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.
5. FAIR VALUE
Fair Value of Assets and Liabilities
The fair value of cash and cash equivalents, accounts receivable, current loan receivables, accounts payable, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. Non-current loan receivables are recorded based on what the Company expects to receive, which approximates fair value. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.
As of September 30, the estimated fair value of long-term debt at NJNG and NJR, including current maturities, excluding capital leases, debt issuance costs and solar asset financing obligations, is as follows (1):
|
| | | | | | |
| (Thousands) | 2018 | 2017 |
| NJNG | | |
| Carrying value | $ | 672,045 |
| $ | 672,045 |
|
| Fair market value | $ | 669,162 |
| $ | 673,051 |
|
| NJR | | |
| Carrying value | $ | 500,000 |
| $ | 425,000 |
|
| Fair market value | $ | 488,889 |
| $ | 434,625 |
|
| |
| (1) | SeeNote 8. Debt for a reconciliation to long-term and short-term debt. |
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, 2018 and 2017, the Company disclosed its debt within Level 2 of the fair value hierarchy.
Fair Value Hierarchy
The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs.
The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and includes the following:
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
| |
| 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 internally to as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM. |
| |
| Level 2 | Other significant observable inputs, such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is: |
widely accepted and public;
non-proprietary and sourced from an independent third party; and
observable and published.
These additional adjustments are generally not considered to be significant to the ultimate recognized values.
| |
| Level 3 | Inputs derived from a significant amount of unobservable market data. These include the Company’s best estimate of fair value and are derived primarily through the use of internal valuation methodologies. |
Financial derivative portfolios of NJNG and Energy Services consist mainly of futures, options and swaps. The Company primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market; therefore, the primary sources for its price inputs are CME, NYMEX and ICE. Energy Services uses Platts and Natural Gas Exchange for Canadian delivery points. However, Energy Services also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the transportation cost to the final delivery location is not significant to the overall valuation. If required, Energy Services’ policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or other pricing services.
The Company also has available for sale securities and 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.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Assets and liabilities measured at fair value on a recurring basis are summarized as follows:
|
| | | | | | | | | | | | | | | | | | |
| | Quoted Prices in Active Markets for Identical Assets | Significant Other Observable Inputs | Significant Unobservable Inputs | |
| (Thousands) | (Level 1) | (Level 2) | (Level 3) | Total |
| As of September 30, 2018: | | | | | | | | | | |
| Assets | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 11,682 |
| | | $ | — |
| | $ | 11,682 |
|
| Financial commodity contracts | | 18,868 |
| | | 7,025 |
| | | — |
| | 25,893 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | — |
| | | — |
| | — |
|
| Interest rate contract | | — |
| | | 381 |
| | | — |
| | 381 |
|
| Available for sale equity securities | | 32,917 |
| | | — |
| | | — |
| | 32,917 |
|
Other (1) | | 1,217 |
| | | — |
| | | — |
| | 1,217 |
|
| Total assets at fair value | | $ | 53,002 |
| | | $ | 19,088 |
| | | $ | — |
| | $ | 72,090 |
|
| Liabilities | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 29,666 |
| | | $ | — |
| | $ | 29,666 |
|
| Financial commodity contracts | | 39,724 |
| | | — |
| | | — |
| | 39,724 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | 244 |
| | | — |
| | 244 |
|
| Total liabilities at fair value | | $ | 39,724 |
| | | $ | 29,910 |
| | | $ | — |
| | $ | 69,634 |
|
| As of September 30, 2017: | | | | | | | | | | |
| Assets | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 21,866 |
| | | $ | — |
| | $ | 21,866 |
|
| Financial commodity contracts | | 17,335 |
| | |
| | |
|
| | 17,335 |
|
| Financial commodity contracts - foreign exchange | | — |
| | | 44 |
| | | — |
| | 44 |
|
| Available for sale equity securities | | 65,752 |
| | | — |
| | | — |
| | 65,752 |
|
Other (1) | | 1,202 |
| | | — |
| | | — |
| | 1,202 |
|
| Total assets at fair value | | $ | 84,289 |
| | | $ | 21,910 |
| | | $ | — |
| | $ | 106,199 |
|
| Liabilities | | | | | | | | | | |
| Physical commodity contracts | | $ | — |
| | | $ | 25,371 |
| | | $ | — |
| | $ | 25,371 |
|
| Financial commodity contracts | | 24,036 |
| | | — |
| | | — |
| | 24,036 |
|
| Interest rate contract | | — |
| | | 8,467 |
| | | — |
| | 8,467 |
|
| Total liabilities at fair value | | $ | 24,036 |
| | | $ | 33,838 |
| | | $ | — |
| | $ | 57,874 |
|
| |
| (1) | Includes money market funds. |
During the second quarter of fiscal 2018, the Company evaluated the decrease in fair value of its available for sale securities on a nonrecurring basis and determined that the decline was other-than-temporary. Accordingly, the Company recognized an other-than-temporary impairment of $17.8 million, which was determined using quoted market prices for identical publicly traded equity securities on an active exchange. As of March 31, 2018, the Company’s available for sale securities had a fair value of $28.2 million.See the Company’s discussion of available for sale securities in Note 2. Summary of Significant Accounting Policies for more information regarding the impairment.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
6. INVESTMENTS IN EQUITY INVESTEES
As of September 30, the Company’s investments in equity method investees includes the following:
|
| | | | | | |
| (Thousands) | 2018 | 2017 |
Steckman Ridge (1) | $ | 117,001 |
| $ | 120,262 |
|
| PennEast | 73,865 |
| 52,323 |
|
| Total | $ | 190,866 |
| $ | 172,585 |
|
(1)Includes loans with a total outstanding principal balance of $70.4 million for both fiscal 2018 and 2017, which accrue interest at a variable rate that resets quarterly and are due October 1, 2023.
The Company, through its subsidiary NJR Pipeline Company, is an investor in PennEast, which is expected to construct and operate a 120-mile pipeline that will extend from northeast Pennsylvania to western New Jersey. PennEast has advised that it currently expects the pipeline to be completed and operational in 2019; however, the project could be delayed beyond 2019 due to factors that are beyond PennEast’s ability to control or estimate precisely, including potential delays in obtaining (or the inability to obtain) governmental and regulatory approvals and land-use rights, and unforeseen construction delays.
NJNG and Energy Services have entered into storage and park and loan agreements with Steckman Ridge. In addition, NJNG has entered into a precedent capacity agreement with PennEast. See Note 15. Related Party Transactions for more information on these intercompany transactions.
7. EARNINGS PER SHARE
The following table presents the calculation of the Company’s basic and diluted earnings per share for the fiscal years ended September 30:
|
| | | | | | | | | |
| (Thousands, except per share amounts) | 2018 | 2017 | 2016 |
| Net income, as reported | $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
| Basic earnings per share | | | |
| Weighted average shares of common stock outstanding-basic | 87,689 |
| 86,321 |
| 85,884 |
|
| Basic earnings per common share | $2.66 | $1.53 | $1.53 |
| Diluted earnings per share | | | |
| Weighted average shares of common stock outstanding-basic | 87,689 |
| 86,321 |
| 85,884 |
|
Incremental shares (1) | 626 |
| 823 |
| 847 |
|
| Weighted average shares of common stock outstanding-diluted | 88,315 |
| 87,144 |
| 86,731 |
|
Diluted earnings per common share (2) | $2.64 | $1.52 | $1.52 |
| |
| (1) | Incremental shares consist primarily of unvested stock awards and performance units. |
| |
| (2) | There were no anti-dilutive shares excluded from the calculation of diluted earnings per share for fiscal 2018, 2017 and 2016. |
8. DEBT
NJNG and NJR finance working capital requirements and capital expenditures through the issuance of various long-term debt and other financing arrangements, including unsecured credit and private placement debt shelf facilities. Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Long-term Debt
The following table presents the long-term debt of the Company as of September 30:
|
| | | | | | | | |
| (Thousands) | 2018 | 2017 |
| NJNG | | | |
| First mortgage bonds: | Maturity date: | | |
| 5.60% | Series LL | May 15, 2018 | $ | — |
| $ | 125,000 |
|
| Variable | Series MM | September 1, 2027 | 9,545 |
| 9,545 |
|
| Variable | Series NN | August 1, 2035 | 41,000 |
| 41,000 |
|
| Variable | Series OO | August 1, 2041 | 46,500 |
| 46,500 |
|
| 3.15% | Series PP | April 15, 2028 | 50,000 |
| 50,000 |
|
| 3.58% | Series QQ | March 13, 2024 | 70,000 |
| 70,000 |
|
| 4.61% | Series RR | March 13, 2044 | 55,000 |
| 55,000 |
|
| 2.82% | Series SS | April 15, 2025 | 50,000 |
| 50,000 |
|
| 3.66% | Series TT | April 15, 2045 | 100,000 |
| 100,000 |
|
| 3.63% | Series UU | June 21, 2046 | 125,000 |
| 125,000 |
|
| 4.01% | Series VV | May 11, 2048 | 125,000 |
| — |
|
| Capital lease obligation-buildings | June 1, 2021 | 8,749 |
| 11,617 |
|
| Capital lease obligation-meters | Various dates | 27,188 |
| 28,042 |
|
| Less: Debt issuance costs | | (6,515 | ) | (6,262 | ) |
| Less: Current maturities of long-term debt | | (9,502 | ) | (135,800 | ) |
| Total NJNG long-term debt | 691,965 |
| 569,642 |
|
| NJR | | | |
| 2.51% | Unsecured senior notes | September 15, 2018 | — |
| 25,000 |
|
| 3.25% | Unsecured senior notes | September 17, 2022 | 50,000 |
| 50,000 |
|
| 3.48% | Unsecured senior notes | November 7, 2024 | 100,000 |
| 100,000 |
|
| 3.20% | Unsecured senior notes | August 18, 2023 | 50,000 |
| 50,000 |
|
| 3.54% | Unsecured senior notes | August 18, 2026 | 100,000 |
| 100,000 |
|
| 3.96% | Unsecured senior notes | June 8, 2028 | 100,000 |
| — |
|
| Variable | Term loan | August 16, 2019 | 100,000 |
| 100,000 |
|
| Less: Debt issuance costs | | (1,136 | ) | (770 | ) |
| Less: Current maturities of long-term debt | | (100,000 | ) | (25,000 | ) |
| Total NJR long-term debt | 398,864 |
| 399,230 |
|
| Clean Energy Ventures | | |
| Solar asset financing obligation | Various dates | 103,923 |
| 32,790 |
|
| Less: Current maturities of long-term debt | (14,133 | ) | (4,582 | ) |
| Total Clean Energy Ventures long-term debt | 89,790 |
| 28,208 |
|
| Total long-term debt | $ | 1,180,619 |
| $ | 997,080 |
|
Annual long-term debt redemption requirements, excluding capital leases, debt issuance costs and solar asset financing obligations, as of September 30, are as follows:
|
| | | | | | |
| (Thousands) | NJNG | NJR |
| 2019 | $ | — |
| $ | 100,000 |
|
| 2020 | $ | — |
| $ | — |
|
| 2021 | $ | — |
| $ | — |
|
| 2022 | $ | — |
| $ | 50,000 |
|
| 2023 | $ | — |
| $ | 50,000 |
|
| Thereafter | $ | 672,045 |
| $ | 300,000 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
NJNG
First Mortgage Bonds
NJNG and Trustee entered into the Mortgage Indenture, dated September 1, 2014, which secures all of the outstanding First Mortgage Bonds issued by NJNG. The Mortgage Indenture provides a direct first mortgage lien upon substantially all of the operating properties and franchises of NJNG (other than excepted property, such as cash on hand, choses-in-action, securities, rent, natural gas meters and certain materials, supplies, appliances and vehicles), subject only to certain permitted encumbrances. The Mortgage Indenture contains provisions subjecting after-acquired property (other than excepted property and subject to pre-existing liens, if any, at the time of acquisition) to the lien thereof.
NJNG’s Mortgage Indenture no longer contains a restriction on NJNG’s ability to pay dividends. New Jersey Administrative Code 14:4-4.7 states that a public utility cannot issue dividends, without regulatory approval, if its equity to total capitalization ratio falls below 30 percent. As of September 30, 2018, NJNG’s equity to total capitalization ratio is 56.7 percent and has the ability to issue up to $1 billion of FMB under the terms of the Mortgage Indenture.
NJNG has variable rate EDA Bonds with a total principal amount of $97 million and maturity dates ranging from September 2027 to August 2041. The EDA Bonds are not subject to optional tender while they bear interest at a LIBOR index rate. As of September 30, 2018, the interest rate on the EDA Bonds was 2.03 percent.
In June 2016, NJNG entered into a Note Purchase Agreement, under which NJNG issued $125 million of its 3.63 percent senior notes due June 2046. The notes are secured by an equal principal amount of NJNG’s FMB (series UU) issued under NJNG’s Mortgage Indenture. The proceeds of the notes will be used for general corporate purposes, including, but not limited to, refinancing or retiring short-term debt and funding capital expenditures.
On January 17, 2017, the Company completed the purchase of three FMBs in lieu of redemption with an aggregate principal amount totaling $35.8 million. The FMBs bore interest at rates ranging from 4.5 percent to 4.9 percent. The bonds purchased in lieu of redemption are being held by the Company to provide an opportunity to evaluate remarketing alternatives.
On May 11, 2018, NJNG entered into a Note Purchase Agreement, under which NJNG issued $125 million, 4.01 percent senior notes due May 11, 2048. The interest rate includes the quoted March 9, 2018, 30-year treasury rate, plus a market based credit spread. The notes are secured by an equal principal amount of NJNG's FMB (series VV) issued under NJNG's Mortgage Indenture.
In June 2015, NJNG entered into a treasury lock transaction to fix a benchmark treasury rate of 3.26 percent associated with a $125 million debt issuance that was finalized in May 2018. This debt issuance coincided with the maturity of the $125 million, 5.6 percent notes that came due May 15, 2018. This treasury lock was settled on March 13, 2018, which coincided with the pricing of the new debt being issued. Settlement of the treasury lock resulted in a $2.6 million loss, which is recorded as a component of regulatory assets on the Consolidated Balance Sheets and will be amortized in earnings over the term of the May 11, 2018 debt issuance, discussed above.
Sale-Leasebacks
NJNG has entered into a sale-leaseback for its headquarters building, which has a 25.5-year term that expires in June 2021, subject to an option by NJNG to renew the lease for additional five-year terms a maximum of four times. The present value of the agreement’s minimum lease payments is reflected as both a capital lease asset and a capital lease obligation, which are included in utility plant and long-term debt, respectively, on the Consolidated Balance Sheets.
NJNG received $7.8 million, $9.6 million $7.1 million and $7.2$7.1 million for fiscal 2018, 2017 2016 and 2015,2016, respectively, in connection with the sale-leaseback of its natural gas meters. NJNG records a capital lease obligation that is paid over the term of the lease and has the option to purchase the meters back at fair value upon expiration of the lease. During fiscal 2018, 2017 2016 and 2015,2016, NJNG exercised early purchase options with respect to meter leases by making final principal payments of $2.2 million, $2.4 million and $1.9 million, and $768,000, respectively. NJNG continues to evaluate this sale-leaseback program based on current market conditions.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Contractual commitments for capital lease payments, as of the fiscal years ended September 30, are as follows:
|
| | | | |
| (Thousands) | Lease Payments | |
| 2018 | | $ | 12,436 |
|
| 2019 | | 9,675 |
|
| 2020 | | 8,849 |
|
| 2021 | | 5,862 |
|
| 2022 | | 2,518 |
|
| Thereafter | | 4,914 |
|
| Subtotal | | 44,200 |
|
| Less: Interest component | | (4,494 | ) |
| Total | | $ | 39,700 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
|
| | | | |
| (Thousands) | Lease Payments | |
| 2019 | | $ | 10,932 |
|
| 2020 | | 7,989 |
|
| 2021 | | 9,236 |
|
| 2022 | | 3,775 |
|
| 2023 | | 2,393 |
|
| Thereafter | | 5,245 |
|
| Subtotal | | 39,570 |
|
| Less: Interest component | | (3,633 | ) |
| Total | | $ | 35,937 |
|
NJR
In March 2016, NJR entered into a Note Purchase Agreement, under which the Company issued, in August 2016, $50 million of the Company’s 3.2 percent senior notes due August 2023, and $100 million of the Company’s 3.54 percent senior notes due August 2026. The notes are not secured by assets, but are instead guaranteed by certain unregulated subsidiaries of the Company. The proceeds of the notes will be used for general corporate purposes, including working capital and capital expenditures.
