For the fiscal year ended December 31, 2018
| o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
| For the transition period from ____________to ______________. | |
Commission File Number | Exact name of registrant as specified in its charter and principal office address and telephone number | State of Incorporation | I.R.S. Employer Identification No. | Name of exchange on which registered | Securities registered pursuant to Section 12(b) of the Act: | Securities registered pursuant to Section 12(g) of the Act: |
| 1-6364 | South Jersey Industries, Inc. 1 South Jersey Plaza Folsom, NJ 08037 (609) 561-9000 | New Jersey | 22-1901645 | New York Stock Exchange | Common Stock - $1.25 par value per share (Title of each class) | None |
| 000-22211 | South Jersey Gas Company 1 South Jersey Plaza Folsom, NJ 08037 (609) 561-9000 | New Jersey | 21-0398330 | |||
| None | ||||||
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act:
South Jersey Industries, Inc.: Yes x No o
South Jersey Gas Company: Yes oNo x
Indicate by check mark if theeach registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Act: Yes oNo x
Indicate by check mark whether theeach registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that theeach registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes xNo o
Indicate by check mark whether theeach 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 theeach registrant was required to submit and post such files). Yes x No o
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of 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.
South Jersey Industries, Inc.: o
South Jersey Gas Company: x
Indicate by check mark whether theeach registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.filer, smaller reporting company, or an emerging growth company. See definitionthe definitions of “accelerated filer” and “large accelerated filer”filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one):
| South Jersey Industries, Inc.: | ||
Large accelerated filer x | Accelerated filer o | Non-accelerated filer o |
Smaller reporting company o | Emerging growth company o | |
| South Jersey Gas Company: | ||
Large accelerated filer o | Accelerated filer o | |
Non-accelerated filer x | ||
Smaller reporting company o | Emerging growth company o | |
Indicate by check mark whether any of the registrant isregistrants are a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes oNo x
Documents Incorporated by Reference: None
In Part III of Form 10-K: Portions of South Jersey Industries, Inc.'s definitive proxy statement for its 2019 annual meeting of shareholders to be filed with the Securities and Exchange Commission are incorporated by reference into Part III of this Form 10-K.
TABLE OF CONTENTS
| Page No. | ||
| PART I | ||
| Item 4A. | ||
| PART II | ||
| South Jersey Industries, Inc. | ||
| South Jersey Gas Company | ||
| Item 9. | ||
| PART III | ||
| PART IV | ||
GLOSSARY OF TERMS AND ABBREVIATIONS
| ABO | Accumulated Benefit Obligation |
| ACB | ACB Energy Partners, LLC |
| ACLE | AC Landfill Energy, LLC |
| Acquisition | The Company's acquisition of Elizabethtown Gas Company and Elkton Gas Company effective July 1, 2018, from Pivotal Utility Holdings, Inc., a subsidiary of Southern Company Gas |
| AFUDC | Allowance for Funds During Construction |
| AIRP | Accelerated Infrastructure Replacement Program |
| AMA | Asset Management Agreement |
| AOCL | Accumulated Other Comprehensive Loss |
| ARO | Asset Retirement Obligation |
| ASC | Accounting Standards Codification |
| ASU | Accounting Standards Update |
| Bcf | One billion cubic feet |
| BCLE | BC Landfill Energy, LLC |
| BGSS | Basic Gas Supply Service |
| BPA | Bond Purchase Agreement |
| BPU | New Jersey Board of Public Utilities |
| CBA | Collective Bargaining Agreement |
| CEGR | Compounded Earnings Annual Growth Rate |
| CIP | Conservation Incentive Program |
| CLEP | Clean Energy Program |
| CODM | Chief Operating Decision Maker |
| Columbia | Columbia Gas Transmission, LLC |
| DCF | Discounted Cash Flow |
| DOJ | Department of Justice |
| Dominion | Dominion Transmission, Inc. |
| DPA | Deferred Payment Arrangements |
| DRP | Dividend Reinvestment Plan |
| dt | Decatherm |
| dts/d | Decatherms per day |
| EEP | Energy Efficiency Program |
| EET | Energy Efficiency Tracker |
| EGR | Earnings Growth Rate |
| ELK | Elkton Gas Company |
| EMI | Energy & Minerals, Inc. |
| EnerConnex | EnerConnex, LLC |
| Energenic | Energenic US, LLC |
| EnergyMark | EnergyMark, LLC |
| EPS | Earnings Per Share |
| ERIP | Early Retirement Incentive Program |
| ERISA | Employee Retirement Income Security Act of 1974 |
| ETG | Elizabethtown Gas Company |
| F | Fahrenheit |
| FASB | Financial Accounting Standards Board |
| FERC | Federal Energy Regulatory Commission |
| FSS | Federal Supply Schedule |
| FT | Firm Transportation |
| GAAP | Generally Accepted Accounting Principles for financial reporting in the United States |
| Gulf South | Gulf South Pipeline |
| IAM | International Association of Machinists and Aerospace Workers |
| IBEW | International Brotherhood of Electrical Workers |
| IIP | Infrastructure Investment Programs |
| IIT | Infrastructure Investment Recovery |
| LFGTE | Landfill Gas-to-Energy |
| LIBOR | London Interbank Offer Rate |
| LMP | Locational Marginal Price |
| LNG | Liquefied Natural Gas |
| Marina | Marina Energy, LLC |
| Mcf | One thousand cubic feet |
| MCS | MCS Energy Partners, LLC |
| MDQ | Maximum Daily Quantities |
| MDWQ | Maximum Daily Withdrawal Quantity |
| Midstream | SJI Midstream, LLC |
| Millennium | Millennium Account Services, LLC |
| MPSC | Maryland Public Service Commission |
| MMdts | One million decatherms |
| MMmwh | One million megawatt hours |
| Morie | The Morie Company, Inc. |
| MTM | Mark-to-market |
| MTN | Medium Term Notes |
| MW | Megawatts |
| Mwh | Megawatt-hours |
| National Fuel | National Fuel Gas Supply Corporation |
| NAV | Net Asset Value |
| NBS | NBS Energy Partners, LLC |
| Non-GAAP | The financial measures that are not prepared in accordance with U.S. GAAP |
| NPA | Note Purchase Agreement |
| NJCEP | New Jersey Clean Energy Program |
| NJDEP | New Jersey Department of Environmental Protection |
| NJEDA | New Jersey Economic Development Authority |
| NOL | Net Operating Loss |
| OPEB | Other Postretirement Benefits |
| OSMC | On-System Margin Sharing Credit |
| PennEast | PennEast Pipeline, LLC |
| Potato Creek | Potato Creek, LLC |
| PBO | Projected Benefit Obligation |
| RAC | Remediation Adjustment Clause |
| RAM | Rate Adjustment Mechanism |
| ROE | Return on Equity |
| SAB | Staff Accounting Bulletin |
| Savings Plan | Employees' Retirement Savings Plan |
| SBC | Societal Benefits Clause |
| SBS | SBS Energy Partners, LLC |
| SCLE | SC Landfill Energy, LLC |
| SEC | Securities and Exchange Commission |
| SERP | Supplemental Executive Retirement Plan |
| SHARP | Storm Hardening and Reliability Program |
| SJE | South Jersey Energy Company |
| SJES | South Jersey Energy Solutions, LLC |
| SJESP | South Jersey Energy Service Plus, LLC |
| SJEX | South Jersey Exploration, LLC |
| SJF | South Jersey Fuel, Inc. |
| SJG | South Jersey Gas Company |
| SJI | South Jersey Industries, Inc., or the Company |
| SJIU | SJI Utilities, Inc. |
| SJRG | South Jersey Resources Group, LLC |
| SOA | Society of Actuaries |
| SRECs | Solar Renewable Energy Credits |
| SXLE | SX Landfill Energy, LLC |
| Tax Reform | Tax Cuts and Jobs Act which was enacted into law on December 22, 2017 |
| Tennessee | Tennessee Gas Pipeline Company, L.L.C. |
| Tetco | Texas Eastern Transmission Corp |
| TIC | Transportation Initiation Clause |
| Transco | Transcontinental Gas Pipe Line Company, LLC |
| TSA | Transition Services Agreement |
| TSR | Total Shareholder Return |
| USF | Statewide Universal Service Fund |
| Utilities | Represents SJI's three utility businesses: SJG, ETG, and ELK |
| UWUA | United Workers Union of America |
| VIE | Variable Interest Entities |
| WNC | Weather Normalization Clause |
INTRODUCTION
FILING FORMAT
This Annual Report on Form 10-K is a combined report being filed separately by two registrants: South Jersey Industries, Inc. (SJI) and South Jersey Gas Company (SJG). Information relating to SJI or any of its subsidiaries, other than SJG, is filed by SJI on its own behalf. SJG is only responsible for information about itself.