On August 18, 2017,January 26, 2018, NJR entered into a variable-for-fixed interest rate swap on its existing $100 million credit agreementvariable rate term loan due August 16, 2019. The2019, which fixed the variable rate at 2.84 percent. On July 17, 2018, the $100 million variable rate term loan will accrue interest at a variable rate determined monthly, whichwas amended to permit the disposition of assets relating to sale leaseback or other similar tax equity financing arrangements of meter assets or of solar or wind facilities. These transactions are permissible so long as NJR is LIBOR plus 70 basis points. The weighted average interest rate on the term loan asin compliance with certain covenants both before and after such incurrence, and if no event of September 30, 2017, was 1.95 percent. NJR had no long-term, variable-rate debt outstanding as of September 30, 2016.
default may be caused by such sale leaseback or similar arrangement. As of September 30, 2017, NJR's $25 million, 2.51 percent debt shelf notes, which will mature in September 2018, wereNJR’s variable rate term loan was classified as awithin current maturitymaturities of long-term debt.
On June 8, 2018, NJR entered into a Note Purchase Agreement, under which the Company issued $100 million, 3.96 percent senior notes due June 8, 2028. The notes are not secured by assets, but are instead guaranteed by certain unregulated subsidiaries of NJR.
Clean Energy Ventures
During September 2017, Clean Energy Ventures enteredreceived proceeds of $71.5 million and $32.9 million in connection with the sale-leasebacks of commercial solar projects for fiscal 2018 and 2017, respectively. Clean Energy Ventures enters into transactions to sell twothe commercial solar assets concurrent with agreements to lease the assets back over a period of sevensix to 15 years. These sale-leasebacks are treated as financing obligations, which are typically secured by the renewable energy facility asset and its future cash flows from SREC and energy sales. ITCs and other tax benefits associated with these solar projects will beare transferred to the buyer. Clean Energy Ventures will continuecontinues to operate the solar assets, including related expenses, and retain the revenue generated from SRECs and energy sales.sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. Clean Energy Ventures received proceeds of $32.9 million in connection with these sale-leasebacks.
Contractual commitments for solar sale-leaseback lease payments, as of the sale-leasebacks will be $2.7 million annually for the next fivefiscal years and $5.3 million in the aggregate for all years thereafter.ended September 30, are as follows:
|
| | | | |
| (Thousands) | Lease Payments | |
| 2019 | | $ | 9,794 |
|
| 2020 | | 7,830 |
|
| 2021 | | 7,803 |
|
| 2022 | | 7,802 |
|
| 2023 | | 7,878 |
|
| Thereafter | | 38,303 |
|
| Subtotal | | 79,410 |
|
| Less: Interest component | | (26,728 | ) |
| Total | | $ | 52,682 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Short-term Debt
A summary of NJR’s and NJNG’s short-term bank facilities as of September 30, are as follows:
| | | (Thousands) | 2017 | | 2016 | 2018 | | 2017 |
| NJR | | | | | | |
Bank revolving credit facilities: (1) | $ | 425,000 |
| | $ | 425,000 |
| $ | 425,000 |
| | $ | 425,000 |
|
| Notes outstanding at end of period | $ | 255,000 |
| | $ | 121,700 |
| $ | 87,950 |
| | $ | 255,000 |
|
| Weighted average interest rate at end of period | 2.14 | % | | 1.43 | % | 3.07 | % | | 2.14 | % |
Amount available at end of period (2) | $ | 156,601 |
| | $ | 288,910 |
| $ | 322,144 |
| | $ | 156,601 |
|
| NJNG | | | | | | |
Bank revolving credit facilities: (3) | $ | 250,000 |
| | $ | 250,000 |
| $ | 250,000 |
| | $ | 250,000 |
|
| Commercial paper outstanding at end of period | $ | 11,000 |
| | $ | — |
| $ | 64,000 |
| | $ | 11,000 |
|
| Weighted average interest rate at end of period | 1.13 | % | | — | % | 2.18 | % | | 1.13 | % |
Amount available at end of period (4) | $ | 238,269 |
| | $ | 249,269 |
| $ | 185,269 |
| | $ | 238,269 |
|
| |
| (1) | Committed credit facilities, which require commitment fees of .075 percent on the unused amounts. |
| |
| (2) | Letters of credit outstanding total $13.4$14.9 million and $14.4$13.4 million as of September 30, 20172018 and 2016,2017, respectively, which reduces amount available by the same amount. |
| |
| (3) | Committed credit facilities, which require commitment fees of .075 percent on the unused amounts. |
| |
| (4) | Letters of credit outstanding total $731,000 as of September 30, 20172018 and 2016,2017, which reduces amount available by the same amount. |
NJR
On September 28, 2015, NJR entered into a $425 million unsecured, committed credit facility scheduled to expire on September 28, 2020, subject to two mutual options for a one-year extension beyond that date. The NJR Credit Facility includes an accordion feature, which would allow NJR, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit Facility in minimum $5 million increments up to a maximum of $100 million. The credit facility is used primarily to finance its share repurchases, to satisfy Energy Services’ short-term liquidity needs and to finance, on an initial basis, unregulated investments.
New Jersey Resources Corporation
Part IIOn June 25, 2018, the $425 million NJR Credit Facility was amended to permit liens and the disposition of assets relating to sale-leaseback or other similar tax equity financing arrangements of meter assets or of solar or wind facilities. These transactions are permissible so long as NJR is in compliance with certain covenants both before and after such incurrence, and if no event of default may be caused by such sale-leaseback or similar arrangement.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
On December 14, 2017, NJR entered into a four-month, $75 million revolving line of credit facility.On January 19, 2018, NJR amended the agreement to increase the available amount to $100 million. This facility expired on April 14, 2018. No amounts were outstanding on the facility at the time of expiration.
As of September 30, 2017,2018, NJR had six letters of credit outstanding totaling $13.4$14.9 million. Three letters of credit totaling $10.4$11.9 million are issued on behalf of Energy Services and three letters of credit, which total $3 million, are issued on behalf of Clean Energy Ventures. These letters of credit reduce the amount available under NJR’s committed credit facility by the same amount. NJR does not anticipate that these letters of credit will be drawn upon by the counterparties, and they will be renewed as necessary.
Energy Services’ letters of credit are used for margin requirements for natural gas transactions, collateral and security deposit for retail gas sales and expire on dates ranging from December 20172018 to September 2018.2019. Clean Energy Ventures’ letters of credit are used to secure construction of ground-mounted solar projects and to secure obligations pursuant to an Interconnection Services Agreement. They expire on dates ranging from May 20182019 to August 2018.2019.
Neither NJNG nor the results of its operations are obligated or pledged to support the NJR credit or debt shelf facilities.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
NJNG
NJNG has a $250 million, five-year, revolving, unsecured credit facility, which expires in May 2019. The NJNG Credit Facility permits the borrowing of revolving loans and swing loans, as well as the issuance of letters of credit. It also permits an increase to the facility, from time to time, with the existing or new lenders, in a minimum of $15 million increments up to a maximum of $50 million at the lending banks’ discretion.
As of September 30, 2017,2018, NJNG has two letters of credit outstanding for $731,000. NJNG’s letters of credit are used as collateral for remediation projects and expire in August 2018.2019. These letters of credit reduce the amount available under NJNG’s committed credit facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by the counterparty and will be renewed as necessary.
10.9. STOCK-BASED COMPENSATION
Effective January 25, 2017, the shareholders of the Company approved the NJR 2017 Stock Award and Incentive Plan, which replaced the NJR 2007 Stock Award and Incentive Plan. The 2007 plan had 914,169 shares granted but not issued as of September 30, 2016,2017, which were transferred into the 2017 plan. The 2017 plan added an additional 3,135,000 shares available for issuance. Shares have been issued in the form of performance shares, restricted stock, deferred retention stock and unrestricted common stock to non-employee directors. As of September 30, 2017, 3,119,8782018, 3,473,062 shares remain available for future issuance.
The following table summarizes all stock-based compensation expense recognized during the following fiscal years:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Stock-based compensation expense: | | |
| Performance share awards | $ | 2,614 |
| $ | 3,188 |
| $ | 2,473 |
| $ | 3,526 |
| $ | 2,614 |
| $ | 3,188 |
|
| Restricted and non-restricted stock | 1,732 |
| 2,161 |
| 1,899 |
| 2,191 |
| 1,732 |
| 2,161 |
|
| Deferred retention stock | 1,461 |
| 1,885 |
| 5,273 |
| 7,128 |
| 1,461 |
| 1,885 |
|
| Compensation expense included in operation and maintenance expense | 5,807 |
| 7,234 |
| 9,645 |
| 12,845 |
| 5,807 |
| 7,234 |
|
Income tax benefit (1) | (2,372 | ) | (2,955 | ) | (3,940 | ) | (3,734 | ) | (2,372 | ) | (2,955 | ) |
| Total, net of tax | $ | 3,435 |
| $ | 4,279 |
| $ | 5,705 |
| $ | 9,111 |
| $ | 3,435 |
| $ | 4,279 |
|
| |
| (1) | Excludes additional tax benefit related to delivered shares of $1.3$3 million, $1.8$1.3 million and $881,000$1.8 million as of September 30, 20172018, 20162017 and 2015,2016, respectively. |
Performance Shares
In fiscal 2018, the Company granted to various officers 31,836 performance shares, which are market condition awards that vest on September 30, 2020, subject to the Company meeting certain performance conditions. In fiscal 2018, the Company also granted to various officers 59,341 performance shares, of which 29,608 vest on September 30, 2020 and 29,733 vest annually over a three-year period beginning on September 30, 2018, both of which are subject to the Company meeting certain performance conditions.
In fiscal 2017, the Company granted to various officers 44,576 performance shares, which are market condition awards that vest on September 30, 2019, subject to the Company meeting certain performance conditions. In fiscal 2017, the Company also granted to various officers 51,931 performance shares, of which 25,806 vest on September 30, 2019 and 26,125 vest annually over a three yearthree-year period beginning onin September 30, 2017, both of which are subject to the Company meeting certain performance conditions.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued) ��
In fiscal 2016, the Company granted to various officers 46,175 performance shares, which are market condition awards that vestvested on September 30, 2018, subject to the Company meeting certain performance conditions. In fiscal 2016, the Company also granted to various officers 69,305 performance shares, of which 38,789 vest onvested in September 30, 2018 and 30,516 vest annually over a three yearthree-year period beginning in September 2016, both of which are subject to the Company meeting certain performance conditions.
In fiscal 2015, the Company granted to various officers 41,214 performance shares, which are market condition awards that vested on September 30, 2017, subject to the Company meeting certain performance conditions. In fiscal 2015, the Company also granted to various officers 61,576 performance shares, of which 34,622 vested in September 30, 2017 and 26,954 vest annually over a three year period beginning in September 2015, both of which were subject to the Company meeting certain performance conditions. The vesting of these awards are shown in the table below.
There is approximately $2.9$3.8 million of deferred compensation related to unvested performance shares that is expected to be recognized over the weighted average period of 1.7 years.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table summarizes the performance share activity under the stock award and incentive plans for the past three fiscal years:
| | | | Shares (1) | Weighted Average Grant Date Fair Value | Total Fair Value of Vested Shares (in Thousands) | Shares (1) | Weighted Average Grant Date Fair Value | Total Fair Value of Vested Shares (in Thousands) |
| Non-vested and outstanding at September 30, 2014 | 247,536 |
| | $18.30 | | — |
| | |
| Non-vested and outstanding at September 30, 2015 | | 214,464 |
| | $23.40 | | — |
| |
| Granted | 102,790 |
| | $28.25 | | — |
| | 115,480 |
| | $27.37 | | — |
| |
Vested (2) | (112,446 | ) | | $17.10 | | $ | 4,318 |
| | (137,053 | ) | | $21.40 | | $ | 5,657 |
| |
Cancelled/forfeited (3) | (23,416 | ) | | $17.98 | | — |
| | (12,975 | ) | | $23.40 | | — |
| |
| Non-vested and outstanding at September 30, 2015 | 214,464 |
| | $23.40 | | — |
| | |
| Non-vested and outstanding at September 30, 2016 | | 179,916 |
| | $27.47 | | — |
| |
| Granted | 115,480 |
| | $27.37 | | — |
| | 96,507 |
| | $33.57 | | — |
| |
Vested (4) | (137,053 | ) | | $21.40 | | $ | 5,657 |
| | (95,407 | ) | | $28.88 | | $ | 4,179 |
| |
Cancelled/forfeited (5) | (12,975 | ) | | $23.40 | | | — |
| | |
| Non-vested and outstanding at September 30, 2016 | 179,916 |
| | $27.47 | | | — |
| | |
| Cancelled/forfeited | | (24,429 | ) | | $29.14 | | | — |
| |
| Non-vested and outstanding at September 30, 2017 | | 156,587 |
| | $30.12 | | | — |
| |
| Granted | 96,507 |
| | $33.57 | | — |
| | 91,177 |
| | $44.67 | | — |
| |
Vested (6)(5) | (95,407 | ) | | $28.88 | | $ | 4,179 |
| | (100,146 | ) | | $29.49 | | $ | 4,714 |
| |
| Cancelled/forfeited | (24,429 | ) | | $29.14 | | | — |
| | (2,442 | ) | | $31.45 | | | — |
| |
| Non-vested and outstanding at September 30, 2017 | 156,587 |
| | $30.12 | | | — |
| | |
| Non-vested and outstanding at September 30, 2018 | | 145,176 |
| | $39.67 | | | — |
| |
| |
| (1) | The number of common shares issued related to certain performance shares may range from zero to 150 percent of the number of shares shown in the table above based on the Company’s achievement of performance goals. |
| |
| (2) | As certified by the Company’s Leadership and Compensation Committee on November 10, 2015, the number of common shares related to performance shares earned was 120 percent, or 112,918 shares, excluding accumulated dividends. The number represented on this line is the target number of 100 percent. See footnote (1) above. Also included in the vested number are 9,364 shares certified by the Leadership and Compensation Committee on November 11, 2014 and 8,984 shares certified by the Leadership and Compensation Committee on November 10, 2015.