Except where the content clearly indicates otherwise, any reference in the report to "SJI," "the Company," "we," "us" or "our" is to SJI and all of its subsidiaries, including SJG, which is a wholly-owned subsidiary of SJI.
Management's Discussion and Analysis of Financial Condition and Results of Operations (Management's Discussion) included under Item 7 is divided into two major sections: SJI and SJG. Financial information in this Annual Report on Form 10-K included in Item 8 includes separate financial statements (i.e., statements of income, statements of comprehensive income, statements of cash flows, balance sheets, and statements of changes in equity and comprehensive income) for SJI and SJG. The Notes to Consolidated Financial Statements are presented on a combined basis for both SJI and SJG.
Forward Looking Statements
Certain statements contained in this Annual Report on Form 10-K may qualify as “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements in this Report other than statements of historical fact, including statements regarding future results of operations or financial position, expected sources of incremental margin, strategy, financing needs, future capital expenditures and the outcome or effect of ongoing litigation, should be considered forward-looking statements made in good faith by South Jersey Gas Company (SJGIndustries (SJI or the Company) and South Jersey Gas Company (SJG), as applicable, and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. When used in this Report, or any other of the Company’s documents, or oral presentations, words such as “anticipate,” “believe,” “estimate,”"estimate," “expect,” “forecast,” “goal,” “intend,” “objective,” “plan,” “project,” “seek,” “strategy,” "target," "will" and similar expressions are intended to identify forward-looking statements. These forward-looking statements are based on the beliefs and assumptions of management at the time that these statements were made and are inherently uncertain. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed or implied in the forward-looking statements. These risks and uncertainties include, but are not limited to the risks set forth under “Risk Factors” in Part I, Item 1A of this Report and elsewhere throughout this Report. These cautionary statements should not be construed by you to be exhaustive and they are made only as of the date of this Report. While the Company believes these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. Further, neither SJI nor SJG undertakes no obligation to update or revise any of its forward-looking statements whether as a result of new information, future events or otherwise.
Available Information
South Jersey Industries, Inc.
Part I
PART I
Item 1. Business
Description of Business
South Jersey Industries, Inc. (SJI or the Company), a New Jersey corporation, was formed in 1969 for the purpose of owning and holding all of the outstanding common stock of South Jersey Gas Company, (SJG) is a regulated natural gas utility.public utility, and acquiring and developing non-utility lines of business.
SJI provides a variety of energy-related products and services, primarily through the following wholly-owned subsidiaries:
| ▪ | SJIU is a holding company that owns SJG, and as of July 1, 2018, ETG and ELK (see "Acquisition" below). |
| * | SJG is a regulated natural gas utility which distributes natural gas in the seven southernmost counties of New Jersey. |
| * | ETG is a regulated natural gas utility which distributes natural gas in seven counties in northern and central New Jersey. |
| * | ELK is a regulated natural gas utility which distributes natural gas in northern Maryland. |
SJE acquires and markets electricity to retail end users. SJE previously acquired and marketed natural gas and provided total energy management services to commercial, industrial and residential customers. In November 2018, the Company sold SJE's retail gas businesses.
SJRG markets natural gas storage, commodity and transportation assets along with fuel management services on a wholesale basis in the mid-Atlantic, Appalachian and southern states.
SJEX owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.
Marina develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include:
ACB, which owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey.
ACLE, BCLE, SCLE and SXLE, which owns and operates landfill gas-to-energy production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.
MCS, NBS and SBS, which owned and operated solar-generation sites located in New Jersey. These entities were sold in October 2018.
SJESP receives commissions on service contracts from a third party.
Midstream invests in infrastructure and other midstream projects, including a current project to build an approximately 118-mile natural gas pipeline in Pennsylvania and New Jersey.
On July 1, 2018, SJI, through its wholly-owned subsidiary SJIU, acquired the assets of ETG and ELK from Pivotal Utility Holdings, Inc., a subsidiary of Southern Company Gas (collectively, the "Acquisition"), for total consideration of $1.7 billion. See Note 20 to the consolidated financial statements.
On June 27, 2018, the Company, through Marina, entered into a series of agreements whereby Marina agreed to sell its portfolio of solar energy assets to a third-party buyer. As part of these agreements, Marina has agreed to sell its distributed solar energy projects located across New Jersey, Maryland, Massachusetts and Vermont. As of December 31, 2018, the Company earned cash of $228.1 million related to the closing of these projects, which included selling the wholly-owned subsidiaries MCS, NBS and SBS, along with $62.5 million related to the sale of certain SRECs. The Company currently has projects that have not yet closed and are expected to be sold in 2019. See Note 1 to the consolidated financial statements.
On November 30, 2018, SJI sold the retail gas assets of SJE for total consideration of $15.0 million. As a result of this agreement, SJE no longer acquires, transports or markets natural gas for retail markets.
9
South Jersey Industries, Inc.
Part I
Additional informationInformation on the nature of our business is incorporated by reference to “Management’sSJI's and SJG's businesses can be found in “Management's Discussion and Analysis of Financial Condition and Results of Operations,” “Market Risk” and Note 3 to the financial statements.under Item 7 of this Report.
Financial Information About Reportable Segments
Information on our rates and regulatory affairsregarding Reportable Segments is incorporated by reference to “Management’s Discussion and AnalysisNote 8 of Financial Condition and Resultsthe consolidated financial statements included under Item 8 of Operations,” and Note 3 to the financial statements.this Report.
Sources and Availability of Raw Materials
The Utilities:
Transportation and Storage Agreements
During 2018, SJG, ETG and ELK purchased and had delivered natural gas distribution of 49.1 MMdts, 21.8 MMdts and 0.5 MMdts, respectively (ETG and ELK are for the period July 1 - December 31, 2018 only). These deliveries were for on-system and off-system customers and for injections into storage. SJG's average cost per dt of natural gas purchased and delivered in 2018, 2017 and 2016, including demand charges, was $5.20, $3.75 and $3.40, respectively. The average cost per dt of natural gas purchased and delivered for ETG and ELK for the period July 1 - December 31, 2018 was $4.71 and $6.43, respectively.
SJG has direct connections to the interstate pipeline systems of both Transcontinental Gas Pipe Line Company, LLC (Transco)Transco and Columbia Gas Transmission, LLC (Columbia). During 2016,Columbia. SJG purchased and had delivered approximately 46.5 MMdts of natural gas for distribution to both on-system and off-system customers and for injections into storage. Of this total, 25.1 MMdts were transported on the Transco pipeline system while 21.4 MMdts were transported on the Columbia pipeline system. Moreover, during 2016 third-party suppliers delivered 29.6 MMdts to SJG's system on behalf of end use customers behind our city gate stations. SJG also secures other long-term services from Dominion, Transmission, Inc. (Dominion), a pipeline upstream of the Transco and Columbia systems. Services provided by Dominion are utilized to deliver gas into either the Transco or Columbia systems for ultimate delivery to SJG.
ETG has direct connections to the interstate pipeline systems of Transco, Columbia, Tetco and Tennessee. ETG secures other long-term services from several inter-state pipelines, Dominion, National Fuel and Gulf South that are not directly connected to ETG and are upstream of the Transco and Tetco systems. Services provided by Dominion are utilized to deliver gas into either the Transco or Tetco systems for ultimate delivery to ETG. Services provided by National Fuel and Gulf South are utilized to deliver gas into the Transco system for ultimate delivery to ETG. ETG also secures third-party storage services from Stagecoach Gas Services and Stagecoach Pipeline & Storage Company.
Total transportation under contract at SJG and ETG are 421,980 dts/d and 218,523 dts/d, respectively. These contracts have terms with various ending dates, ranging from March 31, 2019 through March 31, 2029. The Company's intentions are to renew or extend these service agreements before they expire.
Total storage capacity under contract at SJG and ETG is 8.9 MMdts and 13.1 MMdts, respectively, with a total MDWQ of 170,298 dts and 225,343 dts, respectively. These contracts have terms with various ending dates, ranging from March 31, 2019 through September 30, 2029. The Company's intentions are to renew or extend these service agreements before they expire.
ELK has direct connections to the interstate pipeline systems of Eastern Shore Natural Gas, along with firm transportation agreements with Transco and Columbia Gas. The activities of ELK utility operations are immaterial.
Services provided by all of the above-mentioned pipelines are subject to the jurisdiction of the Federal Energy Regulatory Commission (FERC). Unless otherwise indicated, our intentions are to renew or extend these service agreements before they expire.
Gas Supplies
10
South Jersey Industries, Inc.
Part I
On July 1, 2018, ETG and ELK entered into a long-term gas purchase agreementan AMA with a gas producer, the primary term ofSJRG which extends through OctoberMarch 31, 2019. The maximum daily quantities (MDQ) available for purchase under2022. Under this agreement initially start at 6,250 dts/dETG and ratchet upELK released to an MDQSJRG and/or designated SJRG as agent for all firm transportation and storage contracts. SJRG is obligated to provide natural gas supply to meet demand requirements and optimize ETG’s and ELK's portfolio of 25,000 dts/d. Gas purchased from this producer will be sourced in the Appalachian supply areasnatural gas transportation and delivered into the Columbia pipeline system for delivery to SJG.
storage contracts. SJRG pays a fixed fee and shares net margin generated through portfolio optimization.
As part of itsthe gas purchasing strategy, SJG usesthe Utilities use financial contracts to hedge against forward price risk. These contracts are recoverable through SJG’s Basic Gas Supply Servicethe BGSS Clause, (BGSS), subject to the New Jersey Board of Public Utilities (BPU)BPU/MPSC approval.
Supplemental Gas Supplies
SJG operates peaking facilities, whichlocated in McKee City, NJ, where it liquefies, stores and vaporizes LNG for injection into its distribution system. SJG’sSJG's LNG facility has a storage capacity equivalent to 434,300 dts of natural gas and has an installed capacity to vaporize up to 118,250 dts of LNG per day for injection into its distribution system.
ETG operates a peaking facility, located in Elizabeth, NJ, where it stores and vaporizes LNG for injection into its distribution system. ETG's LNG facility has a storage capacity equivalent to 145,000 dts of natural gas and has an installed capacity to vaporize up to 25,000 dts of LNG per day for injection into its distribution system.
Peak-Day Supply
SJG plans for a winter season peak-day demand on the basis of an average daily temperature of 2 degrees Fahrenheit (F).F or 63 Heating Degree Days, while ETG's plans on an average daily temperature of 0 degrees F or 65 Heating Degree Days. Gas demand on such a design day for the 2016-20172018-2019 winter season is estimated to be 512,891566,405 dts for SJG and 445,102 dts for ETG (excluding industrial customers). SJG projects that it hasand ETG project to have adequate supplies and interstate pipeline entitlements to meet its design day requirements. SJG and ETG both experienced itstheir highest peak-day demand for calendar year 2016 of 473,178 dts (including industrial customers)2018 on February 13, while experiencing an average temperature of 20.6 degrees F that day.January 6th.
South Jersey Energy Company
South Jersey Resources Group
Transportation and Storage Agreements
SJRG holds multiple storage service agreements with National Fuel, Transco (for storage service at Transco's WSS facility) and Columbia (for service under Columbia's FSS rate schedule). Total storage capacity under contract is approximately 8.6 MMdts. These contracts have terms with various ending dates, ranging from March 31, 2020 through March 31, 2023. SJRG's intentions are to renew or extend these service agreements before they expire.
Gas Supplies
SJRG has entered into several long-term natural gas purchased and delivered in 2016, 2015, and 2014, including demand charges, was $3.40 per dt, $4.71 per dt, and $6.56 per dt, respectively.supply agreements to purchase 832,500 dts/d, depending upon production levels, for terms ranging from four to ten years at index-based prices.
Patents and Franchises
11
South Jersey Industries, Inc.
Part I
Seasonal Aspects
The Utilities experience seasonal fluctuations in sales when selling natural gas for heating purposes. SJG meets thisThe Utilities meet these seasonal fluctuationfluctuations in demand from its firm customers by buying and storing gas during the summer months, and by drawing from storage and purchasing supplemental supplies during the heating season. As a result of this seasonality, SJG’sthe Utilities' revenues and net income are significantly higher during the first and fourth quarters than during the second and third quarters of the year.
Non-Utility Companies
Among SJI's non-utility activities, wholesale (including fuel supply management) has seasonal patterns similar to the Utilities. Activities such as energy services and energy project development do not follow seasonal patterns. Other activities, such as retail electric marketing, can have seasonal earnings patterns that are different from the Utilities. The first and fourth quarters remain the periods where most of SJI's revenue and net income is produced.
Working Capital Practices
Reference is made to “Liquidity and Capital Resources” included in Item 7, “Management’s“Management's Discussion and Analysis of Financial Condition and Results of Operations,” of this Report.
Customers
No material part of SJG’sthe Company's business is dependent upon a single customer or a few customers, the loss of which would be expected to have a material adverse effect on SJG’s business.the results of operations of SJI on a consolidated basis, or of SJG.
Backlog
Backlog is not material to an understanding of SJG’s business.SJI's business or that of any of its subsidiaries.
Government Contracts
No material portion of SJG’sthe business of SJI or any of its subsidiaries is subject to renegotiation of profits or termination of contracts or subcontracts at the election of any government.
Competition
Information on competition is incorporated by reference tofor SJI and its subsidiaries can be found in Item 7, “Management’s“Management's Discussion and Analysis of Financial Condition and Results of Operations,” of this Report.
Research
During the last three fiscal years, SJG did not engageneither SJI nor any of its subsidiaries engaged in research activities to any material extent.
Environmental Matters
Information on environmental matters for SJI and its subsidiaries can be found in Note 1215 of the consolidated financial statements.statements included under Item 8 of this Report.
12
South Jersey Industries, Inc.
Part I
Employees
Financial Information About Foreign and Domestic Operations and Export Sales
Item 1A. Risk Factors
SJI and its subsidiaries, including SJG, operatesoperate in an environment that involves risks, many of which are beyond our control. The CompanySJI has identified the following risk factors that could cause the Company’sSJI's operating results and financial condition to be materially adversely affected. Security holders should carefully consider these risk factors and should also be aware that this list is not all-inclusive of existing risks. In addition, new risks may emerge at any time, and the CompanySJI cannot predict those risks or the extent to which they may affect the Company’sSJI's businesses or financial performance. To the extent such risk factors may affect SJI's utility businesses, such risk factors may also affect SJG's business or performance.
SJI is a holding company and its assets consist primarily of investments in subsidiaries. Should SJI's subsidiaries be unable to pay dividends or make other payments to SJI for financial, regulatory, legal or other reasons, SJI's ability to pay dividends on its common stock could be limited. SJI's stock price could be adversely affected as a result.
Changes in the regulatory environment or unfavorable rate regulation at the Utilities may have an unfavorable impact on SJG’s financial performance or condition. SJG’s businessSJG and ETG are regulated by the BPU, and ELK is regulated by the New Jersey Board of Public Utilities (BPU) which hasMPSC. These regulatory commissions have authority over many of the activities of the utility business including, but not limited to, the rates itthe Utilities charges to its customers, the amount and type of securities it can issue, the nature of investments it can make, the nature and quality of services it provides, safety standards and other matters. The extent to which the actions of regulatory commissions restrict or delay SJG’sthe Utilities' ability to earn a reasonable rate of return on invested capital and/or fully recover operating costs may adversely affect itsSJI's and SJG's results of operations, financial condition and cash flows.
SJI and SJG may not be able to respond effectively to competition, which may negatively impact SJG’stheir financial performance or condition.Regulatory initiatives may provide or enhance opportunities for competitors that could reduce utility income obtained from existing or prospective customers. Also, competitors in all of SJI's business lines may be able to provide superior or less costly products or services based upon currently available or newly developed technologies.
Warm weather, high commodity costs, or customer conservation initiatives could result in reduced demand for natural gas.some of SJI's and SJG's energy products and services. SJG currently has a conservation incentive program clause that protects its revenues and gross margin against usage that is lower than a set level. ETG has a weather normalization clause which allows ETG to implement surcharges or credits during the months of October through May to compensate for weather-related changes in customer usage from the previous winter period. Should this clausethese clauses be terminated without replacement, lower customer energy utilization levels would likely reduce SJG’sSJI's and SJG's net income. Further, during periods of warmer temperatures, demand and volatility in the natural gas market could decrease, which would negatively impact their financial results.
High natural gas prices could cause more of SJG’s receivables to be uncollectible.Higher levels of uncollectibles from utilityeither residential or commercial customers would negatively impact SJG’snet income and could result in higher working capital requirements.
13
South Jersey Industries, Inc.
Part I
Climate change legislation could impact SJG’sSJI's and SJG's financial performance and condition. Climate change is receiving ever increasing attention from both scientists and legislators. The debate is ongoing as to the extent to which our climate is changing, the potential causes of this change and its future impacts. Some attribute global warming to increased levels of greenhouse gases, which has led to significant legislative and regulatory efforts to limit greenhouse gas emissions. The outcome of federal and state actions to address global climate change could result in a variety of regulatory programs, including additional charges to fund energy efficiency activities or other regulatory actions. These actions could affect the demand for natural gas and electricity, result in increased costs to our business and impact the prices we charge our customers. Because natural gas is a fossil fuel with low carbon content, it is possible that future carbon constraints could create additional demands for natural gas, both for production of electricity and direct use in homes and businesses. Any adoption by federal or state governments mandating a substantial reduction in greenhouse gas emissions could have far-reaching and significant impacts on the energy industry. We cannot predict the potential impact of such laws or regulations on our future consolidated financial condition, results of operations or cash flows.