|
| |
(3) | As certified by the Company’s Leadership and Compensation Committee on November 10, 2015, 9,364 shares were canceled due to not achieving a certain performance target. The remainder were forfeitures due to individuals departing the company. |
| |
(4) | As certified by the Company’s Leadership and Compensation Committee on November 15, 2016, the number of common shares earned related to TSR performance shares earned was 85 percent, or 55,702 shares, the number of common shares earned related to NFE performance was 150 percent or 71,808 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 23,649 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent. |
| |
(5)(3) | As certified by the Company’s Leadership and Compensation Committee on November 15, 2016, 9,366 shares were canceled due to not achieving a certain performance target. The remainder were forfeitures due to individuals departing the company.Company. |
| |
(6)(4) | As certified by the Company’s Leadership and Compensation Committee on November 14, 2017, the number of common shares earned related to TSR performance was 108.44 percent or 39,595 shares, the number of common shares earned related to NFE performance was 119 percent or 36,498 shares, and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 28,223 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent. |
| |
| (5) | As certified by the Company’s Leadership and Compensation Committee on November 13, 2018, the number of common shares earned related to TSR performance was 99 percent or 38,660 shares, the number of common shares earned related to NFE performance was 121 percent or 39,694 shares and the number of common shares earned related to Performance Based Restricted Stock was 100 percent or 36,998 shares. Each award earned excludes accumulated dividends. The number represented on this line is the target number of 100 percent. |
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’sCompany’s stock price on grant date, and are subsequently adjusted for actual achievement of the performance goals.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Restricted Stock
In fiscal 2018, the Company granted 27,949 shares of restricted stock that vest annually over a three-year period beginning October 15, 2018. In fiscal 2017, the Company granted 22,591 shares of restricted stock that vest annually over a three yearthree-year period beginning in October 15, 2017. In fiscal 2017, the Company also granted 6,143 shares of restricted stock that vest annually over a three yearthree-year period beginning May 8, 2018. In fiscal 2016, the Company granted 41,909 shares of restricted stock that vest annually over a three yearthree-year period beginning in October 2016. In fiscal 2015, the Company granted 48,542 shares of restricted stock that vest annually over a three year period beginning in October 2015. In fiscal 2015, the Company also granted 10,236 shares of restricted stock that will vest October 15, 2017 and 3,194 that vested September 30, 2015. There is approximately $511,409$612,964 of deferred compensation related to unvested restricted stock shares that is expected to be recognized over the weighted average period of two years.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following table summarizes the restricted stock activity under the stock award and incentive plans for the past three fiscal years:
| | | | Shares |
| Weighted Average Grant Date Fair Value | Total Fair Value of Vested Shares (in Thousands) | Shares |
| Weighted Average Grant Date Fair Value | Total Fair Value of Vested Shares (in Thousands) |
| Non-vested and outstanding at September 30, 2014 | 41,491 |
| | $22.60 | | — |
| | |
| Granted | 61,972 |
| | $29.41 | | — |
| | |
| Vested | (18,170 | ) | | $24.45 | | $ | 510 |
| | |
| Cancelled/forfeited | (3,801 | ) | | $26.79 | | — |
| | |
| Non-vested and outstanding at September 30, 2015 | 81,492 |
| | $27.17 | | — |
| | 81,492 |
| | $27.17 | | — |
| |
| Granted | 41,909 |
| | $30.03 | | — |
| | 41,909 |
| | $30.03 | | — |
| |
| Vested | (48,089 | ) | | $26.66 | | $ | 1,469 |
| | (48,089 | ) | | $26.66 | | $ | 1,469 |
| |
| Cancelled/forfeited | (2,241 | ) | | $29.21 | | — |
| | (2,241 | ) | | $29.21 | | — |
| |
| Non-vested and outstanding at September 30, 2016 | 73,071 |
| | $29.09 | | — |
| | 73,071 |
| | $29.09 | | — |
| |
| Granted | 28,734 |
| | $35.79 | |
| | 28,734 |
| | $35.79 | | — |
| |
| Vested | (38,752 | ) | | $28.92 | | $ | 1,344 |
| | (38,752 | ) | | $28.92 | | $ | 1,344 |
| |
| Cancelled/forfeited | (11,899 | ) | | $31.56 | |
| | (11,899 | ) | | $31.56 | | — |
| |
| Non-vested and outstanding at September 30, 2017 | 51,154 |
| | $32.40 | | — |
| | 51,154 |
| | $32.40 | | — |
| |
| Granted | | 27,949 |
| | $45.00 | |
| |
| Vested | | (33,815 | ) | | $31.23 | | $ | 1,438 |
| |
| Cancelled/forfeited | | (1,120 | ) | | $33.54 | |
| |
| Non-vested and outstanding at September 30, 2018 | | 44,168 |
| | $41.24 | | — |
| |
Deferred Retention Stock
Deferred retention stock awards vest immediately when granted, with shares delivered at a future date in accordance with the terms of the underlying agreements. The expense for these awards is recognized in the fiscal year in which services are rendered. The related shares are granted upon approval by the Board of Directors, which generally occurs subsequent to the fiscal year end.
The following table summarizes the deferred retention stock award under the stock award and incentive plans for the past three fiscal years:
| | | | Shares | Weighted Average Grant Date Fair Value | Total Fair Value of Vested Shares (in Thousands) | Shares | Weighted Average Grant Date Fair Value | Total Fair Value of Vested Shares (in Thousands) |
| Outstanding at September 30, 2014 | 276,782 |
| | $21.95 | | — |
| | |
| Granted/Vested | 462,790 |
| | $29.32 | | — |
| | |
| Delivered | (95,098 | ) | | $23.62 | | $ | 2,519 |
| | |
| Forfeited | (11,744 | ) | | $24.69 | | — |
| | |
| Outstanding at September 30, 2015 | 632,730 |
| | $27.03 | | — |
| | 632,730 |
| | $27.03 | | — |
| |
| Granted/Vested | 159,831 |
| | $30.37 | | — |
| | 159,831 |
| | $30.37 | | — |
| |
| Delivered | (121,764 | ) | | $20.31 | | $ | 3,751 |
| | (121,764 | ) | | $20.31 | | $ | 3,751 |
| |
| Forfeited | (8,318 | ) | | $28.14 | | — |
| | (8,318 | ) | | $28.14 | | — |
| |
| Outstanding at September 30, 2016 | 662,479 |
| | $29.06 | | — |
| | 662,479 |
| | $29.06 | | — |
| |
| Granted/Vested | 63,977 |
| | $35.64 | | — |
| | 63,977 |
| | $35.64 | | — |
| |
| Delivered | (53,878 | ) | | $23.11 | | $ | 1,774 |
| | (53,878 | ) | | $23.11 | | $ | 1,774 |
| |
| Outstanding at September 30, 2017 | 672,578 |
| | $29.54 | | — |
| | 672,578 |
| | $29.54 | | — |
| |
| Granted/Vested | | 24,167 |
| | $45.00 | |
| |
| Delivered | | (452,694 | ) | | $29.42 | | $ | 19,581 |
| |
| Forfeited | | (1,969 | ) | | $35.56 | |
| |
| Outstanding at September 30, 2018 | | 242,082 |
| | $32.99 | | — |
| |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Stock Options
The following table summarizes the stock option activity:
|
| | | | | |
| | Shares | Weighted Average Exercise Price |
| Outstanding at September 30, 2014 | 48,250 |
| | $15.00 | |
| Exercised | (48,250 | ) | | $15.00 | |
| Outstanding at September 30, 2015 | — |
| | $0.00 | |
NJR received proceeds of $724,000 from the stock options exercised during fiscal 2015. There were no remaining stock options outstanding as of September 30, 2015, and therefore NJR received no proceeds from stock options exercised during fiscal 2017 and 2016. There were no stock options granted during fiscal 2017, 2016 and 2015.
Non-Employee Director Stock
Non-employee director compensation includes an annual January retainer that is awarded in stock. The shares vest immediately and are subsequently amortized to expense over a 12-month period. The following summarizes non-employee director share awards for the past three fiscal years:
| | | | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Shares granted | 27,972 | (1) | 27,481 | 26,122 | 26,524 | (1) | 27,972 | 27,481 |
| Weighted average grant date fair value | $35.59 | | $32.75 | $30.63 | $39.85 | | $35.59 | $32.75 |
| |
| (1) | $280,000264,000 of expense remains as of September 30, 2017,2018, to be recognized through December 31, 2017.2018. |
11.10. EMPLOYEE BENEFIT PLANS
Pension and Other Postemployment Benefit Plans
The Company has two trusteed, noncontributory defined benefit retirement plans covering eligible regular represented and nonrepresented employees with more than one year of service. Defined benefit plan benefits are based on years of service and average compensation during the highest 60 consecutive months of employment. The Company also provides postemployment medical and life insurance benefits to employees who meet certain eligibility requirements.
All represented employees of NJRHS hired on or after October 1, 2000, non-represented employees hired on or after October 1, 2009 and NJNG represented employees hired on or after January 1, 2012, are covered by an enhanced defined contribution plan instead of the defined benefit plan. Participation in the postemployment medical and life insurance plan was also frozen to new employees as of the same dates, with the exception of new NJRHS represented employees, for which benefits were frozen beginning April 3, 2012.
The Company maintains an unfunded nonqualified PEP that was established to provide employees with the full level of benefits as stated in the qualified plan without reductions due to various limitations imposed by the provisions of federal income tax laws and regulations. There were no plan assets in the nonqualified plan due to the nature of the plan.
In April 2018, the Company implemented a voluntary early retirement program open to certain eligible employees. As of September 30, 2018, pension and postemployment benefit costs related to the special termination benefits were $4.2 million and other severance benefits were $2.2 million. For the amounts incurred, NJNG recognized an expense of approximately $5.1 million and Home Services and other recognized an expense of approximately $1.3 million, as a component of O&M in the Consolidated Statements of Operations.
The Company’s funding policy for its pension plans is to contribute at least the minimum amount required by the Employee Retirement Income Security Act of 1974, as amended. In fiscal 20172018 and 2016,2017, the Company had no minimum funding requirements. The Company made a discretionary contribution of $30 million during the first quarter of fiscal 2016 to improve the funded status of the pension plans based on current actuarial assumptions. The Company made no discretionary contributions to the pension plans in fiscal 20172018. or 2017. The Company does not expect to be required to make additional contributions to fund the pension plans over the following two fiscal years based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents.
There are no Federalfederal 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 $6$6.2 million and $3.2$6 million, in fiscal 20172018 and 2016,2017, respectively, and estimates that it will contribute between $4$5 million to $7$8 million over each of the next five years. Additional contributions may be required based on market conditions and changes to assumptions.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following summarizes the changes in the funded status of the plans and the related liabilities recognized on the Consolidated Balance Sheets as of September 30:
| | | | Pension (1) | OPEB | Pension (1) | OPEB |
| (Thousands) | 2017 | 2016 | 2017 | 2016 | 2018 | 2017 | 2018 | 2017 |
| Change in Benefit Obligation | | |
| Benefit obligation at beginning of year | $ | 293,654 |
| $ | 255,987 |
| $ | 160,393 |
| $ | 138,367 |
| $ | 297,835 |
| $ | 293,654 |
| $ | 175,090 |
| $ | 160,393 |
|
| Service cost | 8,347 |
| 7,591 |
| 4,380 |
| 4,521 |
| 8,139 |
| 8,347 |
| 4,607 |
| 4,380 |
|
| Interest cost | 9,771 |
| 11,342 |
| 5,545 |
| 6,256 |
| 10,493 |
| 9,771 |
| 6,365 |
| 5,545 |
|
Plan participants’ contributions (2) | 45 |
| 47 |
| 120 |
| 104 |
| 45 |
| 45 |
| 161 |
| 120 |
|
Special termination benefits (3) | | 3,730 |
| — |
| 490 |
| — |
|
| Actuarial (gain) loss | (5,995 | ) | 26,369 |
| 8,985 |
| 15,590 |
| (12,846 | ) | (5,995 | ) | 15,145 |
| 8,985 |
|
| Benefits paid, net of retiree subsidies received | (7,987 | ) | (7,682 | ) | (4,333 | ) | (4,445 | ) | (8,821 | ) | (7,987 | ) | (5,073 | ) | (4,333 | ) |
| Benefit obligation at end of year | $ | 297,835 |
| $ | 293,654 |
| $ | 175,090 |
| $ | 160,393 |
| $ | 298,575 |
| $ | 297,835 |
| $ | 196,785 |
| $ | 175,090 |
|
| Change in plan assets | | |
| Fair value of plan assets at beginning of year | $ | 249,875 |
| $ | 199,123 |
| $ | 62,035 |
| $ | 57,269 |
| $ | 271,743 |
| $ | 249,875 |
| $ | 71,534 |
| $ | 62,035 |
|
| Actual return on plan assets | 29,736 |
| 28,316 |
| 7,953 |
| 5,872 |
| 16,306 |
| 29,736 |
| 5,284 |
| 7,953 |
|
| Employer contributions | 74 |
| 30,071 |
| 6,049 |
| 3,235 |
| 137 |
| 74 |
| 6,222 |
| 6,049 |
|
Benefits paid, net of plan participants’ contributions (2) | (7,942 | ) | (7,635 | ) | (4,503 | ) | (4,341 | ) | (8,776 | ) | (7,942 | ) | (5,060 | ) | (4,503 | ) |
| Fair value of plan assets at end of year | $ | 271,743 |
| $ | 249,875 |
| $ | 71,534 |
| $ | 62,035 |
| $ | 279,410 |
| $ | 271,743 |
| $ | 77,980 |
| $ | 71,534 |
|
| Funded status | $ | (26,092 | ) | $ | (43,779 | ) | $ | (103,556 | ) | $ | (98,358 | ) | $ | (19,165 | ) | $ | (26,092 | ) | $ | (118,805 | ) | $ | (103,556 | ) |
| Amounts recognized on Consolidated Balance Sheets | | |
| Postemployment employee (liability) | | |
| Current | $ | (158 | ) | $ | (79 | ) | $ | (602 | ) | $ | (454 | ) | $ | (294 | ) | $ | (158 | ) | $ | (669 | ) | $ | (602 | ) |
| Noncurrent | (25,934 | ) | (43,700 | ) | (102,954 | ) | (97,904 | ) | (18,871 | ) | (25,934 | ) | (118,136 | ) | (102,954 | ) |
| Total | $ | (26,092 | ) | $ | (43,779 | ) | $ | (103,556 | ) | $ | (98,358 | ) | $ | (19,165 | ) | $ | (26,092 | ) | $ | (118,805 | ) | $ | (103,556 | ) |
| |
| (1) | Includes the Company’s PEP. |
| |
| (2) | Prior to July 1, 1998, employees were eligible to elect an additional participant contribution to enhance their benefits and contributions made during the periods were insignificant. |
| |
| (3) | Related to the voluntary early retirement program offered during fiscal 2018, as previously discussed. |
The actuarial gain on the Company’s pension plans is primarily due to an increase in the discount rate andused to measure the adoption of the MP-2016 mortality table.obligation. The actuarial loss related to the OPEB plans is primarily due to an increase in expected retiree healthcare claims, partially offset by an increase in the discount rate and the adoption of the MP-2016 mortality table.
rate. The Company recognizes a liability for its underfunded benefit plans as required by theASC 715, Compensation - Retirement Benefits Topic of the ASC.. The Company records the offset to regulatory assets for the portion of liability relating to NJNG and to accumulated other comprehensive income for the portion of the liability related to its unregulated operations.
The following table summarizes the amounts recognized in regulatory assets and accumulated other comprehensive income as of September 30:
| | | | Regulatory Assets | | Accumulated Other Comprehensive Income (Loss) | Regulatory Assets | | Accumulated Other Comprehensive Income (Loss) |
| | Pension | OPEB | | Pension | OPEB | Pension | OPEB | | Pension | OPEB |
| Balance at September 30, 2015 | $ | 86,960 |
| $ | 50,737 |
| | $ | 25,640 |
| $ | 1,242 |
| |
| Amounts arising during the period: | | | | |
| Net actuarial loss | 13,696 |
| 11,274 |
| | 4,475 |
| 3,289 |
| |
| Amounts amortized to net periodic costs: | | | | |
| Net actuarial (loss) | (5,607 | ) | (3,175 | ) | | (1,676 | ) | (99 | ) | |
| Prior service (cost) credit | (108 | ) | 311 |
| | (3 | ) | 54 |
| |
| Balance at September 30, 2016 | $ | 94,941 |
| $ | 59,147 |
| | $ | 28,436 |
| $ | 4,486 |
| $ | 94,941 |
| $ | 59,147 |
| | $ | 28,436 |
| $ | 4,486 |
|
| Amounts arising during the period: | | | | | | |
| Net actuarial (gain) loss | (9,429 | ) | 5,211 |
| | (6,990 | ) | 587 |
| (9,429 | ) | 5,211 |
| | (6,990 | ) | 587 |
|
| Amounts amortized to net periodic costs: | | | | | | |
| Net actuarial (loss) | (6,799 | ) | (4,209 | ) | | (2,028 | ) | (160 | ) | (6,799 | ) | (4,209 | ) | | (2,028 | ) | (160 | ) |
| Prior service (cost) credit | (108 | ) | 311 |
| | (3 | ) | 54 |
| (108 | ) | 311 |
| | (3 | ) | 54 |
|
| Balance at September 30, 2017 | $ | 78,605 |
| $ | 60,460 |
| | $ | 19,415 |
| $ | 4,967 |
| $ | 78,605 |
| $ | 60,460 |
| | $ | 19,415 |
| $ | 4,967 |
|
| Amounts arising during the period: | | | | |
| Net actuarial (gain) loss | | (6,090 | ) | 12,378 |
| | (3,422 | ) | 2,834 |
|
| Amounts amortized to net periodic costs: | | | | |
| Net actuarial (loss) | | (6,177 | ) | (4,464 | ) | | (1,359 | ) | (196 | ) |
| Prior service (cost) credit | | (105 | ) | 311 |
| | (1 | ) | 54 |
|
| Balance at September 30, 2018 | | $ | 66,233 |
| $ | 68,685 |
| | $ | 14,633 |
| $ | 7,659 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The amounts in regulatory assets and accumulated other comprehensive income not yet recognized as components of net periodic benefit cost as of September 30 are:
| | | | Regulatory Assets | Accumulated Other Comprehensive Income (Loss) | Regulatory Assets | Accumulated Other Comprehensive Income (Loss) |
| | Pension | OPEB | Pension | OPEB | Pension | OPEB | Pension | OPEB |
| (Thousands) | 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | 2018 | 2017 | 2018 | 2017 | 2018 | 2017 | 2018 | 2017 |
| Net actuarial loss | $ | 77,930 |
| $ | 94,158 |
| $ | 61,563 |
| $ | 60,561 |
| $ | 19,414 |
| $ | 28,432 |
| $ | 5,113 |
| $ | 4,686 |
| $ | 65,664 |
| $ | 77,930 |
| $ | 69,477 |
| $ | 61,563 |
| $ | 14,633 |
| $ | 19,414 |
| $ | 7,750 |
| $ | 5,113 |
|
| Prior service cost (credit) | 675 |
| 783 |
| (1,103 | ) | (1,414 | ) | 1 |
| 4 |
| (146 | ) | (200 | ) | 569 |
| 675 |
| (792 | ) | (1,103 | ) | — |
| 1 |
| (91 | ) | (146 | ) |
| Total | $ | 78,605 |
| $ | 94,941 |
| $ | 60,460 |
| $ | 59,147 |
| $ | 19,415 |
| $ | 28,436 |
| $ | 4,967 |
| $ | 4,486 |
| $ | 66,233 |
| $ | 78,605 |
| $ | 68,685 |
| $ | 60,460 |
| $ | 14,633 |
| $ | 19,415 |
| $ | 7,659 |
| $ | 4,967 |
|
To the extent the unrecognized amounts in accumulated other comprehensive income or regulatory assets exceed 10 percent of the greater of the benefit obligation or the fair value of plan assets, an amortized amount over the average expected future working lifetime of the active plan participants is recognized. Amounts included in regulatory assets and accumulated other comprehensive income expected to be recognized as components of net periodic benefit cost in fiscal 20182019 are as follows:
| | | | Regulatory Assets | | Accumulated Other Comprehensive Income (Loss) | Regulatory Assets | | Accumulated Other Comprehensive Income (Loss) |
| (Thousands) | Pension | OPEB | | Pension | OPEB | Pension | OPEB | | Pension | OPEB |
| Net actuarial loss | $ | 6,177 |
| $ | 4,464 |
| | $ | 1,360 |
| $ | 196 |
| $ | 4,662 |
| $ | 5,527 |
| | $ | 1,103 |
| $ | 643 |
|
| Prior service cost (credit) | 105 |
| (311 | ) | | 1 |
| (53 | ) | 102 |
| (312 | ) | | — |
| (53 | ) |
| Total | $ | 6,282 |
| $ | 4,153 |
| | $ | 1,361 |
| $ | 143 |
| $ | 4,764 |
| $ | 5,215 |
| | $ | 1,103 |
| $ | 590 |
|
The accumulated benefit obligation for the pension plans, including the PEP, exceeded the fair value of plan assets. The projected benefit and accumulated benefit obligations and the fair value of plan assets as of September 30, are as follows:
| | | | Pension | Pension |
| (Thousands) | 2017 | 2016 | 2018 | 2017 |
| Projected benefit obligation | $ | 297,835 |
| $ | 293,654 |
| $ | 298,575 |
| $ | 297,835 |
|
| Accumulated benefit obligation | $ | 258,514 |
| $ | 252,077 |
| $ | 263,279 |
| $ | 258,514 |
|
| Fair value of plan assets | $ | 271,743 |
| $ | 249,875 |
| $ | 279,410 |
| $ | 271,743 |
|
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 | Pension | OPEB |
| (Thousands) | 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 | 2018 | 2017 | 2016 |
| Service cost | $ | 8,347 |
| $ | 7,591 |
| $ | 7,485 |
| $ | 4,380 |
| $ | 4,521 |
| $ | 4,253 |
| $ | 8,139 |
| $ | 8,347 |
| $ | 7,591 |
| $ | 4,607 |
| $ | 4,380 |
| $ | 4,521 |
|
| Interest cost | 9,771 |
| 11,342 |
| 10,199 |
| 5,545 |
| 6,256 |
| 5,739 |
| 10,493 |
| 9,771 |
| 11,342 |
| 6,365 |
| 5,545 |
| 6,256 |
|
| Expected return on plan assets | (19,313 | ) | (20,118 | ) | (17,090 | ) | (4,767 | ) | (4,845 | ) | (4,977 | ) | (19,639 | ) | (19,313 | ) | (20,118 | ) | (5,352 | ) | (4,767 | ) | (4,845 | ) |
| Recognized actuarial loss | 8,827 |
| 7,281 |
| 6,985 |
| 4,370 |
| 3,274 |
| 2,943 |
| 7,537 |
| 8,827 |
| 7,281 |
| 4,660 |
| 4,370 |
| 3,274 |
|
| Prior service cost (credit) amortization | 111 |
| 111 |
| 111 |
| (365 | ) | (365 | ) | (364 | ) | 106 |
| 111 |
| 111 |
| (365 | ) | (365 | ) | (365 | ) |
| Net periodic benefit cost | | $ | 6,636 |
| $ | 7,743 |
| $ | 6,207 |
| $ | 9,915 |
| $ | 9,163 |
| $ | 8,841 |
|
| Special termination benefit | | 3,730 |
| — |
| — |
| 490 |
| — |
| — |
|
| Net periodic benefit cost recognized as expense | $ | 7,743 |
| $ | 6,207 |
| $ | 7,690 |
| $ | 9,163 |
| $ | 8,841 |
| $ | 7,594 |
| $ | 10,366 |
| $ | 7,743 |
| $ | 6,207 |
| $ | 10,405 |
| $ | 9,163 |
| $ | 8,841 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Assumptions
The weighted average assumptions used to determine the Company’s benefit costs during the fiscal years below and obligations as of September 30, are as follows:
| | | | Pension | | OPEB | | Pension | | OPEB | |
| | 2017 | | 2016 | | 2015 | | 2017 | | 2016 | | 2015 | | 2018 | | 2017 | | 2016 | | 2018 | | 2017 | | 2016 | |
| Benefit costs: | | | | | | | | | | | | | | | | | | | | | | | | |
| Discount rate | 3.96/3.94% | | 4.50 | % | | 4.55 | % | | 4.08/4.01% |
| (1) | 4.60/4.55% |
| (1) | 4.55 | % | | 4.04/4.03% | | 3.96/3.94% |
| | 4.50 | % | | 4.12/4.08% |
| (1) | 4.08/4.01% |
| (1) | 4.60/4.55% |
| |
| Expected asset return | 7.75 | % | | 8.75 | % | | 8.75 | % | | 7.75 | % | | 8.75 | % | | 8.75 | % | | 7.50 | % | | 7.75 | % | | 8.75 | % | | 7.50 | % | | 7.75 | % | | 8.75 | % | |
| Compensation increase | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.25 | % | | 3.25/3.50% |
| (1) | 3.50 | % | | 3.50 | % | | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.25/3.50% |
| | 3.25/3.50% |
| (1) | 3.25/3.50% |
| | 3.50 | % | |
| Obligations: | | | | | | | | | | | | | | | | | | | | | | | | |
| Discount rate | 4.03 | % | | 3.96/3.94% |
| (1) | 4.50 | % | | 4.12/4.08% |
| (1) | 4.08/4.01% |
| (1) | 4.60/4.55% |
| (1) | 4.36/4.35% |
| | 4.03 | % | (1) | 3.96/3.94% |
| | 4.38/4.37% |
| (1) | 4.12/4.08% |
| (1) | 4.08/4.01% |
| (1) |
| Compensation increase | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.50 | % | | 3.50 | % | | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.25/3.50% |
| (1) | 3.25/3.50% |
| | 3.50 | % | |
| |
| (1) | Percentages for represented and nonrepresented plans, respectively. |
When measuring its projected benefit obligations, the Company uses an aggregate discount rate at which its obligation could be effectively settled. The Company determines a single weighted average discount rate based on a yield curve comprised of rates of return on a population of high quality debt issuances (AA- or better) whose cash flows (via coupons or maturities) match the timing and amount of its expected future benefit payments. Prior to October 1, 2016, the Company used the same assumed rate to measure the service and interest cost components of its net periodic benefit costs. Effective October 1, 2016, the Company changed its method of measuring its service and interest costs from the aggregate approach to a disaggregated, or spot rate, approach. Under the new approach, the Company applies the duration specificduration-specific spot rates from the full yield curve, as of the measurement date, to each year’s future benefit payments. The Company believes that the new methodthis provides for a more precise measurement of its service and interest costs by aligning the timing of the plans’ separate future cash flows to the corresponding spot rates on the yield curve. Accordingly, the Company accounted for this change prospectively as a change in accounting estimate.
Information relating to the assumed HCCTR used to determine expected OPEB benefits as of September 30, and the effect of a one1 percent change in the rate, are as follows:
| | | ($ in thousands) | 2017 | | 2016 | | 2015 | 2018 | | 2017 | | 2016 |
| HCCTR | 8.3 | % | | 8.5 | % | | 6.7 | % | 7.9 | % | | 8.3 | % | | 8.5 | % |
| Ultimate HCCTR | 4.5 | % | | 4.5 | % | | 4.8 | % | 4.5 | % | | 4.5 | % | | 4.5 | % |
| Year ultimate HCCTR reached | 2025 |
| | 2025 |
| | 2022 |
| 2024 |
| | 2025 |
| | 2025 |
|
| Effect of a 1 percentage point increase in the HCCTR on: | | | | | | | | | | |
| Year-end benefit obligation | $ | 32,019 |
| | $ | 28,803 |
| | $ | 26,025 |
| $ | 36,260 |
| | $ | 32,019 |
| | $ | 28,803 |
|
| Total service and interest cost | $ | 2,468 |
| | $ | 2,331 |
| | $ | 2,026 |
| $ | 2,482 |
| | $ | 2,468 |
| | $ | 2,331 |
|
| Effect of a 1 percentage point decrease in the HCCTR on: | | | | | | | | | | |
| Year-end benefit obligation | $ | (25,466 | ) | | $ | (22,862 | ) | | $ | (20,427 | ) | $ | (28,743 | ) | | $ | (25,466 | ) | | $ | (22,862 | ) |
| Total service and interest costs | $ | (1,909 | ) | | $ | (1,801 | ) | | $ | (1,593 | ) | $ | (1,937 | ) | | $ | (1,909 | ) | | $ | (1,801 | ) |
The Company’s investment objective is a long-term real rate of return on assets before permissible expenses that is approximately 5 percent greater than the assumed rate of inflation, as measured by the consumer price index. The expected long-term rate of return is based on the asset categories in which the Company invests and the current expectations and historical performance for these categories.
The mix and targeted allocation of the pension and OPEB plans’ assets are as follows:
| | | | 2018 | Assets at | 2019 | Assets at |
| | Target | September 30, | Target | September 30, |
| Asset Allocation | Allocation | 2017 |
| | 2016 |
| | Allocation | 2018 |
| | 2017 |
| |
| U.S. equity securities | 40 | % | | 39 | % | | 38 | % | | 34 | % | | 41 | % | | 39 | % | |
| International equity securities | 20 |
| | 21 |
| | 20 |
| | 17 |
| | 19 |
| | 21 |
| |
| Fixed income | 40 |
| | 40 |
| | 42 |
| | 41 |
| | 37 |
| | 40 |
| |
| Other assets | | 8 |
| | 3 |
| | — |
| |
| Total | 100 | % | | 100 | % | | 100 | % | | 100 | % | | 100 | % | | 100 | % | |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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 United States. The adoption of the new mortality tables resulted in an increase toprojection scale, MP-2017, did not materially impact the projected benefit obligation for the plans.
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following fiscal years:
| | | (Thousands) | Pension | OPEB | Pension | OPEB |
| 2018 | $ | 8,928 |
| $ | 4,230 |
| |
| 2019 | $ | 9,712 |
| $ | 4,807 |
| $ | 10,320 |
| $ | 5,450 |
|
| 2020 | $ | 10,549 |
| $ | 5,435 |
| $ | 11,769 |
| $ | 6,512 |
|
| 2021 | $ | 11,502 |
| $ | 6,061 |
| $ | 12,399 |
| $ | 7,096 |
|
| 2022 | $ | 12,469 |
| $ | 6,755 |
| $ | 13,239 |
| $ | 7,810 |
|
| 2023 - 2027 | $ | 79,081 |
| $ | 43,267 |
| |
| 2023 | | $ | 14,217 |
| $ | 8,413 |
|
| 2024 - 2028 | | $ | 85,426 |
| $ | 50,869 |
|
The Company’s OPEB plans provide prescription drug benefits that are actuarially equivalent to those provided by Medicare Part D. Therefore, under the Medicare Prescription Drug, Improvement and Modernization Act of 2003, the Company qualifies for federal subsidies.