SJI's wholesale commodity marketing and retail electric businesses are exposed to the risk that counterparties that owe money or energy to SJI will not be able to meet their obligations for operational or financial reasons. SJI could be forced to buy or sell commodity at a loss as a result of such failure. Such a failure, if large enough, could also impact SJI's liquidity.
Increasing interest rates would negatively impact the net income of SJI and SJG. Several of SJI's subsidiaries, including SJG, are capital intensive, resulting in the incurrence of significant amounts of debt financing. Some of the long-term debt of SJI and its subsidiaries is issued at fixed rates or has utilized interest rate swaps to mitigate changes in variable rates. However, long-term debt of SJI and SJG at variable rates, along with all variable rate short-term borrowings, are exposed to the impact of rising interest rates.
The inability to obtain capital, particularly short-term capital from commercial banks, could negatively impact the daily operations and financial performance of SJI and SJG. SJI and SJG use short-term borrowings under committed credit facilities provided by commercial banks to supplement cash provided by operations, to support working capital needs, and to finance capital expenditures, as incurred. SJG also relies upon short-term borrowings issued under a commercial paper program supported by a committed bank credit facility to support working capital needs, and to finance capital expenditures, as incurred. If the customary sources of short-term capital were no longer available due to market conditions, SJI and its subsidiaries may not be able to meet their working capital and capital expenditure requirements and borrowing costs could increase.
A downgrade in either SJI's or SJG's credit ratings could negatively affect our ability to access adequate and cost-effective capital. Our ability to obtain adequate and cost-effective capital depends to a significant degree on our credit ratings, which are greatly influenced by our financial condition and results of operations. If the rating agencies downgrade either SJI's or SJG's credit ratings, particularly below investment grade, our borrowing costs would increase. In addition, we would likely be required to pay higher interest rates in future financings and potential funding sources would likely decrease. To the extent that a decline in SJG's credit rating has a negative effect on SJI, SJI could be required to provide additional support to certain counterparties.
Hedging activities of the Company designed to protect against commodity price or interest rate risk may cause fluctuations in reported financial results and SJI's stock price could be adversely affected as a result. Although SJI enters into various contracts to hedge the value of energy assets, liabilities, firm commitments or forecasted transactions, the timing of the recognition of gains or losses on these economic hedges in accordance with accounting principles generally accepted in the United States of America does not always match up 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.
14
South Jersey Industries, Inc.
Part I
The inability to obtain natural gas or electricity from suppliers would negatively impact the financial performance of SJI and SJG. Several of SJI's subsidiaries, including SJG, have businesses based upon the ability to deliver natural gas or electricity to customers. Disruption in the production or transportation to SJI or SJG from its suppliers could prevent SJI or SJG from completing sales to its customers.
Transporting and storing natural gas involves numerous risks that may result in accidents and other operating risks and costs. SJI's and SJG's gas distribution activities involve a variety of inherent hazards and operating risks, such as leaks, accidents, mechanical problems, natural disasters or terrorist activities which could cause substantial financial losses. In addition, these risks could result in loss of human life, significant damage to property, environmental pollution and impairment of operations, which in turn could lead to substantial losses. In accordance with customary industry practice, SJI and SJG maintain insurance against some, but not all, of these risks and losses. The occurrence of any of these events, even if fully covered by insurance, could adversely affect SJI's or SJG's financial position, results of operations and cash flows.
Adverse results in legal proceedings could be detrimental to the financial condition of SJI or SJG. The outcomes of legalproceedings can be unpredictable and can result in adverse judgments.
Constraints in available pipeline capacity, particularly in the Marcellus Shale producing region, may negatively impact SJI's financial performance. Natural gas production and/or pipeline transportation disruptions in the Marcellus region, where SJI has natural gas receipt requirements, may cause temporary take-away constraints resulting in higher transportation costs and the sale of shale gas at a loss.
SJI's and SJG's business could be adversely impacted by strikes or work stoppages by its unionized employees.employees. The gas utility operations of SJG and ETG are dependent upon employees represented by unions and covered under collective bargaining agreements. A work stoppage could negatively impact operations, which could impact financial results as well as customer relationships.
The risk of terrorism may adversely affect the economy as well as SJI's and SJG's business. An act of terror could result in disruptions of natural gas supplies cause price volatility in the cost of natural gas and overall could cause instability in the financial and capital markets. This could adversely impact the priceSJI's or SJG's ability to deliver products or raise capital and availability of natural gas andcould adversely affect SJG'simpact its results of operationsoperations.
Failure to obtain proper approvals and abilityproperty rights in the PennEast pipeline could hinder SJI's equity investment in the project. Construction, development and operation of energy investments, specifically the PennEast pipeline, are subject to raise capital.federal and state regulatory oversight and require certain property rights from public and private property owners, as well as regulatory approvals, including environmental and other permits and licenses. SJI, as well as our joint venture partners in the PennEast pipeline, may be unable to obtain all such needed property rights, permits and licenses to successfully construct and develop the pipeline, and failing to do so could cause SJI's equity investment in the project to become impaired. Such impairment could have a materially adverse effect on SJI's financial condition and results of operations.
15
South Jersey Industries, Inc.
Part I
Our business could be harmed by cybersecurity threats and related disruptions. We rely extensively on information technology systems to process transactions, transmit and store information and manage our business. Disruption or failure of our information technology systems could shut down our facilities or otherwise harm our ability to safely deliver natural gas to our customers, serve our customers effectively, manage our assets, or otherwise materially disrupt our business. Cyber threats are constantly evolving, increasing the difficulty of detecting and successfully defending against them. SJI and SJG hashave experienced such attacks in the past; however, based on information currently available to SJI and SJG, none have had a material impact on our business, financial condition, results of operations or cash flows. In response, we have invested in expanded cybersecurity systems and procedures designed to safeguard the continuous and uninterrupted performance of our information technology systems and protect against unauthorized access. However, all information technology systems are potentially vulnerable to security threats, including hacking, viruses, other malicious software, and other unlawful attempts to disrupt or gain access to such systems. There is no guarantee that our cybersecurity systems and procedures will prevent or detect the unauthorized access by experienced computer programmers, hackers or others. An attack on or failure of our information technology systems could result in the unauthorized disclosure, theft, misuse or destruction of customer or employee data or business or confidential information, or disrupt the performance of our information technology systems. These events could expose us to potential liability, litigation, governmental inquiries, investigations or regulatory actions, harm our brand and reputation, diminish customer confidence, disrupt operations, and subject us to payment of fines or other penalties, legal claims by our clients and significant remediation costs.
Tax law or regulation changes may negatively impact financial performance. SJI and SJG are subject to taxation by various taxing authorities at the federal, state and local levels. Any future changes in tax laws or regulations, including Tax Reform, or interpretation of such laws or regulations, could have a materially adverse effect on SJI's and SJG's financial condition and results of operations.
The loss of long-tenured employees could negatively impact the daily operations and financial performance of SJI and SJG. In October 2018, the Company announced it will offer an ERIP for eligible non-union employees and officers. Several employees have accepted the ERIP and will be retiring from the Company within 6 to 12 months. The departure of these individuals, who have varying roles and corresponding oversight responsibilities for SJI and SJG, could adversely impact SJI's and SJG's results of operations.
Our stated long-term goals are based on various assumptions and beliefs that may not prove to be accurate, and we may not achieve our stated long-term goals by 2020 or at all. SJI's current long-term goals are to grow Economic Earnings Per Share 6-8% annually while maintaining high quality earnings, a strong balance sheet and a low-to-moderate risk profile. Management established those goals in conjunction with our board of directors based upon a number of different internal and external factors that characterize and influence our current and expected future activities. For example, these long-term goals are based on certain assumptions regarding our participation in a current project to build an approximately 118-mile natural gas pipeline in Pennsylvania and New Jersey. However, construction on this project is not expected to begin until 2019 and is estimated to be completed in late 2020, but may be subject to delay. As a result, no assurance can be given that this project will be completed on time or at all. Also, as noted below, the Acquisition involves risks associated with acquisitions and integrating acquired assets, including the potential exposure to significant liabilities, and the intended benefits of the Acquisition may not be realized. Further, the economy could cause increased customer delinquencies or otherwise negatively affect achievement of our long-term earnings goals. Changes in the New Jersey State administration could lead to unfavorable state and local regulatory changes that could delay approvals, require environmental remediation or capital or other expenditures or otherwise adversely affect our results of operations, financial condition or cash flows. Other factors, assumptions and beliefs of management and our board of directors on which our long-term goals were based may also prove to differ materially from actual future results. Accordingly, we may not achieve our stated long-term goals by 2020 or at all, or our stated long-term goals may be negatively revised as a result of less than expected progress toward achieving these goals, and you are therefore cautioned not to place undue reliance on these goals.
16
South Jersey Industries, Inc.
Part I
The Acquisition involves risks associated with acquisitions and integrating acquired assets, including the potential exposure to significant liabilities. The Acquisition may not achieve its intended results and benefits, including anticipated investment opportunities and earnings growth.
The Acquisition involves risks associated with acquisitions and integrating acquired assets into existing operations, including that:
our senior management's attention may be diverted from the management of daily operations to the integration of the Acquisition;
we could incur significant unknown and contingent liabilities for which we have limited or no contractual remedies or insurance coverage;
the assets to be acquired may not perform as well as we anticipate; and
unexpected costs, delays and challenges may arise in integrating the assets acquired in the Acquisition into our existing operations.
Although we expect that the Acquisition will result in various benefits, including expanding our gas utility rate and customer bases, providing investment opportunities through infrastructure development and enhancing our regulatory relationships within the local communities served, we cannot assure you regarding when or the extent to which we will be able to realize these or other benefits. Achieving the anticipated benefits is subject to a number of uncertainties, including whether the businesses acquired can be operated in the manner we intend and whether our costs to finance the Acquisition will be consistent with our expectations. Events outside of our control, including but not limited to regulatory changes or developments, could also adversely affect our ability to realize the anticipated benefits from the Acquisition. Thus the integration of the ETG and ELK businesses, respectively, may be unpredictable, subject to delays or changed circumstances, and we cannot assure you that the acquired businesses will perform in accordance with our expectations or that our expectations with respect to improving our business risk profile, leveraging existing regulatory relationships or achieving earnings growth as a result of the Acquisition will be achieved. In addition, our anticipated costs to achieve the integration of the acquired businesses may differ significantly from our current estimates. The integration may place an additional burden on our management and internal resources, and the diversion of management’s attention during the integration process could have an adverse effect on our business, financial condition and expected operating results.
We issued additional securities to provide permanent financing for the Acquisition, and, as a result, we are subject to market risks including market demand for our debt and equity securities. We are also seeking to consummate certain asset sales.
In connection with the Acquisition, we have obtained permanent financing which includes common stock and Equity Units, Senior Unsecured Notes, Floating Rate Senior Notes, a Term Loan Facility and a Revolving Credit Agreement.
Among other risks, the increase in our indebtedness may:
make it more difficult for us to repay or refinance our debts as they become due during adverse economic and industry conditions;
limit our flexibility to pursue other strategic opportunities or react to changes in our business and the industries in which we operate and, consequently, place us at a competitive disadvantage to competitors with less debt;
require an increased portion of our cash flows from operations to be used for debt service payments, thereby reducing the availability of cash flows to fund working capital, capital expenditures, dividend payments and other general corporate purposes;
result in a downgrade in the credit rating of our indebtedness, which could limit our ability to borrow additional funds or increase the interest rates applicable to our indebtedness;
result in higher interest expense in the event of increases in market interest rates for both long-term debt as well as short-term commercial paper, bank loans or borrowings under our lines of credit at variable rates;
reduce the amount of credit available to support hedging activities; and
require that additional terms, conditions or covenants be placed on us.
17
South Jersey Industries, Inc.
Part I
Among other risks, the issuance of additional equity by SJI may:
be dilutive to our existing shareholders and earnings per share;
impact our capital structure and cost of the capital;
be adversely impacted by movements in the overall equity markets or the utility or natural gas utility industry sectors of that market, which could impact the offering price of our new equity or necessitate the use of other equity or equity-like instruments such as preferred stock, convertible preferred shares, or convertible debt; and
impact our ability to make our current and future dividend payments.
The Company may not be able to obtain refinancings of short-term debt, causing the ability to pay such debt at maturity to be at risk. As a result of the Acquisition, the Company has $733.9 million of debt coming due within the next twelve months. The plan is to obtain refinancings for most of this debt, with the remainder being paid off through various transactions including the expected sale of non-core assets as noted below. The Company can offer no assurances that these refinancings or sales will be successful.
The agreements to sell certain non-core assets of the Company may not be consummated. An agreement to sell solar assets has been entered into with a third party, with actual sales occurring on a rolling basis as the conditions precedent to the closing of each solar project, including certain regulatory filings and receipt of consents to assignment of project contracts and permits, are satisfied. While certain consents have been received and the sale of certain projects has consummated, we cannot guarantee that all approvals and consents will occur.
Item 1B. Unresolved Staff Comments
None.
Item 2. Properties
The principal property of SJGSJI consists of its gas transmission and distribution systems that include mains, service connections and meters. The transmission facilities carry the gas from the connections with Transco and Columbia to SJG’s distribution systems for delivery to customers. As of December 31, 2016,2018, there were approximately 146.2 miles of mains in the transmission systems and 6,6056,567 miles of mains in the distribution systems.
In 2018, SJG sold 117 acres of deed restricted land in Folsom. Currently, SJG owns 154approximately 44 acres of land in Folsom, New Jersey which is the site of itsSJI's corporate headquarters. Approximately 14030 acres of this property areis deed restricted. SJG also has office and service buildings at six other locations in its territory. There is a liquefied natural gas storage, liquefaction and vaporization facility at one of these locations.
In November 2018, SJG opened its corporate headquarters in Atlantic City, New Jersey.
ETG is headquartered in Union, NJ and owns approximately 3,200 miles of distribution pipeline in seven counties in northern and central New Jersey. ETG has office and service buildings at six other locations in its territory. ELK is headquartered in Elkton, MD and has one other service building in its territory.
As of December 31, 2016, SJG’s2018, SJI's utility plant had a gross book value of $2.4$4.3 billion and net book value, after accumulated depreciation, of $3.6 billion. In 2018, SJI spent $341.1 million on additions to utility plant and nonutility property and equipment, and there were retirements of property having an aggregate gross book cost of $38.1 million. As of December 31, 2018, SJG's utility plant had a gross book value of $2.9 billion and a net book value, after accumulated depreciation, of $2.0$2.4 billion. In 2016, $225.32018, SJG spent $241.9 million was spent on additions to utility plant and there were retirements of property having an aggregate gross carrying valuebook cost of $16.7$26.8 million.
Virtually all of SJG’sthe Utilities transmission pipeline, distribution mains and service connections are under streets or highways or on the property of others. The transmission and distribution systems are maintained under franchises or permits or rights-of-way, many of which are perpetual. SJG’sThe Utilities' properties (other than property specifically excluded) are subject to a lien of mortgage under which its first mortgage bonds are outstanding. We believe these properties are generally well maintained and in good operating condition.
Nonutility property and equipment with a net book value of $99.6 million consists primarily of Marina's thermal facility. This amount is reduced compared to the prior year due to the sale of certain solar assets (see Note 1 to the consolidated financial statements).
SJF an inactive subsidiary, owns real estate in Deptford Township and Upper Township, New Jersey.
Item 3. Legal Proceedings
SJI and SJG isare subject to claims which arisearising in the ordinary course of business and other legal proceedings. SJG accrues liabilities related to these claims when it can reasonably estimate the amount or range of amounts of probable settlement costs orSJI has been named in, among other charges for these claims. SJG is currently involved in a pricing dispute related to a long-termactions, certain gas supply contract whereby SJG has sued the supplier to recover amounts that were improperly invoiced. Subsequently, the supplier counter-sued SJG claiming it is owed an additional $14.9 million, plus interest, through December 31, 2016 under the same contract. We believe any monies received or paid associated with the SJGdisputes and certain product liability claims would reflect gas costs that would be recovered from SJG's customers through adjusted rates. The Company has accrued approximately $0.6 million and $0.8 million related to all claims inour former sand mining subsidiary. See Note 15 to the aggregate, as of December 31, 2016 and 2015, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effectconsolidated financial statements for more detail on our financial position, results of operations or liquidity.
these claims.
Item 4. Mine Safety Disclosures
Not applicable.
Item 4A. Executive Officers of the Registrant
Set forth below are the names, ages and positions of SJI's executive officers along with their business experience during the past five years. All executive officers of SJI are elected annually and serve at the discretion of the Board of Directors. All information is as of the date of the filing of this Report.
| Name, age and position with the Company | Period Served | |
Michael J. Renna, Age 51 | ||
| Chief Executive Officer | April 2015 - Present | |
| Director | January 2014 - Present | |
| President | January 2014 - Present | |
| Chief Operating Officer | January 2014 - April 2015 | |
| Senior Vice President | January 2013 - January 2014 | |
Cielo Hernandez, Age 43 | ||
| Chief Financial Officer | January 2019 - Present | |
| Senior Vice President | January 2019 - Present | |
| VP and Chief Financial Officer North America and Canada Region, Maersk Line | February 2015 - December 2018 | |
| VP & CFO Latin America Region, APM Terminals | November 2013 - January 2015 | |
Stephen H. Clark, Age 60 | ||
| President, SJES | August 2018 - Present | |
| Chief Operating Officer, SJES | August 2018 - Present | |
| Executive Vice President | January 2017 - Present | |
| Senior Vice President | April 2015 - December 2016 | |
| Chief Financial Officer | November 2013 - August 2018 | |
| Treasurer | January 2004 - April 2014 | |
Kenneth A. Lynch, Age 53 | ||
| Chief Accounting & Risk Officer | August 2018 - Present | |
| Chief Risk Officer | January 2017 - Present | |
South Jersey Industries, Inc.