The following estimated subsidy payments are as follows:expected to be paid during the following fiscal years:
| | | | Estimated Subsidy Payment | Estimated Subsidy |
| Fiscal Year | (Thousands) | |
| 2018 | $262 | |
| (Thousands) | | Payment |
| 2019 | $283 | | $ | 280 |
|
| 2020 | $311 | | $ | 316 |
|
| 2021 | $342 | | $ | 347 |
|
| 2022 | $373 | | $ | 375 |
|
| 2023 - 2027 | $2,574 | |
| 2023 | | | $ | 417 |
|
| 2024 - 2028 | | | $ | 2,787 |
|
Pension and OPEB assets held in the master trust, measured at fair value, as of September 30, are summarized as follows:
| | | | Quoted Prices in Active Markets for Identical Assets (Level 1) | Quoted Prices in Active Markets for Identical Assets (Level 1) |
| (Thousands) | Pension | | OPEB | Pension | | OPEB |
| Assets | 2017 | | 2016 | | 2017 | | 2016 | 2018 | | 2017 | | 2018 | | 2017 |
| Money market funds | $ | — |
| | $ | — |
| | $ | 11 |
| | $ | 9 |
| $ | 8,207 |
| | $ | — |
| | $ | 2,273 |
| | $ | 11 |
|
| Registered Investment Companies: | | | | | | | | | | | | | | |
| Equity Funds: | | | | | | | | | | | | | | |
| Large Cap Index | 88,321 |
| | 78,306 |
| | 23,986 |
| | 19,532 |
| 97,016 |
| | 88,321 |
| | 27,340 |
| | 23,986 |
|
| Extended Market Index | 16,329 |
| | 16,250 |
| | 4,409 |
| | 4,114 |
| 17,741 |
| | 16,329 |
| | 5,014 |
| | 4,409 |
|
| International Stock | 56,446 |
| | 50,702 |
| | 15,000 |
| | 12,997 |
| 53,516 |
| | 56,446 |
| | 14,874 |
| | 15,000 |
|
| Fixed Income Funds: | | | | | | | | | | | | | | |
| Emerging Markets | 13,516 |
| | 12,906 |
| | 3,551 |
| | 3,294 |
| 11,754 |
| | 13,516 |
| | 3,264 |
| | 3,551 |
|
| Core Fixed Income | — |
| | — |
| | 8,082 |
| | 7,177 |
| — |
| | — |
| | 7,970 |
| | 8,082 |
|
| Opportunistic Income | — |
| | — |
| | 4,744 |
| | 4,155 |
| — |
| | — |
| | 4,798 |
| | 4,744 |
|
| Ultra Short Duration | — |
| | — |
| | 4,673 |
| | 4,082 |
| — |
| | — |
| | 4,830 |
| | 4,673 |
|
| High Yield Bond Fund | 26,540 |
| | 25,976 |
| | 7,078 |
| | 6,675 |
| 25,720 |
| | 26,540 |
| | 7,236 |
| | 7,078 |
|
| Long Duration Fund | 70,591 |
| | 65,735 |
| | — |
| | — |
| 64,039 |
| | 70,591 |
| | — |
| | — |
|
| Total assets at fair value | $ | 271,743 |
| | $ | 249,875 |
| | $ | 71,534 |
| | $ | 62,035 |
| |
| Total assets | | $ | 277,993 |
| | $ | 271,743 |
| | $ | 77,599 |
| | $ | 71,534 |
|
The Plan had no Level 2 or Level 3 fair value measurements during fiscal 20172018 and 2016,2017, and there have been no changes in valuation methodologies as of September 30, 2017. 2018. The Plan held $1.8 million of other assets as of September 30, 2018, that are valued using net asset value as a practical expedient, which are excluded from the fair value hierarchy.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The following is a description of the valuation methodologies used for assets measured at fair value:
Money Market funds — Represents bank balances and money market funds that are valued based on the net asset value of shares held at year end.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Registered Investment Companies — Equity and fixed income funds valued at the net asset value of shares held by the plan at year end as reported on the active market on which the individual securities are traded.
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. As of January 1, 2015, the Company matches 65 percent of participants’ contributions up to 6 percent of base compensation. Represented NJRHS employees, non-represented employees hired on or after October 1, 2009, and NJNG represented employees hired on or after January 1, 2012, are eligible for an employer special contribution of between 3 and 4 percent of base compensation, depending on years of service, into the Savings Plan on their behalf. The amount expensed and contributed for the matching provision of the Savings Plan was $2.9$3.9 million in fiscal 20172018, $2.9 million in fiscal 2017 and $2.8 million in fiscal 2016 and $2.6 million in fiscal 2015.2016. The amount contributed for the employer special contribution of the Savings Plan was $781,000$959,000 in fiscal 20172018, $781,000 in fiscal 2017 and $571,000 in fiscal 2016 and $461,000 in fiscal 2015.2016.
12.11. ASSET RETIREMENT OBLIGATIONS
The Company recognizes AROs when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. Accordingly, the Company recognizes AROs related to the costs associated with cutting and capping its main and service gas distribution pipelines of NJNG, which is required by New Jersey law when taking such gas distribution pipeline out of service. The Company also recognizes AROs related to Clean Energy Ventures’ solar and wind assets when there are decommissioning provisions in Clean Energy Ventures’ lease agreements that require removal of the asset.
Accretion amounts associated with NJNG’s ARO isare recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets. During fiscal 2016, accretion amounts were not reflected as an expense, but rather were deferred as a regulatory asset and netted against NJNG’s regulatory liabilities, for presentation purposes, on the Consolidated Balance Sheets. Accretion amounts associated with Clean Energy Ventures’ ARO are recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations.
The following is an analysis of the change in the Company’s AROs for the fiscal yearyears ended September 30:
|
| | | | | | | | | | | | | |
| (Thousands) | 2017 | | 2016 |
| | NJNG | NJRCEV | | NJNG | NJRCEV |
| Balance at October 1 | $ | 23,521 |
| $ | 4,858 |
| | $ | 16,773 |
| $ | 2,372 |
|
| Accretion | 1,304 |
| 245 |
| | 1,048 |
| 158 |
|
| Additions | 729 |
| 1,492 |
| | 783 |
| 2,328 |
|
| Revisions in estimated cash flows | (245 | ) | — |
| | 5,320 |
| — |
|
| Retirements | (484 | ) | — |
| | (403 | ) | — |
|
| Balance at period end | $ | 24,825 |
| $ | 6,595 |
| | $ | 23,521 |
| $ | 4,858 |
|
During fiscal 2016, NJNG revised its retirement assumptions to reflect an increase in inflation rates and construction costs. These increases, were discounted using the current credit adjusted risk free rate, resulting in an increase of approximately $5.3 million to the ARO liability. |
| | | | | | | | | | | | | |
| (Thousands) | 2018 | | 2017 |
| | NJNG | NJRCEV | | NJNG | NJRCEV |
| Balance at October 1 | $ | 24,825 |
| $ | 6,595 |
| | $ | 23,521 |
| $ | 4,858 |
|
| Accretion | 1,366 |
| 198 |
| | 1,304 |
| 245 |
|
| Additions | 1,880 |
| 517 |
| | 729 |
| 1,492 |
|
| Revisions in estimated cash flows | (2,133 | ) | — |
| | (245 | ) | — |
|
| Retirements | (298 | ) | — |
| | (484 | ) | — |
|
| Reclassification to held for sale or sold | — |
| (4,262 | ) | | — |
| — |
|
| Balance at period end | $ | 25,640 |
| $ | 3,048 |
| | $ | 24,825 |
| $ | 6,595 |
|
Accretion for the next five years, for the fiscal years ended September 30, is estimated to be as follows:
| | | | | | | | Estimated |
| (Thousands) | | | | Accretion |
| Fiscal Year Ended September 30, | Estimated Accretion | |
| 2018 | | $ | 1,644 |
| | |
| 2019 | | 1,718 |
| | $ | 1,557 |
|
| 2020 | | 1,795 |
| | 1,627 |
|
| 2021 | | 1,877 |
| | 1,702 |
|
| 2022 | | 1,960 |
| | 1,778 |
|
| 2023 | | 1,863 |
|
| Total | | $ | 8,994 |
| | $ | 8,527 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
13.12. INCOME TAXES
A reconciliation of the U.S. federal statutory rate of 35 percent to the effective rateThe income tax (benefit) provision from operations for the fiscal years ended September 30, 2017, 2016 and 2015 is as follows:
|
| | | | | | | | | |
| (Thousands) | 2017 | 2016 | 2015 |
| Statutory income tax expense | $ | 52,643 |
| $ | 54,321 |
| $ | 84,239 |
|
| Change resulting from: | | | |
| State income taxes | 8,222 |
| 6,044 |
| 8,233 |
|
| Cost of removal of assets placed in service prior to1981 | (6,886 | ) | (5,738 | ) | (5,149 | ) |
| Investment/production tax credits | (34,526 | ) | (32,491 | ) | (30,096 | ) |
| Basis adjustment of solar assets due to ITC | 4,256 |
| 4,453 |
| 4,861 |
|
| AFUDC equity | (2,624 | ) | (1,531 | ) | (1,339 | ) |
| Other | (2,742 | ) | (1,528 | ) | (1,025 | ) |
| Income tax provision | $ | 18,343 |
| $ | 23,530 |
| $ | 59,724 |
|
| Effective income tax rate | 12.2 | % | 15.2 | % | 24.8 | % |
The income tax (benefit) provision from operations consists of the following:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Current: | | |
| Federal | $ | (16,023 | ) | $ | (23,597 | ) | $ | 20,492 |
| $ | (2,848 | ) | $ | (16,023 | ) | $ | (23,597 | ) |
| State | 2,470 |
| (2,209 | ) | 5,473 |
| 4,563 |
| 2,470 |
| (2,209 | ) |
| Deferred: | | |
| Federal | 54,965 |
| 70,386 |
| 56,480 |
| (40,785 | ) | 54,965 |
| 70,386 |
|
| State | 11,457 |
| 11,441 |
| 7,375 |
| 6,731 |
| 11,457 |
| 11,441 |
|
| Investment/production tax credits | (34,526 | ) | (32,491 | ) | (30,096 | ) | (21,446 | ) | (34,526 | ) | (32,491 | ) |
| Income tax provision | $ | 18,343 |
| $ | 23,530 |
| $ | 59,724 |
| |
| Income tax (benefit) provision | | $ | (53,785 | ) | $ | 18,343 |
| $ | 23,530 |
|
TheAs of September 30, the temporary differences, which give rise to deferred tax assets and (liabilities), consist of the following:
| | | (Thousands) | 2017 | | 2016 | 2018 | | 2017 |
| Deferred tax assets | | | | | | |
Investment tax credits (1) | $ | 111,642 |
| | $ | 76,517 |
| $ | 123,258 |
| | $ | 111,642 |
|
| Deferred service contract revenue | 3,877 |
| | 3,601 |
| — |
| | 3,877 |
|
| Incentive compensation | 6,260 |
| | 8,128 |
| 4,646 |
| | 6,260 |
|
| Fair value of derivatives | 11,519 |
| | 1,179 |
| 8,411 |
| | 11,519 |
|
Federal net operating losses | 28,487 |
| | 27,541 |
| 24,500 |
| | 28,487 |
|
| State net operating losses | 23,597 |
| | 18,113 |
| 34,754 |
| | 23,597 |
|
| Overrecovered gas costs | — |
| | 3,831 |
| |
| Amortization of intangibles | | 3,737 |
| | 2,747 |
|
| Conservation incentive plan | | 1,955 |
| | — |
|
| Other | 13,845 |
| | 11,668 |
| 8,213 |
| | 11,098 |
|
| Total deferred tax assets | $ | 199,227 |
| | $ | 150,578 |
| $ | 209,474 |
| | $ | 199,227 |
|
| Deferred tax liabilities | | | | | | |
| Property related items | $ | (620,850 | ) | | $ | (532,027 | ) | $ | (392,886 | ) | | $ | (620,850 | ) |
| Remediation costs | (11,625 | ) | | (7,928 | ) | (9,229 | ) | | (11,625 | ) |
| Equity investments | (38,370 | ) | | (37,740 | ) | (31,956 | ) | | (38,370 | ) |
| Postemployment benefits | (6,855 | ) | | (7,902 | ) | (353 | ) | | (6,855 | ) |
| Conservation incentive plan | (7,195 | ) | | (14,953 | ) | — |
| | (7,195 | ) |
| Underrecovered gas costs | (4,035 | ) | | — |
| (1,156 | ) | | (4,035 | ) |
| Other | (16,643 | ) | | (14,610 | ) | (7,826 | ) | | (16,643 | ) |
| Total deferred tax liabilities | $ | (705,573 | ) | | $ | (615,160 | ) | $ | (443,406 | ) | | $ | (705,573 | ) |
| | | | | |
| Total net deferred tax liabilities | $ | (506,346 | ) | | $ | (464,582 | ) | $ | (233,932 | ) | | $ | (506,346 | ) |
| |
| (1) | Includes $2.3$2.2 million and $2.5$2.3 million for NJNG for fiscal 20172018 and 20162017, respectively, which is being amortized over the life of the related assets, and$109.3121.1 million and $74$109.3 million for Clean Energy Ventures for fiscal 20172018 and 20162017, respectively, which is ITC carryforward. |
| |
| (2) | See discussion of federal net operating loss utilization in the Other Tax Items section of this note. |
A reconciliation of the U.S. federal statutory rate to the effective rate from operations for the fiscal years ended September 30, is as follows:
|
| | | | | | | | | |
| (Thousands) | 2018 | 2017 | 2016 |
| Statutory income tax expense | $ | 44,014 |
| $ | 52,643 |
| $ | 54,321 |
|
| Change resulting from: | | | |
Tax Act - nonutility excess deferred income taxes (1) | (59,627 | ) | — |
| — |
|
Tax Act - utility excess deferred income taxes refunded to customers (1) | (14,323 | ) | — |
| — |
|
Tax Act - utility excess deferred income taxes amortized (1) | (1,786 | ) | — |
| — |
|
| State income taxes, net of federal benefit | 7,092 |
| 8,222 |
| 6,044 |
|
| Cost of removal of assets placed in service prior to1981 | (5,829 | ) | (6,886 | ) | (5,738 | ) |
| Investment/production tax credits | (21,446 | ) | (34,526 | ) | (32,491 | ) |
| Basis adjustment of solar assets due to ITC | 1,080 |
| 4,256 |
| 4,453 |
|
| AFUDC equity | (2,117 | ) | (2,624 | ) | (1,531 | ) |
| Other | (843 | ) | (2,742 | ) | (1,528 | ) |
| Income tax (benefit) provision | $ | (53,785 | ) | $ | 18,343 |
| $ | 23,530 |
|
Effective income tax rate (2) (3) | (29.9 | )% | 12.2 | % | 15.2 | % |
| |
| (1) | For a more detailed description, see The Tax Act section of this note. |
| |
| (2) | The U.S. federal statutory rate was 24.5 percent for fiscal 2018 and 35 percent for fiscal 2017 and 2016. |
| |
| (3) | The effective tax rate without the impact of the Tax Act would have been 12.4 percent for fiscal 2018. |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
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, Iowa, Kansas, Louisiana, Maryland, Montana, New Jersey, New York, North Carolina, Pennsylvania, South Carolina, Texas, Utah, Virginia and the City of New York. The Company neither files in, nor believes it has a filing requirement in, any foreign jurisdictions other than Canada. Due to certain available tax treaty benefits, the Company incurs no tax liability in Canada.
The Company’s federal income tax returns through fiscal 20132014 have either been reviewed by the IRS, or the related statute of limitations has expired and all matters have been settled. Federal income tax returns for periods subsequent to fiscal 20132014 are not currently under examination by the IRS. For all periods subsequent to those ended September 30, 2014, 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, 2013 are statutorily open to examination.
The State of New Jersey is currently conducting a sales and use tax examination for the period from July 1, 2011 through JuneSeptember 30, 2016.2018.
On March 7, 2018, the State of New Jersey notified the Company that it will conduct a general tax examination for fiscal years 2014 through 2017 related to NJRHS. The audit is currently in the information gathering stage. All periods subsequent to those ended September 30, 2013, are statutorily open to examination in all applicable states with the exception of New York. In New York, all periods subsequent to September 30, 2014, are statutorily open to examination.
The Company evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with unrecognized tax benefits. As of September 30, 20172018 and 2016,2017, based on its analysis, the Company determined there was no need to recognize any liabilities associated with uncertain tax positions.
The Tax Act
On December 22, 2017, the President signed into law the Tax Act. The law made several changes to the Internal Revenue Code of 1986, as amended, the most impactful to the Company of which was a reduction in the federal corporate income tax rate from 35 percent to 21 percent that became effective January 1, 2018. Since the Company's fiscal year end is September 30, it is required by the Internal Revenue Code to calculate a statutory rate based upon the federal tax rates in effect before and after the effective date of the change in the taxable year that includes the effective date. Accordingly, the Company will use a federal statutory tax rate of 24.5 percent during fiscal 2018 and will use the enacted rate of 21 percent beginning in fiscal 2019.
The SEC issued guidance in Staff Accounting Bulletin 118 to address the changes in estimates associated with impacts resulting from the Tax Act, which allows companies to record provisional amounts during a one-year measurement period. The Company calculated an original estimate for the measurement and accounting for certain effects of the Tax Act, including the remeasurement of deferred tax assets and liabilities to reflect the rates that will be in effect when the deferred tax assets and liabilities are expected to be realized or settled. The adjustments to deferred income taxes were based on assumptions the Company made with respect to its book versus tax differences and the timing of when those differences will reverse, including estimations associated with depreciation and the settlement of derivative unrealized amounts. Therefore, the revaluation of net deferred tax liabilities was subject to change as information and assumptions were updated each quarter for actual results.