Part I
| Senior Vice President | April 2015 - Present | |
| Chief Accounting Officer | January 2013 - December 2016 | |
Kathleen A. McEndy, Age 65 | ||
| Chief Administrative Officer | June 2015 - Present | |
| Senior Vice President | April 2015 - Present | |
| Chief Human Resources Officer | March 2013 - June 2015 | |
| Vice President | March 2013 - April 2015 | |
David Robbins, Jr., Age 56 | ||
| President, SJIU | August 2018 - Present | |
| President, SJG | January 2017 - August 2018 | |
| Senior Vice President | April 2015 - Present | |
| Vice President | April 2014 - April 2015 | |
| Senior Vice President, SJES | January 2013 - December 2016 | |
| Chief Operating Officer, SJES | January 2013 - April 2014 | |
Steven R. Cocchi, Age 41 | ||
| Chief Strategy and Development Officer | January 2018 - Present | |
| Interim General Counsel | August 2017 - December 2017 | |
| Senior Vice President, Strategy and Growth | April 2017 - Present | |
| Vice President, Strategy and Growth | January 2017 - April 2017 | |
| Vice President, Rates and Regulatory Affairs | April 2015 - January 2017 | |
| Director, Rates and Revenue Requirements | October 2011 - April 2015 | |
Melissa Orsen, Age 43 | ||
| Senior Vice President & General Counsel | January 2018 - Present | |
| Chief Executive Officer, New Jersey Economic Development Authority | March 2015 - December 2017 | |
| Deputy Commissioner, New Jersey Department of Community Affairs | March 2014 - March 2015 | |
| Chief of Staff & Lieutenant Governor, Office of the New Jersey Governor | January 2011 - March 2014 | |
Item 5. Market for the Registrant’sRegistrant's Common Equity,
Related Stockholder Matters and Issuer Purchases of Equity Securities
South Jersey Industries, Inc.
Market Price of Common Stock and Related Information
Our stock is traded on the New York Stock Exchange under the symbol SJI. As of December 31, 2018, the latest available date, our records indicate there were 6,248 shareholders of record.
Stock Performance Graph
The performance graph below illustrates a five-year comparison of cumulative total returns based on an initial investment of $100 in South Jersey Industries, Inc. common stock, as compared with the S&P 500 Stock Index and the S&P Utility Index for the five-year period through December 31, 2018.
This performance chart assumes:
$100 invested on December 31, 2013 in South Jersey Industries, Inc. common stock, in the S&P 500 Stock Index and in the S&P Utility Index; and
All dividends are reinvested.
| Dec-13 | Dec-14 | Dec-15 | Dec-16 | Dec-17 | Dec-18 | |||||||||||||
| S&P 500 | 100 | $ | 114 | $ | 115 | $ | 129 | $ | 157 | $ | 150 | |||||||
| S&P Utilities | $ | 100 | $ | 129 | $ | 123 | $ | 143 | $ | 160 | $ | 167 | ||||||
| SJI | $ | 100 | $ | 109 | $ | 91 | $ | 134 | $ | 128 | $ | 119 | ||||||
Information required by this item is also found in Note 6 of the consolidated financial statements included under Item 8 of this Report.
SJI has a history of paying quarterly dividends and has a stated goal of increasing its dividend annually.
In 2018, non-employee members of SJI's Board of Directors received an aggregate of 26,416 shares of restricted stock, valued at that time at $823,123, as part of their compensation for serving on the Board.
Issuer Purchases of Equity Securities - There were no purchases by SJI of its own common stock during the year ended December 31, 2018.
South Jersey Gas Company
All of the outstanding common stock of SJG (its only class of equity securities) is owned by its parent company, South Jersey Industries, Inc.SJI. The common stock is not traded on any stock exchange.
SJG is restricted under its First Mortgage Indenture, as supplemented, as to the amount of cash dividends or other distributions that may be paid on its common stock. As of December 31, 2016,2018, these restrictions did not affect the amount that may be distributed from SJG’s retained earnings. SJG declared and paid cash dividends of $20.0 million in 2017 to SJI. No dividends were declared or paid on SJG's common stock in 2018 or 2016. SJG declared and paid dividends totaling $40.8 on its common stock in 2015.
Item 6. Selected Financial Data
Five-Year Summary of Selected Financial Data
(In Thousands Where Applicable)
South Jersey Industries, Inc. and Subsidiaries
Year Ended December 31,
The following financial data has been obtained from SJI’s consolidated financial statements (in thousands, except for ratios, shares data and earnings per share):
| 2018 | 2017 | 2016 | 2015 | 2014 | |||||||||||
| Operating Results: | |||||||||||||||
| Operating Revenues | $ | 1,641,338 | $ | 1,243,068 | $ | 1,036,500 | $ | 959,568 | $ | 886,996 | |||||
| Income (Loss) from Continuing Operations | $ | 17,903 | $ | (3,404 | ) | $ | 119,061 | $ | 105,610 | $ | 97,628 | ||||
| Discontinued Operations - Net (1) | (240 | ) | (86 | ) | (251 | ) | (503 | ) | (582 | ) | |||||
| Net Income (Loss) | $ | 17,663 | $ | (3,490 | ) | $ | 118,810 | $ | 105,107 | $ | 97,046 | ||||
| Total Assets | $ | 5,956,577 | $ | 3,865,086 | $ | 3,730,567 | $ | 3,480,900 | $ | 3,349,425 | |||||
| Capitalization: | |||||||||||||||
| Equity | $ | 1,267,022 | $ | 1,192,409 | $ | 1,289,240 | $ | 1,037,539 | $ | 932,432 | |||||
| Long-Term Debt | 2,106,863 | 1,122,999 | 808,005 | 1,006,394 | 859,491 | ||||||||||
| Total Capitalization | $ | 3,373,885 | $ | 2,315,408 | $ | 2,097,245 | $ | 2,043,933 | $ | 1,791,923 | |||||
| Ratio of Earnings to Fixed Charges (2) | 1.2x | 0.5x | 5.4 | x | 3.8x | 3.8x | |||||||||
| Diluted Earnings (Loss) Per Common Share (Based on Average Diluted Shares Outstanding) (3): | |||||||||||||||
| Continuing Operations | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | $ | 1.53 | $ | 1.47 | ||||
| Discontinued Operations - Net (1) | — | — | — | (0.01 | ) | (0.01 | ) | ||||||||
| Diluted Earnings (Loss) Per Common Share (3) | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | $ | 1.52 | $ | 1.46 | ||||
| Return (Loss) on Average Equity (4) | 1.5 | % | (0.3 | )% | 10.2 | % | 10.7 | % | 11.1 | % | |||||
| Share Data: | |||||||||||||||
| Number of Shareholders of Record | 6.3 | 6.5 | 6.7 | 6.7 | 6.9 | ||||||||||
| Average Common Shares (3) | 83,693 | 79,541 | 76,362 | 68,735 | 66,278 | ||||||||||
| Common Shares Outstanding at Year End (3) | 85,506 | 79,549 | 79,478 | 70,966 | 68,334 | ||||||||||
| Dividend Reinvestment Plan: | |||||||||||||||
| Number of Shareholders | 4.8 | 5.0 | 5.2 | 5.2 | 5.2 | ||||||||||
| Number of Participating Shares (3) | 3,317 | 3,607 | 3,627 | 4,170 | 4,082 | ||||||||||
| Book Value at Year End (3) | $ | 14.82 | $ | 14.99 | $ | 16.22 | $ | 14.62 | $ | 13.65 | |||||
| Dividends Declared per Common Share (3) | $ | 1.13 | $ | 1.10 | $ | 1.07 | $ | 1.02 | $ | 0.96 | |||||
| Market Price at Year End (3) | $ | 27.80 | $ | 31.23 | $ | 33.69 | $ | 23.52 | $ | 29.46 | |||||
| Market-to-Book Ratio (3) | 1.9 | x | 2.1 | x | 2.1 | x | 1.6x | 2.2x | |||||||
| Consolidated Economic Earnings (5) | |||||||||||||||
| Income (Loss) from Continuing Operations | $ | 17,903 | $ | (3,404 | ) | $ | 119,061 | $ | 105,610 | $ | 97,628 | ||||
| Minus/Plus: | |||||||||||||||
| Unrealized Mark-to-Market Losses/(Gains) on Derivatives and Realized Losses/(Gains) on Inventory Injection Hedges (6) | (35,846 | ) | 14,558 | (26,867 | ) | (8,355 | ) | 8,211 | |||||||
| Net Loss from Affiliated Companies (6,7) | — | — | — | (2,540 | ) | 2,540 | |||||||||
| Loss on Property, Plant and Equipment (8) | 105,280 | 91,299 | — | — | — | ||||||||||
| Net Losses from Legal Proceedings (9) | 5,910 | 56,075 | — | — | — | ||||||||||
| Acquisition/Sale Costs (10) | 34,674 | 19,564 | — | — | — | ||||||||||
| Customer Credits (11) | 15,333 | — | — | — | — | ||||||||||
| ERIP (12) | 6,733 | — | — | — | — | ||||||||||
| Other (6,13) | — | 2,227 | (165 | ) | (165 | ) | (165 | ) | |||||||
| Income Taxes (14) | (33,753 | ) | (70,834 | ) | 10,813 | 4,424 | (4,235 | ) | |||||||
| Additional Tax Adjustments (15) | — | (11,420 | ) | — | — | — | |||||||||
| Economic Earnings | $ | 116,234 | $ | 98,065 | $ | 102,842 | $ | 98,974 | $ | 103,979 | |||||
| Earnings (Loss) per Share from Continuing Operations (3) | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | $ | 1.53 | $ | 1.47 | ||||
| Minus/Plus: | |||||||||||||||
| Unrealized Mark-to-Market Losses/(Gains) on Derivatives and Realized Losses/(Gains) on Inventory Injection Hedges (6) | (0.42 | ) | 0.18 | (0.35 | ) | (0.12 | ) | 0.12 | |||||||
| Net Loss from Affiliated Companies (6,7) | — | — | — | (0.04 | ) | 0.04 | |||||||||
| Loss on Property, Plant and Equipment (8) | 1.24 | 1.14 | — | — | — | ||||||||||
| Net Losses from Legal Proceedings (9) | 0.07 | 0.70 | — | — | — | ||||||||||
| Acquisition/Sale Costs (10) | 0.41 | 0.25 | — | — | — | ||||||||||
| Customer Credits (11) | 0.18 | — | — | — | — | ||||||||||
| ERIP (12) | 0.08 | — | — | — | — | ||||||||||
| Other (6,13) | — | 0.03 | — | — | — | ||||||||||
| Income Taxes (14) | (0.39 | ) | (0.89 | ) | 0.13 | 0.07 | (0.06 | ) | |||||||
| Additional Tax Adjustments (15) | — | (0.14 | ) | — | — | — | |||||||||
| Economic Earnings per Share (3,5) | $ | 1.38 | $ | 1.23 | $ | 1.34 | $ | 1.44 | $ | 1.57 | |||||
| (1) | Represents discontinued business segments: sand mining and distribution operations sold in 1996 and fuel oil operations with related environmental liabilities in 1986 (See Note 3 to the consolidated financial statements). |
| (2) | Calculated as Income (Loss) from Continuing Operations before Income Taxes and Interest Expense divided by Total Fixed Charges, which consists of Interest Expense and Capitalized Interest. |
| (3) | All share and per share amounts were adjusted for all periods presented for the 2-for-1 stock split, effected in the form of a stock dividend, effective on May 8, 2015. |
| (4) | Calculated based on Income from Continuing Operations. |
| (5) | This section includes the non-GAAP financial measures of Economic Earnings and Economic Earnings per share. See "Management's Discussion and Analysis of Financial Condition and Results of Operations" in Item 7 of this Report for a discussion regarding the use of non-GAAP financial measures and a reconciliation of income from Continuing Operations and earnings per share to Economic Earnings and Economic Earnings per share, respectively. |
| (6) | Certain reclassifications have been made to the prior period numbers in these tables to conform to the current period presentation. The 2014-2015 numbers in these line items have been adjusted to be presented before income taxes. |
| (7) | Resulting from a reserve for uncollectible accounts recorded by an Energenic subsidiary that owned and operated a central energy center and energy distribution system for a hotel, casino and entertainment complex in Atlantic City, New Jersey . In 2014, this charge was excluded from Economic Earnings as the total economic impact of the proceedings had not been realized. During the second quarter 2015, the Company, through its investment in Energenic, reduced the carrying value of the investment in this project. As such, this charge is included in Economic Earnings in 2015. |
| (8) | Represents impairment charges taken in 2018 on solar generating facilities (which was primarily driven by the purchase price in the agreement to sell solar assets being less than the carrying amount of the assets) along with LFGTE assets (which was primarily driven by the remaining carrying value of these assets no longer being recoverable. Also represents impairment charges taken in 2017 on solar generating facilities, LFGTE long-lived assets, LFGTE assets customer relationships, and goodwill. |
| (9) | Represents net losses from three separate legal proceedings: (a) charges in 2017 and 2018, including interest, legal fees and the realized difference in the market value of the commodity (including financial hedges) resulting from a ruling in a legal proceeding related to a pricing dispute between SJI and a gas supplier that began in October 2014; (b) a charge in 2017, including legal fees, resulting from a settlement with a counterparty over a dispute related to a three-year capacity management contract; and (c) a gain taken in 2017 resulting from a favorable FERC decision, including interest, over a tariff rate dispute with a counterparty, whereby SJI contended that the counterparty was overcharging for storage demand charges over a ten-year period. |
| (10) | Represents costs incurred on the agreement to acquire the assets of ETG and ELK, including legal, consulting and other professional fees. Also included here are costs incurred on the sale of solar and SJE assets, partially offset by gains recorded on the sale of solar assets. |
| (11) | Represents credits to ETG and ELK customers that were required as part of the Acquisition. |
| (12 | Represents costs incurred on the Company's ERIP as well as the benefit of amending the Company's OPEB. |
| (13) | Included in this amount are amendments made to an existing interest rate derivative linked to unrealized losses previously recorded in AOCL. SJI reclassified this amount from AOCL to Interest Charges on the consolidated statements of income as a result of the prior hedged transactions being deemed probable of not occurring. Since the economic impact will not be realized until future periods, this amount is excluded from Economic Earnings. Also included is additional depreciation expense within Economic Earnings on a solar generating facility where an impairment charge was recorded in the past, which reduced the depreciable basis and recurring depreciation expense, and the related reduction in depreciation expense was added back in prior years. |
| (14) | Determined using a combined average statutory tax rate of approximately 25% for 2018, 39% for 2017 and 40% for 2016, 2015 and 2014. |
| (15) | Represents one-time tax adjustments, most notably for Tax Reform. |
The following financial data has been obtained from SJG’s audited financial statements (In(in thousands, except for Ratio Dataratios and Customers)customers):
| Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||||||||||||||||||
| 2016 | 2015 | 2014 | 2013 | 2012 | 2018 | 2017 | 2016 | 2015 | 2014 | |||||||||||||||||||||||||||||
| Operating Revenues | $ | 461,055 | $ | 534,290 | $ | 501,875 | $ | 446,480 | $ | 421,874 | $ | 548,000 | $ | 517,254 | $ | 461,055 | $ | 534,290 | $ | 501,875 | ||||||||||||||||||
| Operating Income | $ | 122,455 | $ | 119,585 | $ | 113,690 | $ | 105,822 | $ | 101,762 | ||||||||||||||||||||||||||||
| Net Income | $ | 69,045 | $ | 66,578 | $ | 66,483 | $ | 62,236 | $ | 58,241 | $ | 82,949 | $ | 72,557 | $ | 69,045 | $ | 66,578 | $ | 66,483 | ||||||||||||||||||
| Average Shares of Common Stock Outstanding | 2,339 | 2,339 | 2,339 | 2,339 | 2,339 | 2,339 | 2,339 | 2,339 | 2,339 | 2,339 | ||||||||||||||||||||||||||||
| Ratio of Earnings to Fixed Charges (1) | 5.5x | 5.4x | 5.4x | 5.3x | 5.5x | 4.5x | 5.4x | 5.5x | 5.4x | 5.4x | ||||||||||||||||||||||||||||
| As of December 31, | As of December 31, | |||||||||||||||||||||||||||||||||||||
| 2016 | 2015 | 2014 | 2013 | 2012 | 2018 | 2017 | 2016 | 2015 | 2014 | |||||||||||||||||||||||||||||
| Property, Plant and Equipment, Net | $ | 1,952,912 | $ | 1,770,766 | $ | 1,589,369 | $ | 1,424,775 | $ | 1,285,591 | $ | 2,383,459 | $ | 2,154,083 | $ | 1,952,912 | $ | 1,770,766 | $ | 1,589,369 | ||||||||||||||||||
| Total Assets | $ | 2,551,923 | $ | 2,288,204 | $ | 2,185,672 | $ | 1,909,126 | $ | 1,786,459 | $ | 3,118,236 | $ | 2,865,974 | $ | 2,551,923 | $ | 2,288,204 | $ | 2,185,672 | ||||||||||||||||||
| Capitalization: | ||||||||||||||||||||||||||||||||||||||
| Common Equity | $ | 839,900 | $ | 707,927 | $ | 680,568 | $ | 610,969 | $ | 521,395 | $ | 1,008,022 | $ | 921,433 | $ | 839,900 | $ | 707,927 | $ | 680,568 | ||||||||||||||||||
| Long-Term Debt | 423,177 | 584,082 | 507,091 | 454,000 | 425,000 | 874,507 | 758,052 | 423,177 | 584,082 | 507,091 | ||||||||||||||||||||||||||||
| Total Capitalization | $ | 1,263,077 | $ | 1,292,009 | $ | 1,187,659 | $ | 1,064,969 | $ | 946,395 | $ | 1,882,529 | $ | 1,679,485 | $ | 1,263,077 | $ | 1,292,009 | $ | 1,187,659 | ||||||||||||||||||
| Total Customers | 377,625 | 373,100 | 366,854 | 362,256 | 357,306 | 391,092 | 383,633 | 377,625 | 373,100 | 366,854 | ||||||||||||||||||||||||||||
(1) The ratio of earnings to fixed charges represents, on a pre-tax basis, the number of times earnings cover fixed charges. Earnings consist of net income, to which has been added fixed charges and taxes based on income of the Company.SJG. Fixed charges consist of interest charges.
charges and capitalized interest.