As a result of the changes associated with the Tax Act, NJNG recorded a decrease in its net deferred tax liability of $228.4 million, which included $164.3 million for the revaluation of its deferred income taxes and $64.1 million for the accounting of the income tax effects on the revaluation of those deferred income taxes. These amounts were recorded as a regulatory liability on the Consolidated Balance Sheets. On May 22, 2018, the BPU approved a refund of $31 million, which included approximately $20.1 million of the initial revaluation of excess deferred income taxes, $9 million for the overcollection of taxes from customers from January 1, 2018 through March 31, 2018, and interest on the overcollected taxes at the Company's short-term debt rate. These credits were returned to customer accounts in June 2018.
During fiscal 2018, NJNG credited approximately $17 million to income tax (benefit) provision on the Consolidated Statements of Operations, which includes $14.3 million attributable to the remeasurement of deferred income taxes, $1.8 million for the amortization of excess deferred income taxes primarily related to timing differences associated with utility plant depreciation and $880,000 related to the revaluation of deferred income taxes not included in base rates. As of September 30, 2018, the regulatory liability included excess deferred income taxes of $205.4 million, which requires amortization over the remaining life of the utility plant consistent with IRS normalization principles.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The (decrease) increase of the net deferred tax liability due to the impact of the Tax Act that was recognized on the Consolidated Statements of Operations for the remaining entities, was as follows:
|
| | | |
| (Thousands) | 2018 |
| Income tax (benefit) provision | |
| Clean Energy Ventures | $ | (61,423 | ) |
| Energy Services | 6,062 |
|
| Midstream | (13,946 | ) |
| Home Services and Other | 9,680 |
|
| Total | $ | (59,627 | ) |
There was a $2.1 million change in the original estimate resulting from the use of actual results instead of estimated results through the Company’s fourth fiscal quarter.
As of September 30, 2018, our accounting for the income tax effects of the Tax Act is considered complete. The Company does not expect to make any further adjustments to the amounts recorded as a result of the Tax Act.
Other Tax Items
As of September 30, 20172018 and 2016,2017, the Company has consolidated federal income tax net operating losses of approximately $136.8 million and $125.3 million, and $78.7 million, respectively, whichrespectively. Federal net operating losses can generally can be carried back two years and forward 20 years.years and will begin to expire in fiscal 2036, with the remainder expiring by 2038. The Company plansexpects to exercise its ability to carryback its federal net operating losses. Additionally,losses to offset taxable income in prior periods.
For the net operating losses it expects to carryback, the Company estimated the portion considered refundable and recorded receivables of approximately $23 million and $15.4 million as of September 30, 2018 and 2017, respectively, as a component of other noncurrent assets on the Consolidated Balance Sheets. Upon filing amended federal income tax returns to carryback its remaining federal net operating losses totaling $24.5 million, the Company will reduce its taxable income in those periods and 2016,recapture federal investment tax credits of the same amount that were previously utilized to offset taxable income.
In addition, as of September 30, 2018 and 2017, the Company has an ITC/PTC carryforward of approximately $121.1 million and $109.3 million, respectively, which each have a life of 20 years. When the Company carries back the federal net operating losses noted above, it expects to recapture investment tax credits totaling $24.5 million. These recaptured tax credits are in addition to the $121.1 million and will be carried forward to offset future taxable income. The Company expects to utilize this entire carryforward, which would begin to expire in fiscal 2033.
As of September 30, 2018 and 2017, the Company has state income tax net operating losses of approximately $471.7$578.8 million and $310.6$471.7 million, respectively. These state net operating losses have varying carry forward periods dictated by the state in which they were incurred; these state carry forward periods range from seven to 20 years. The Company has recorded deferred federalyears and state tax assets of approximately $52.1 million and federal income tax receivables of approximately$15.4 million on the Consolidated Balance Sheets, reflecting the tax benefit associatedwould begin to expire in fiscal 2021, with the loss carrybacks.majority expiring after 2035.
The Company recordedIn March 2018, Clean Energy Ventures committed to a valuation allowance associated withplan to sell its wind assets and expects that the sale will be completed within the next 12 months. As a result of the planned sale, it is more likely than not that certain state net operating loss carryforwards will not be realizable prior to their expiration. As of $1September 30, 2018, the Company had a valuation allowance of $4 million related to NJRCEVstate net operating loss carryforwards in the state of Montana, as of September 30, 2017,Iowa, Kansas and $262,000 related to CR&R in the state of New Jersey, as of September 30, 2016, which was deemed more likely than not to be realized prior to expiration and therefore was released during fiscal 2017.
In addition, asWyoming. As of September 30, 2017, the Company has an ITC/PTC carryforwardhad a valuation allowance of approximately $109.3$1 million which hasrelated to state net operating loss carryforwards in Montana. This is included as a lifecomponent of 20 years. This carryforward will begin to expire in fiscal 2035. The Company expects to utilize this entire carryforward.Other within the composition of deferred tax assets.
The deferred tax assets will expire as follows:
|
| | | |
| (Thousands) | |
| Fiscal years 2018 - 2022 | $ | 313 |
|
| Fiscal years 2023 - 2027 | 1,051 |
|
| Fiscal years 2028 - 2032 | 796 |
|
| Fiscal years 2033 - 2037 | 159,237 |
|
| Total | $ | 161,397 |
|
In December 2015, the Consolidated Appropriations Act extended the 30 percent ITC for solar property that is under construction on or before December 31, 2019. The credit will decline to 26 percent for property under construction during 2020, and to 22 percent for property under construction during 2021. For any property that is under construction before 2022, but not placed in service before 2024, the ITC will be reduced to 10 percent. In addition, the Consolidated Appropriations Act retroactively extended the PTC for five years through December 31, 2019, with a gradual three-year phase outphase-out for any project for which construction of the facility begins after December 31, 2016.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
14.13. COMMITMENTS AND CONTINGENT LIABILITIES
Cash Commitments
NJNG has entered into long-term contracts, expiring at various dates through October 2033,September 2024, for the supply, storage and transportation of natural gas. These contracts include annual fixed charges of approximately $98.6$112 million at current contract rates and volumes, which are recoverable through BGSS.
For the purpose of securing storage and pipeline capacity, our Energy Services segment enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by Energy Services to maintain the ability to access such natural gas storage or pipeline capacity, during a fixed time period, which generally ranges from one to 10 years. Demand charges are established by interstate storage and pipeline operators and are regulated by FERC. These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and/or transport natural gas utilizing their respective assets.
Commitments as of September 30, 2017,2018, for natural gas purchases and future demand fees for the next five fiscal year periods, are as follows:
| | | (Thousands) | 2018 | 2019 | 2020 | 2021 | 2022 | Thereafter | 2019 | 2020 | 2021 | 2022 | 2023 | Thereafter |
| Energy Services: | | |
| Natural gas purchases | $ | 296,491 |
| $ | 114,817 |
| $ | 22,270 |
| $ | 11,488 |
| $ | — |
| $ | — |
| $ | 428,015 |
| $ | 28,389 |
| $ | 10,965 |
| $ | — |
| $ | — |
| $ | — |
|
| Storage demand fees | 32,870 |
| 22,638 |
| 13,350 |
| 9,041 |
| 5,833 |
| 2,746 |
| 31,716 |
| 19,926 |
| 13,478 |
| 8,904 |
| 4,212 |
| 991 |
|
| Pipeline demand fees | 55,916 |
| 32,412 |
| 23,804 |
| 21,621 |
| 19,653 |
| 19,311 |
| 52,148 |
| 49,790 |
| 28,209 |
| 24,153 |
| 18,988 |
| 5,151 |
|
| Sub-total Energy Services | $ | 385,277 |
| $ | 169,867 |
| $ | 59,424 |
| $ | 42,150 |
| $ | 25,486 |
| $ | 22,057 |
| $ | 511,879 |
| $ | 98,105 |
| $ | 52,652 |
| $ | 33,057 |
| $ | 23,200 |
| $ | 6,142 |
|
| NJNG: | | |
| Natural gas purchases | $ | 51,050 |
| $ | 41,156 |
| $ | 2,514 |
| $ | — |
| $ | — |
| $ | — |
| $ | 65,737 |
| $ | 37,727 |
| $ | 33,738 |
| $ | 33,546 |
| $ | 34,221 |
| $ | 35,762 |
|
| Storage demand fees | 30,042 |
| 26,628 |
| 15,331 |
| 8,231 |
| 7,804 |
| 3,903 |
| 31,384 |
| 24,263 |
| 14,251 |
| 12,930 |
| 7,899 |
| 6,066 |
|
| Pipeline demand fees | 68,544 |
| 102,091 |
| 100,909 |
| 91,231 |
| 89,859 |
| 642,481 |
| 80,609 |
| 96,241 |
| 89,236 |
| 91,946 |
| 87,240 |
| 586,266 |
|
| Sub-total NJNG | $ | 149,636 |
| $ | 169,875 |
| $ | 118,754 |
| $ | 99,462 |
| $ | 97,663 |
| $ | 646,384 |
| $ | 177,730 |
| $ | 158,231 |
| $ | 137,225 |
| $ | 138,422 |
| $ | 129,360 |
| $ | 628,094 |
|
| Total | $ | 534,913 |
| $ | 339,742 |
| $ | 178,178 |
| $ | 141,612 |
| $ | 123,149 |
| $ | 668,441 |
| $ | 689,609 |
| $ | 256,336 |
| $ | 189,877 |
| $ | 171,479 |
| $ | 152,560 |
| $ | 634,236 |
|
As of September 30, 2017,2018, the Company’s future minimum lease payments under various operating leases will not be more than $2.6$3.7 million annually for the next five years and $38.3$50 million in the aggregate for all years thereafter.
Guarantees
As of September 30, 2017,2018, there were NJR guarantees covering approximately $331.4$418.1 million of Energy Services’ natural gas purchases and demand fee commitments not yet reflected in accounts payable on the Consolidated Balance Sheets.
Legal Proceedings
Manufactured Gas Plant Remediation
NJNG is responsible for the remedial cleanup of five 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 Administrative Consent Orders or Memoranda of Agreement with the NJDEP.
NJNG may recoverrecovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. NJNG currently recovers approximately$9.4recovered approximately $9.4 million annually through its SBC RAC. On November 17, 2017, NJNG filed it'sIn July 2018, the BPU approved NJNG's annual SBC applicationfiling requesting a reduction in the RAC, which will decreasedecreased the annual recovery to $7 million, effective September 1, 2018. On September 21, 2018, NJNG filed its annual SBC application requesting to recover remediation expenses incurred through June 30, 2018, which will result in an annual increase of $1.4 million, effective April 1, 2018.2019. As of September 30, 2017, $28.52018, $33 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Consolidated Balance Sheets.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
In the first quarter of fiscal 2018, the NJDEP contacted NJNG regarding its association with a parcel of land, located within NJNG's service territory, which may have been a MGP site for a period of time. NJNG is investigating to determine the nature and extent of its relationship to the parcel, its previous owners and the operations conducted on the site and has accrued for costs associated with the preliminary investigation of the existence of potential contaminants. NJNG will continue to gather information to determine whether a potential obligation exists to undertake remedial action, if any, and whether there are other potentially responsible parties.
NJNG periodically, and at least annually, performs an environmental review of the MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester and Toms River, 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 to remediate and monitor the five MGP sites for which it is responsible, including potential liabilities for Natural Resource Damagesnatural 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 $117.6$117.7 million to $205.2$204.1 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, as of September 30, 2017,2018, NJNG recorded an MGP remediation liability and a corresponding regulatory asset of $149$130.8 million on the Consolidated Balance Sheets, based on the most likely amount. This was reduced from $172$149 million in fiscal 2016,2017, due to the completion of remediation work at some ofcertain sites and a reduction to the remediation scope at another site. 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.recoveries, if any.
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.
LitigationGeneral
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 connection with the conductordinary course of its 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 reserves for litigation for those matters that present loss contingencies as to which it is both probable that a loss will be incurred and the amount of such loss can be reasonably estimated. NJR also discloses contingent matters for which there is a reasonable possibility of a loss. Based upon currently available information, NJR believes that the results of litigation that is currently pending, taken together, will not have a materially adverse effect on the Company’s financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially higher than the amounts reserved.
The foregoing statements about NJR’s litigation are based upon the Company’s judgments, assumptions and estimates and are necessarily subjective and uncertain. The Company has a number of threatened and pending litigation matters at various stages. Certain of the Company’s significant litigation is described below.
OnStafford Township
In February 24, 2015, a natural gas fire and explosion occurred in Stafford Township, New Jersey as a result of a natural gas leak emanating from an underground pipe. There were no fatalities, although several employees of NJNG were injured and several homes were damaged. NJNG notified its insurance carrier and believes that any costs associated with the incident, including attorneys’ fees, property damage and other losses, will be substantially covered by insurance. The Company believes the resolution of any potentialthe remaining claims associated with the incident will not have a material effect on its financial condition, results of operations or cash flows. As of September 30, 2017, NJNG estimates that liabilities associated withSubrogated property damage claims will range between $600,000asserted against the Company and $3.2 millionco-defendants and has accrued the lower end of the range.cross-claims have been amicably resolved in August 2018.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
15.14. REPORTING SEGMENT AND OTHER OPERATIONS DATA
The Company organizes its businesses based on a combination of factors, including its products and its regulatory environment. As a result, the Company manages its businesses through the following reporting segments and other operations: the Natural Gas Distribution segment consists of regulated energy and off-system, capacity and storage management operations; the Clean Energy Ventures segment consists of capital investments in clean energy projects; the Energy Services segment consists of unregulated wholesale and retail energy operations; the Midstream segment consists of the Company’s investments in natural gas transportation and storage facilities; the Home Services and Other operations consist of heating, cooling and water appliance sales, installations and services, other investments and general corporate activities.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Information related to the Company’s various reporting segments and other operations is detailed below:
| | | (Thousands) | | |
| Fiscal Years Ended September 30, | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Operating revenues | | |
| Natural Gas Distribution | | |
| External customers | $ | 695,637 |
| $ | 594,346 |
| $ | 781,970 |
| $ | 731,865 |
| $ | 695,637 |
| $ | 594,346 |
|
| Clean Energy Ventures | | |
| External customers | 64,394 |
| 53,540 |
| 32,513 |
| 71,375 |
| 64,394 |
| 53,540 |
|
| Energy Services | | |
External customers (1) | 1,462,365 |
| 1,187,754 |
| 1,872,781 |
| 2,064,477 |
| 1,462,365 |
| 1,187,754 |
|
| Intercompany | 316 |
| 9,499 |
| 61,526 |
| 48,327 |
| 316 |
| 9,499 |
|
| Subtotal | 2,222,712 |
| 1,845,139 |
| 2,748,790 |
| 2,916,044 |
| 2,222,712 |
| 1,845,139 |
|
| Home Services and Other | | |
| External customers | 46,221 |
| 45,265 |
| 46,723 |
| 47,392 |
| 46,221 |
| 45,265 |
|
| Intercompany | 3,370 |
| 3,232 |
| 1,980 |
| 2,665 |
| 3,370 |
| 3,232 |
|
| Eliminations | (3,686 | ) | (12,731 | ) | (63,506 | ) | (50,992 | ) | (3,686 | ) | (12,731 | ) |
| Total | $ | 2,268,617 |
| $ | 1,880,905 |
| $ | 2,733,987 |
| $ | 2,915,109 |
| $ | 2,268,617 |
| $ | 1,880,905 |
|
| Depreciation and amortization | | |
| Natural Gas Distribution | $ | 49,347 |
| $ | 47,828 |
| $ | 43,085 |
| $ | 53,208 |
| $ | 49,347 |
| $ | 47,828 |
|
| Clean Energy Ventures | 31,834 |
| 23,971 |
| 17,297 |
| 31,877 |
| 31,834 |
| 23,971 |
|
| Energy Services | 63 |
| 88 |
| 90 |
| |
Energy Services (2) | | 76 |
| 63 |
| 88 |
|
| Midstream | 6 |
| 6 |
| 6 |
| 6 |
| 6 |
| 6 |
|
| Subtotal | 81,250 |
| 71,893 |
| 60,478 |
| 85,167 |
| 81,250 |
| 71,893 |
|
| Home Services and Other | 798 |
| 981 |
| 952 |
| 780 |
| 798 |
| 981 |
|
| Eliminations | (207 | ) | (126 | ) | (31 | ) | (246 | ) | (207 | ) | (126 | ) |
| Total | $ | 81,841 |
| $ | 72,748 |
| $ | 61,399 |
| $ | 85,701 |
| $ | 81,841 |
| $ | 72,748 |
|
Interest income (2)(3) | | |
| Natural Gas Distribution | $ | 555 |
| $ | 115 |
| $ | 336 |
| $ | 614 |
| $ | 555 |
| $ | 115 |
|
| Clean Energy Ventures | — |
| — |
| 26 |
| |
| Energy Services | 6 |
| 98 |
| 438 |
| 240 |
| 6 |
| 98 |
|
| Midstream | 2,195 |
| 1,524 |
| 977 |
| 3,374 |
| 2,195 |
| 1,524 |
|
| Subtotal | 2,756 |
| 1,737 |
| 1,777 |
| 4,228 |
| 2,756 |
| 1,737 |
|
| Home Services and Other | 590 |
| 397 |
| 217 |
| 1,476 |
| 590 |
| 397 |
|
| Eliminations | (1,312 | ) | (2,006 | ) | (1,414 | ) | (5,090 | ) | (1,312 | ) | (2,006 | ) |
| Total | $ | 2,034 |
| $ | 128 |
| $ | 580 |
| $ | 614 |
| $ | 2,034 |
| $ | 128 |
|
| |
| (1) | Includes sales to Canada, which accounted for .8, 2 and 3.7 percent of total operating revenues during fiscal 2017, 2016 and 2015, respectively. are immaterial. |
| |
| (2) | The amortization of acquired wholesale energy contracts is excluded above and is included in gas purchases - nonutility on the Unaudited Condensed Consolidated Statements of Operations. |
| |
| (3) | Included in other income, net on the Consolidated Statements of Operations. |
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
| | | (Thousands) | | |
| Fiscal Years Ended September 30, | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Interest expense, net of capitalized interest | | |
| Natural Gas Distribution | $ | 25,818 |
| $ | 19,930 |
| $ | 18,534 |
| $ | 25,299 |
| $ | 25,818 |
| $ | 19,930 |
|
| Clean Energy Ventures | 16,263 |
| 10,304 |
| 7,635 |
| 18,320 |
| 16,263 |
| 10,304 |
|
| Energy Services | 2,747 |
| 1,095 |
| 1,209 |
| 3,945 |
| 2,747 |
| 1,095 |
|
| Midstream | 960 |
| 287 |
| 717 |
| 1,667 |
| 960 |
| 287 |
|
| Subtotal | 45,788 |
| 31,616 |
| 28,095 |
| 49,231 |
| 45,788 |
| 31,616 |
|
| Home Services and Other | 410 |
| 252 |
| 49 |
| 7 |
| 410 |
| 252 |
|
| Eliminations | (1,312 | ) | (824 | ) | (423 | ) | (2,952 | ) | (1,312 | ) | (824 | ) |
| Total | $ | 44,886 |
| $ | 31,044 |
| $ | 27,721 |
| $ | 46,286 |
| $ | 44,886 |
| $ | 31,044 |
|
| Income tax (benefit) provision | | |
| Natural Gas Distribution | $ | 43,485 |
| $ | 34,951 |
| $ | 39,544 |
| $ | (1,910 | ) | $ | 43,485 |
| $ | 34,951 |
|
| Clean Energy Ventures | (31,161 | ) | (26,592 | ) | (26,968 | ) | (79,932 | ) | (31,161 | ) | (26,592 | ) |
| Energy Services | (4,015 | ) | 7,030 |
| 39,043 |
| 24,996 |
| (4,015 | ) | 7,030 |
|
| Midstream | 5,820 |
| 6,130 |
| 6,849 |
| (8,548 | ) | 5,820 |
| 6,130 |
|
| Subtotal | 14,129 |
| 21,519 |
| 58,468 |
| (65,394 | ) | 14,129 |
| 21,519 |
|
| Home Services and Other | 3,857 |
| 1,387 |
| 1,551 |
| 11,944 |
| 3,857 |
| 1,387 |
|
| Eliminations | 357 |
| 624 |
| (295 | ) | (335 | ) | 357 |
| 624 |
|
| Total | $ | 18,343 |
| $ | 23,530 |
| $ | 59,724 |
| $ | (53,785 | ) | $ | 18,343 |
| $ | 23,530 |
|
| Equity in earnings of affiliates | | |
| Midstream | $ | 17,797 |
| $ | 13,936 |
| $ | 17,487 |
| $ | 16,165 |
| $ | 17,797 |
| $ | 13,936 |
|
| Eliminations | (3,984 | ) | (4,421 | ) | (4,078 | ) | (3,157 | ) | (3,984 | ) | (4,421 | ) |
| Total | $ | 13,813 |
| $ | 9,515 |
| $ | 13,409 |
| $ | 13,008 |
| $ | 13,813 |
| $ | 9,515 |
|
| Net financial earnings | | |
| Net financial earnings (loss) | | |
| Natural Gas Distribution | $ | 86,930 |
| $ | 76,104 |
| $ | 76,287 |
| $ | 84,048 |
| $ | 86,930 |
| $ | 76,104 |
|
| Clean Energy Ventures | 24,873 |
| 28,393 |
| 20,101 |
| 75,849 |
| 24,873 |
| 28,393 |
|
| Energy Services | 18,554 |
| 21,934 |
| 42,122 |
| 60,378 |
| 18,554 |
| 21,934 |
|
| Midstream | 12,857 |
| 9,406 |
| 9,780 |
| 24,367 |
| 12,857 |
| 9,406 |
|
| Subtotal | 143,214 |
| 135,837 |
| 148,290 |
| 244,642 |
| 143,214 |
| 135,837 |
|
| Home Services and Other | 6,811 |
| 2,882 |
| 3,420 |
| (3,829 | ) | 6,811 |
| 2,882 |
|
| Eliminations | (633 | ) | (634 | ) | (207 | ) | (327 | ) | (633 | ) | (634 | ) |
| Total | $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
|
| Capital expenditures | | |
| Natural Gas Distribution | $ | 176,249 |
| $ | 205,133 |
| $ | 168,875 |
| $ | 254,523 |
| $ | 176,249 |
| $ | 205,133 |
|
| Clean Energy Ventures | 149,400 |
| 149,063 |
| 151,002 |
| 123,421 |
| 149,400 |
| 149,063 |
|
| Midstream | | 5,431 |
| — |
| — |
|
| Subtotal | 325,649 |
| 354,196 |
| 319,877 |
| 383,375 |
| 325,649 |
| 354,196 |
|
| Home Services and Other | 2,434 |
| 1,896 |
| 209 |
| 1,213 |
| 2,434 |
| 1,896 |
|
| Total | $ | 328,083 |
| $ | 356,092 |
| $ | 320,086 |
| $ | 384,588 |
| $ | 328,083 |
| $ | 356,092 |
|
| Investments in equity investees | | |
| Midstream | 27,070 |
| 11,176 |
| 5,780 |
| 16,151 |
| 27,070 |
| 11,176 |
|
| Total | $ | 27,070 |
| $ | 11,176 |
| $ | 5,780 |
| $ | 16,151 |
| $ | 27,070 |
| $ | 11,176 |
|
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
The Chief Executive Officer, who uses NFE as a measure of profit or loss in measuring the results of the Company’s reporting segments and operations, is the chief operating decision maker of the Company. A reconciliation of consolidated NFE to consolidated net income is as follows:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Consolidated net financial earnings | $ | 149,392 |
| $ | 138,085 |
| $ | 151,503 |
| $ | 240,486 |
| $ | 149,392 |
| $ | 138,085 |
|
| Less: | | |
| Unrealized (gain) loss on derivative instruments and related transactions | (11,241 | ) | 46,883 |
| (38,681 | ) | |
| Unrealized loss (gain) on derivative instruments and related transactions | | 26,770 |
| (11,241 | ) | 46,883 |
|
| Tax effect | 4,062 |
| (17,018 | ) | 14,391 |
| (4,512 | ) | 4,062 |
| (17,018 | ) |
| Effects of economic hedging related to natural gas inventory | 38,470 |
| (36,816 | ) | (8,225 | ) | (22,570 | ) | 38,470 |
| (36,816 | ) |
| Tax effect | (13,964 | ) | 13,364 |
| 3,058 |
| 7,362 |
| (13,964 | ) | 13,364 |
|
| Consolidated net income | $ | 132,065 |
| $ | 131,672 |
| $ | 180,960 |
| $ | 233,436 |
| $ | 132,065 |
| $ | 131,672 |
|
The Company uses derivative instruments as economic hedges of purchases and sales of physical 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 gas related to physical gas flow isare recognized when the gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical gas flows. Timing differences occur in two ways:
Unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical 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 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 gas, SRECs and foreign currency contracts. Consequently, to reconcile between net income and NFE, current periodcurrent-period unrealized gains and losses on the derivatives are excluded from NFE as a reconciling item. Additionally, realized derivative gains and losses are also included in current periodcurrent-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 gas flows. Included in the tax effects are current and deferred income tax expense corresponding with the non-GAAP measure. Also included in the tax effects during fiscal 2018, are the impacts of the Tax Act and resulting revaluation of the deferred income taxes that arose from derivative and hedging activity as measured under NFE. The revaluation caused the effective tax rate on reconciling items to differ from the statutory rate in effect for the year. The Company also calculates a quarterly tax adjustment based on an estimated annual effective tax rate for NFE purposes.
The Company’s assets for the various reporting segments and business operations are detailed below:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| Assets at end of period: | | |
| Natural Gas Distribution | $ | 2,519,578 |
| $ | 2,517,401 |
| $ | 2,305,293 |
| $ | 2,663,054 |
| $ | 2,519,578 |
| $ | 2,517,401 |
|
Clean Energy Ventures | 771,340 |
| 665,696 |
| 504,885 |
| 865,018 |
| 771,340 |
| 665,696 |
|
| Energy Services | 398,277 |
| 327,626 |
| 260,021 |
| 396,852 |
| 398,277 |
| 327,626 |
|
| Midstream | 232,806 |
| 186,259 |
| 182,007 |
| 242,069 |
| 232,806 |
| 186,259 |
|
| Subtotal | 3,922,001 |
| 3,696,982 |
| 3,252,206 |
| 4,166,993 |
| 3,922,001 |
| 3,696,982 |
|
| Home Services and Other | 114,801 |
| 109,487 |
| 88,880 |
| 114,732 |
| 114,801 |
| 109,487 |
|
Intercompany assets (1)(2) | (108,295 | ) | (87,899 | ) | (56,729 | ) | (138,061 | ) | (108,295 | ) | (87,899 | ) |
| Total | $ | 3,928,507 |
| $ | 3,718,570 |
| $ | 3,284,357 |
| $ | 4,143,664 |
| $ | 3,928,507 |
| $ | 3,718,570 |
|
| |
| (1) | Includes assets held for sale of $206.9 million for September 30, 2018. |
| |
| (2) | Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation. |
16.15. RELATED PARTY TRANSACTIONS
In JanuaryEffective April 1, 2010, NJNG entered into a 10-year agreement effective April 1, 2010, for 3 Bcf of firm storage capacity with Steckman Ridge. Under the terms of the agreement, NJNG incurs demand fees, at market rates, of approximately $9.3 million annually, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG’s BGSS mechanism and are included in regulatory assets.
Energy Services may periodically enter into storage or park and loan agreements with its affiliated FERC-regulated natural gas storage facility, Steckman Ridge. As of September 30, 2017, Energy Services has entered into storage and park and loan transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2020.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
Energy Services may periodically enter into storage or park and loan agreements with its affiliated FERC-jurisdictional natural gas storage facility, Steckman Ridge. As of September 30, 2018, Energy Services has entered into transactions with Steckman Ridge for varying terms, all of which expire by October 31, 2020.
Demand fees, net of eliminations, associated with Steckman Ridge during the fiscal years ended September 30, are as follows:
| | | (Thousands) | 2017 | 2016 | 2015 | 2018 | 2017 | 2016 |
| NJNG | $ | 5,590 |
| $ | 5,562 |
| $ | 5,700 |
| |
| Natural Gas Distribution | | $ | 5,730 |
| $ | 5,590 |
| $ | 5,562 |
|
| Energy Services | 2,750 |
| 2,789 |
| 1,957 |
| 2,775 |
| 2,750 |
| 2,789 |
|
| Total | $ | 8,340 |
| $ | 8,351 |
| $ | 7,657 |
| $ | 8,505 |
| $ | 8,340 |
| $ | 8,351 |
|
The following table summarizes demand fees payable to Steckman Ridge as of September 30:
| | | (Thousands) | 2017 | 2016 | 2018 | 2017 |
| NJNG | $ | 775 |
| $ | 775 |
| |
| Natural Gas Distribution | | $ | 775 |
| $ | 775 |
|
| Energy Services | 377 |
| 375 |
| 375 |
| 377 |
|
| Total | $ | 1,152 |
| $ | 1,150 |
| $ | 1,150 |
| $ | 1,152 |
|
NJNG and Energy Services have entered into various asset management agreements, the effects of which are eliminated in consolidation. Under the terms of these agreements, NJNG releases certain transportation and storage contracts to Energy Services. NJNG retains the right to purchase market pricedmarket-priced gas or fixed pricefixed-price storage gas from Energy Services. As of September 30, 2017,2018, NJNG and Energy Services had four asset management agreements with expiration dates ranging from OctoberMarch 31, 20172019 through October 31, 2020.2021.
NJNG has entered into a 15-year transportation precedent agreement for committed capacity of 180,000 Dths per day with PennEast, to commence when in service.
17. SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)16. ACQUISITION
A summary of financial data for each quarter of fiscal 2017 and 2016 follows. Due to the seasonal nature of the Company’s businesses, quarterly amounts vary significantly during the fiscal year. In the opinion of management, the information furnished reflects all adjustments necessary for a fair presentation of the results of the interim periods.
|
| | | | | | | | | | | | |
| | First | Second | Third | Fourth |
| (Thousands, except per share data) | Quarter | Quarter | Quarter | Quarter |
| 2017 | | | | |
| Operating revenues | $ | 541,028 |
| $ | 733,546 |
| $ | 457,523 |
| $ | 536,520 |
|
| Operating income (loss) | $ | 41,475 |
| $ | 139,653 |
| $ | 17,967 |
| $ | (32,051 | ) |
| Net income (loss) | $ | 34,929 |
| $ | 114,702 |
| $ | 18,957 |
| $ | (36,523 | ) |
Earnings (loss) per share (1) | | | | |
| Basic | $0.41 | $1.33 | $0.22 | $(0.42) |
| Diluted | $0.40 | $1.32 | $0.22 | $(0.42) |
| 2016 |
|
|
|
|
| Operating revenues | $ | 444,258 |
| $ | 574,193 |
| $ | 393,213 |
| $ | 469,241 |
|
| Operating income (loss) | $ | 59,451 |
| $ | 93,933 |
| $ | (28,329 | ) | $ | 42,480 |
|
| Net income (loss) | $ | 50,281 |
| $ | 73,354 |
| $ | (17,363 | ) | $ | 25,400 |
|
Earnings (loss) per share (1) | | | | |
| Basic | $0.59 | $0.85 | $(0.20) | $0.30 |
| Diluted | $0.58 | $0.84 | $(0.20) | $0.29 |
| |
(1) | The sum of quarterly amounts may not equal the annual amounts due to rounding. |
18. SUBSEQUENT EVENTS
Acquisition
On October 27, 2017, Adelphia, an indirect wholly owned subsidiary of NJR, entered into a Purchase and Sale Agreement with Talen pursuant to which Adelphia will acquire all of Talen’s membership interests in IEC for a base purchase price of $166 million. which includes a $10 million initial payment. As additional consideration, Adelphia will pay Talen specified amounts of up to $23 million contingent upon the achievement of certain regulatory approvals and binding natural gas capacity commitments.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
commitments, which have not been received as of September 30, 2018. On November 7, 2017, the Company made an initial payment of $10 million towards the base purchase price, which is included in other noncurrent assets on the Consolidated Balance Sheets.
IEC owns an existing 84-mile pipeline in southeastern Pennsylvania. The transaction is expected to close following receipt of necessary permits and regulatory actions including those from the FERC and the Pennsylvania Public Utility Commission. Upon the closing, of the transactions contemplated by the purchase and sale agreement, Adelphia will acquire IEC and, with it, IEC’s existing pipeline, related assets and rights of way. Adelphia has also agreed to provide firm natural gas transportation service for ten years following the closing to two power generators owned by affiliates of Talen that are currently served by IEC.
17. DISPOSITIONS
Energy Services
On February 28, 2018, NJR sold all of the issued and outstanding shares of capital stock of NJRRS, which was a component of the Energy Services segment. The Company received $9.5 million in cash and a natural gas swap contract with a fair value of $14.6 million, which was recorded in Derivatives, at fair value on the Consolidated Balance Sheets. The sale generated a pre-tax gain of $3.7 million, which was recognized as a reduction to O&M on the Consolidated Statements of Operations.
Clean Energy Ventures
On June 1, 2018, Clean Energy Ventures completed the sale of its membership interest in its 9.7 MW wind farm in Two Dot, Montana to NorthWestern Energy for a total purchase price of $18.5 million. The transaction generated a pre-tax gain of approximately $951,000, which is recognized as a reduction to O&M on the Consolidated Statements of Operations.
New Jersey Resources Corporation
Part II
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (Continued)
18. SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)
A summary of financial data for each quarter of fiscal 2018 and 2017 follows. Due to the seasonal nature of the Company’s businesses, quarterly amounts vary significantly during the fiscal year. In the opinion of management, the information furnished reflects all adjustments necessary for a fair presentation of the results of the interim periods.
|
| | | | | | | | | | | | |
| | First | Second | Third | Fourth |
| (Thousands, except per share data) | Quarter | Quarter | Quarter | Quarter |
| 2018 | | | | |
| Operating revenues | $ | 705,305 |
| $ | 1,019,043 |
| $ | 543,435 |
| $ | 647,326 |
|
| Operating income (loss) | $ | 75,245 |
| $ | 177,792 |
| $ | (37,666 | ) | $ | (19,295 | ) |
| Net income (loss) | $ | 123,699 |
| $ | 140,266 |
| $ | (14,274 | ) | $ | (16,255 | ) |
Earnings (loss) per share (1) | | | | |
| Basic | $1.42 | $1.60 | $(0.16) | $(0.18) |
| Diluted | $1.42 | $1.59 | $(0.16) | $(0.18) |
| 2017 |
|
|
|
|
| Operating revenues | $ | 541,028 |
| $ | 733,546 |
| $ | 457,523 |
| $ | 536,520 |
|
| Operating income (loss) | $ | 41,475 |
| $ | 139,653 |
| $ | 17,967 |
| $ | (32,051 | ) |
| Net income (loss) | $ | 34,929 |
| $ | 114,702 |
| $ | 18,957 |
| $ | (36,523 | ) |
Earnings (loss) per share (1) | | | | |
| Basic | $0.41 | $1.33 | $0.22 | $(0.42) |
| Diluted | $0.40 | $1.32 | $0.22 | $(0.42) |
| |
| (1) | The sum of quarterly amounts may not equal the annual amounts due to rounding. |
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
None
ITEM 9A. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
Under the supervision and with the participation of the Company’s management, including the principal executive officer and principal financial officer, the Company conducted an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act), as of the end of the period covered by this report. Based on this evaluation, the Company’s principal executive officer and principal financial officer concluded that, as of end of the period covered by this report, the Company’s disclosure controls and procedures are effective to ensure that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to the Company’s management, including its principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.
Management’s Annual Report on Internal Control over Financial Reporting
The report of management required under this Item 9A is contained in Item 8 of this Form 10-K under the caption Management’s Report on Internal Control over Financial Reporting.
Attestation Report of Registered Public Accounting Firm
The attestation report required under this Item 9A is contained in Item 8 of this 10-K under the caption Report of Independent Registered Public Accounting Firm.
Changes in Internal Control over Financial Reporting
There has been no change in internal control over financial reporting (as such term is defined in Exchange Act Rule 13a-15(f)) that occurred during the quarter ended September 30, 2017,2018, that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting, except for changes implemented related to non-recurring transaction controls for business combinations and controls related to customer billing for NJRRS. These changes were implemented to enhance our internal control over financial reporting and not in response to any finding of a significant deficiency or a material weakness.
reporting.
ITEM 9B. OTHER INFORMATION
None
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 20182019 Annual Meeting of Shareowners, which will be filed with the SEC pursuant to Regulation 14A within 120 days after September 30, 20172018. The information regarding executive officers is included in this report following as Item 4A under the caption Executive Officers of the Company and incorporated herein by reference.
The Board of Directors has adopted the Code of Conduct, a code for all directors, officers and employees, as required by the New York Stock Exchange rules, and governing the chief executive officer and senior financial officers, in compliance with Sarbanes-Oxley and SEC regulations. Copies of the Code of Conduct are available free of charge on the Company’s website at http://investor.njresources.com under the caption Corporate Governance. A printed copy of the Code of Conduct is available free of charge to any shareowner who requests it by contacting the Corporate Secretary at 1415 Wyckoff Road, Wall, New Jersey 07719. The Company will disclose any amendments to, or waivers from, a provision of the Code of Conduct that applies to the principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions that relate to any element of the Code of Conduct as defined in Item 406 of Regulation S-K by posting such information on the Company’s website.
ITEM 11. EXECUTIVE COMPENSATION
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND
RELATED STOCKHOLDER MATTERS
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
Information required by this Item is incorporated by reference from the Registrant’s Proxy Statement.
New Jersey Resources Corporation
Part IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
|
| | |
| (a) 1. Financial Statements. |
| | | |
All Financial Statements of the Registrant are filed as part of this report and included in Item 8 of Part II of this Form 10-K. |
| | | |
|
| | | |
| | |
New Jersey Resources Corporation
Part IV
INDEX TO FINANCIAL STATEMENT SCHEDULES
|
| | |
| | | Page |
| | Schedule II - Valuation and qualifying accounts and reserves for each of the three years in the period ended September 30, 20172018 | |
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.
New Jersey Resources Corporation
Part IV
SCHEDULE II
VALUATION AND QUALIFYING ACCOUNTS
YEARS ENDED SEPTEMBER 30, 2017,2018, 20162017 and 20152016
| | | (Thousands) | | ADDITIONS | | | | ADDITIONS | | |
| CLASSIFICATION | BEGINNING BALANCE | CHARGED TO EXPENSE | OTHER (1) | ENDING BALANCE | BEGINNING BALANCE | CHARGED TO EXPENSE | OTHER (1) | ENDING BALANCE |
| 2018 | | | | |
| Allowance for doubtful accounts | | $ | 5,181 |
| 2,579 |
| (2,056 | ) | $ | 5,704 |
|
| 2017 | | | | | | |
| Allowance for doubtful accounts | $ | 4,865 |
| 2,023 |
| (1,707 | ) | $ | 5,181 |
| $ | 4,865 |
| 2,023 |
| (1,707 | ) | $ | 5,181 |
|
| 2016 | | | | | | |
| Allowance for doubtful accounts | $ | 5,189 |
| 1,616 |
| (1,940 | ) | $ | 4,865 |
| $ | 5,189 |
| 1,616 |
| (1,940 | ) | $ | 4,865 |
|
| 2015 | | | | |
| Allowance for doubtful accounts | $ | 5,357 |
| 2,859 |
| (3,027 | ) | $ | 5,189 |
| |
| |
| (1) | Uncollectible accounts written off, less recoveries and adjustments. |
New Jersey Resources Corporation
Part IV
EXHIBIT INDEX
|
| |
Exhibit Number | Exhibit Description |
| | |
| 2.1* | |
| | |
| 3.1 | |
| | |
| 3.2 | |
| | |
| 4.1 | |
| | |
| 4.2 | |
| | |
| 4.2(a) | |
| | |
| 4.2(b) | |
| | |
| 4.3 | $250,000,000 Credit Agreement dated as of May 15, 2014, by and among New Jersey Natural Gas Company, the Lenders party thereto, PNC Bank, National Association, as Administrative Agent, Wells Fargo Bank, National Association, as Syndication Agent, U.S. Bank National Association, TD Bank, N.A., and Santander Bank, N.A., as Documentation Agents, and PNC Capital Markets LLC and Wells Fargo Securities, LLC, as Joint Lead Arrangers (incorporated by reference to Exhibit 4.3 to the Quarterly Report on Form 10-Q for the quarter ended June 30, 2014, as filed on August 4, 2014) |
| | |
| 4.4 | $425,000,000 Amended and Restated Credit Agreement dated as of September 28, 2015, by and among the Company, the guarantors thereto, the lenders party thereto, PNC Bank, National Association, as Administrative Agent, JPMorgan Chase Bank, N.A. and Wells Fargo Bank, National Association, as Syndication Agents, Bank of America, N.A., TD Bank, N.A. and U.S. Bank National Association, as Documentation Agents, and PNC Capital Markets LLC, J.P. Morgan Securities LLC and Wells Fargo Securities, LLC, as Joint Lead Arrangers (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K as filed on October 2, 2015) |
| | |
| 4.5 | |
| | |
| 4.5(a) | |
| | |
| 4.5(b) | |
| | |
| 4.6 | |
| | |
| 4.6(a) | |
| | |
| 4.7 | |
| |
New Jersey Resources Corporation
Part IV
|
| |
Exhibit
Number
| Exhibit Description |
| |
4.7(a) | |
| |
4.8 | |
| |
4.8(a) | |
| |
4.9 | |
| | |
New Jersey Resources Corporation
Part IV
4.10 |
| |
Exhibit Number | Exhibit Description |
| |
| 4.8 | |
| | |
4.114.9 | |
| | |
4.124.10 | |
| | |
4.134.11 | |
| | |
4.144.12 | |
| | |
4.154.13 | |
| | |
4.164.15 | $100,000,000 Credit125,000,000 Note Purchase Agreement, dated as of August 18, 2017, betweenMay 11, 2018, by and among New Jersey Resources CorporationNatural Gas Company and U.S. Bank National Association, as Agentthe Purchasers party thereto (incorporated by reference to Exhibit 10.14.1 to the Current Report on Form 8-K, as filed on August 18, 2017May 11, 2018) |
| |
| 4.16 | |
| |
| 4.17 | |
| | |
| 10.1* | |
| | |
| 10.2(a)* | |
| | |
| 10.2(b)* | |
| | |
| 10.3 | |
| | |
| 10.4 | |
| | |
New Jersey Resources Corporation
Part IV
|
| |
Exhibit
Number
| Exhibit Description |
| |
| 10.5* | |
| |
10.5(a)* | |
| |
10.7* | |
| | |
10.8*10.6* | |
New Jersey Resources Corporation
Part IV
| |
10.9* | |
2007 Stock Award and Incentive Plan Form of Performance Shares Agreement (TSR) (incorporated by reference to ExhibitNumber | Exhibit 10.1 to the Current Report on Form 8-K, as filed on December 23, 2014)Description |
| | |
10.10*10.7* | |
| | |
10.11*10.8* | |
| | |
10.12*10.9* | |
| | |
10.13*10.10* | |
| | |
10.14*10.11* | |
| | |
10.15*10.12* | |
| | |
10.16*10.13* | |
| | |
10.17*10.14* | |
| | |
10.18*
10.15* | |
| | |
10.19*10.16* | |
| | |
10.20*10.17* | |
| |
| 10.18* | |
| | |
10.21+*10.19* | |
| | |
10.22*10.20* | |
| | |
10.23*10.21* | |
| | |
10.24*10.22* | |
| | |
10.25*10.23* | |
| | |
10.26*10.24* | |
| | |
New Jersey Resources Corporation
Part IV
|
| |
Exhibit
Number
| Exhibit Description |
| |
10.27+10.24(a)*+ | |
| | |
10.2810.25 | |
| | |
New Jersey Resources Corporation
Part IV
10.29 |
| |
Exhibit Number | Exhibit Description |
| |
| 10.26 | |
| |
| 10.27 | First Amendment to Amended and Restated Credit Agreement, dated as of June 25, 2018, by and among New Jersey Resources Corporation and the Guarantors party thereto, the Lenders party thereto and PNC Bank, National Association, in its capacity as administrative agent for the Lenders (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K, as filed on June 26, 2018) |
| |
| 10.28 | First Amendment to Amended and Restated Credit Agreement, dated as of July 17, 2018, by and among New Jersey Resources Corporation and the guarantors party thereto, the lenders party thereto and U.S. Bank National Association, in its capacity as administrative agent for the lenders (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K, as filed on July 19, 2018) |
| | |
| 21.1+ | |
| | |
| 23.1+ | |
| | |
| 31.1+ | |
| | |
| 31.2+ | |
| | |
| 32.1+ † | |
| | |
| 32.2+ † | |
| | |
| 99.1 | |
| |
| 101+ | Interactive Data File {Annual Report on Form 10-K, for the fiscal year ended September 30, 2017,2018, furnished in XBRL (eXtensible Business Reporting Language)} |
| |
| * | 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 Securities Exchange Act of 1934, as amended. |
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.
|
| | |
| | | NEW JERSEY RESOURCES CORPORATION |
| | | (Registrant) |
| | | |
| Date: | November 21, 201720, 2018 | By:/s/ Patrick Migliaccio |
| | | Patrick Migliaccio |
| | | Senior Vice President and |
| | | Chief Financial Officer |
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant in the capacities and on the dates indicated:
|
| | | |
November 21, 201720, 2018 | /s/ Laurence M. Downes | November 21, 201720, 2018 | /s/ Patrick J. Migliaccio |
| | Laurence M. Downes Chairman President and Chief Executive Officer Director (Principal Executive Officer) | | Patrick J. Migliaccio
Senior Vice President and
Chief Financial Officer
(Principal Financial and Accounting Officer) |
| | | | |
November 21, 201720, 2018 | /s/ Maureen A. Borkowski | November 21, 201720, 2018 | /s/ Thomas C. O'ConnorJ. Terry Strange |
| | Maureen A. Borkowski Director | | Thomas C. O'Connor
J. Terry Strange
Director |
| | | | |
November 21, 2017 | /s/ Lawrence R. Codey | November 21, 2017 | /s/ J. Terry Strange |
| Lawrence R. Codey
Director | | J. Terry Strange
Director
|
| | | |
November 21, 201720, 2018 | /s/ Donald L. Correll | November 21, 201720, 2018 | /s/ Sharon C. Taylor |
| | Donald L. Correll
Director | | Sharon C. Taylor
Director
|
| | | | |
November 21, 201720, 2018 | /s/ Robert B. Evans | November 21, 201720, 2018 | /s/ David A. Trice |
| | Robert B. Evans
Director | | David A. Trice
Director |
| | | |
| November 20, 2018 | /s/ M. William Howard, Jr. | November 20, 2018 | /s/ Stephen D. Westhoven |
| M. William Howard, Jr.
Director | | Stephen D. Westhoven President and Chief Operating Officer
Director |
| | | | |
November 21, 201720, 2018 | /s/ Jane M. William Howard, Jr.Kenny | November 21, 201720, 2018 | /s/ George R. Zoffinger |
| | Jane M. William Howard, Jr.Kenny
Director | | George R. Zoffinger
Director
|
| | | | |
November 21, 201720, 2018 | /s/ Jane M. KennyThomas C. O’Connor | | |
| | Jane M. KennyThomas C. O’Connor
Director | | |