Item 7. Management’sManagement's Discussion and Analysis of Financial Condition and
Management's Discussion is divided into the following two major sections:
SJI - WeThis section describes the financial condition and results of operations of SJI and its subsidiaries on a consolidated basis. It includes discussions of our regulated operations, including SJG, and our non-regulated operations.
SJG - This section describes the financial condition and results of operations of SJG, a subsidiary of SJI and separate registrant, which comprises the SJG utility operations segment.
Both sections of Management's Discussion - SJI and SJG - are designed to provide an understanding of each company's respective operations and financial performance and should be read in conjunction with each other as well as in conjunction with the respective company's financial statements and the combined Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.
Unless otherwise noted, earnings per share amounts are presented on a diluted basis, and are based on weighted average common and common equivalent shares outstanding.
OVERVIEW - SJI (or the Company) is an energy services holding company that provides a variety of products and services through the following wholly-owned subsidiaries:
SJIU
SJIU was established as a subsidiary of SJI for the purpose of serving as a holding company that owns SJG, and, as of July 1, 2018, ETG and ELK.
SJG
SJG, a New Jersey corporation, is an operating public utility company engaged in the purchase, transmission and sale of natural gas for residential, commercial and industrial use. WeSJG also sellsells natural gas and pipeline transportation capacity (off-system sales) on a wholesale basis to various customers on the interstate pipeline system and transporttransports natural gas purchased directly from producers or suppliers to their customers. SJG contributed approximately $82.9 million to SJI's net income on a consolidated basis in 2018.
As of December 31, 2016, we2018, SJG served 377,625391,092 residential, commercial and industrial customers in southern New Jersey, compared with 373,100383,633 customers at December 31, 2015.2017. No material part of ourSJG's business is dependent upon a single customer or a few customers. Gas sales, transportation and capacity release for 20162018 amounted to 148.4159.1 MMdts, (million dekatherms), of which 56.858.2 MMdts were firm sales and transportation, 1.21.1 MMdts were interruptible sales and transportation and 90.499.8 MMdts were off-system sales and capacity release. The breakdown of firm sales and transportation includes 42.5%46.3% residential, 20.9%22.4% commercial, 21.0%18.4% industrial, and 15.6%12.9% cogeneration and electric generation. At year-end 2016, weAs of December 31, 2018, SJG served 352,427365,009 residential customers, 24,76725,657 commercial customers and 431426 industrial customers. This includes 2018 net additions of 4,3346,983 residential customers and 191476 commercial and industrial customers.
Supplies of natural gas available to usSJG that are in excess of the quantity required by those customers who use gas as their sole source of fuel (firm customers) make possible the sale and transportation of gas on an interruptible basis to commercial and industrial customers whose equipment is capable of using natural gas or other fuels, such as fuel oil and propane. The term “interruptible” is used in the sense that deliveries of natural gas may be terminated by usSJG at any time if this action is necessary to meet the needs of higher priority customers as described in ourSJG's tariffs. In 2016,2018, usage by interruptible customers, excluding off-system customers, amounted to 1.21.1 MMdts, or approximately 1.0%1% of the total throughput.
ETG/ELK
On July 1, 2018, SJI, through its wholly-owned subsidiary SJIU, acquired the assets of ETG and ELK from Pivotal Utility Holdings, Inc., a subsidiary of Southern Company Gas (see Note 20 to the consolidated financial statements).
ETG is a regulated natural gas utility which distributes natural gas in seven counties in northern and central New Jersey. ETG serves residential, business and industrial customers, with a service territory that covers the northern part of New Jersey, including 86 municipalities throughout Union, Middlesex, Sussex, Warren, Hunterdon, Morris and Mercer Counties. ETG was founded in 1855 and is based in Union, New Jersey. ETG had a net loss of approximately $5.0 million, which reduced SJI's net income on a consolidated basis in 2018 by such amount.
ETG believes growth exists in the expansion of its Northwestern service territory, the Franklin/Sparta area, and the Hackettstown Interconnect. At present, ETG serves approximately 56% of households within its territory with natural gas. ETG also serves northern New Jersey's diversified industrial base that includes pharmaceutical, food and beverage, and transportation industries.
As of December 31, 2018, ETG served 293,672 customers in northern and central New Jersey, including 270,342 residential customers, 23,233 commercial customers and 97 industrial customers. No material part of ETG's business is dependent upon a single customer or a few customers. Gas sales and transportation for July 1 - December 31, 2018 (post-Acquisition) amounted to 212.9 MMdts, of which 176.7 MMdts were firm sales and transportation and 36.2 MMdts were interruptible sales and transportation. The breakdown of firm sales and transportation includes 93.9 MMdts residential, 56.4 MMdts commercial, and 62.6 MMdts industrial.
ELK is a regulated natural gas utility which distributes natural gas in northern Maryland. ELK's service territory covers approximately six square miles in Elkton, Maryland with an estimated permanent population of 16,000. At present, ELK serves approximately 44% of households within its territory with natural gas. ELK's diverse customer base includes residential and commercial accounts coupled with a significant industrial presence in the military and defense, pharmaceutical, chemical and textile industries.
SJES
SJI groups its nonutility operations into two categories: Energy Group and Energy Services. Energy Group includes wholesale energy and retail electric operations. Energy Services includes on-site energy production and appliance service operations. SJI established SJES as a direct subsidiary for the purpose of serving as a holding company for all of SJI's non-utility businesses. The following businesses are wholly-owned subsidiaries of SJES:
SJE
SJE provides services for the acquisition and transportation of electricity for retail end users and markets total energy management services. SJE markets electricity to commercial and industrial customers. SJE became active in the residential market for electricity beginning in March 2016 as a result of several municipal aggregation bids won in the second half of 2015. Most customers served by SJE are located within New Jersey, northwestern Pennsylvania and New England. In 2018, SJE had a net loss of approximately $6.0 million which reduced SJI's net income on a consolidated basis by such amount.
On November 30, 2018, SJI sold the retail gas assets of SJE for total consideration of $15.0 million. As a result of this agreement, SJE no longer acquires, transports or markets natural gas for retail markets. See Note 1 to the consolidated financial statements.
SJRG
SJRG markets natural gas storage, commodity and transportation assets along with fuel management services on a wholesale basis. Customers include energy marketers, electric and gas utilities, power plants and natural gas producers. SJRG's marketing activities occur mainly in the mid-Atlantic, Appalachian and southern regions of the country.
SJRG also conducts price risk management activities by entering into a variety of physical and financial transactions including forward contracts, swap agreements, option contracts and futures contracts. In 2018, SJRG contributed approximately $66.2 million to SJI's net income on a consolidated basis.
SJEX
SJEX owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. SJEX is considered part of SJI's wholesale energy operations. In 2018, SJEX contributed approximately $0.2 million to SJI's net income on a consolidated basis.
Marina
Marina develops and operates on-site energy-related projects. Marina's largest wholly-owned operating project provides cooling, heating and emergency power to the Borgata Hotel Casino & Spa in Atlantic City, NJ.
Other entities that are wholly owned by Marina are ACB, ACLE, BCLE, SCLE, and SXLE.
ACB owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey.
ACLE, BCLE, SCLE and SXLE own and operate landfill gas-to-energy production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.
On June 27, 2018, the Company, through Marina, entered into a series of agreements whereby Marina agreed to sell its portfolio of solar energy assets to a third-party buyer. As part of these agreements, Marina has agreed to sell its distributed solar energy projects located across New Jersey, Maryland, Massachusetts and Vermont. As of December 31, 2018, the Company earned cash of $228.1 million related to the closing of these projects, which included selling the wholly-owned subsidiaries MCS, NBS and SBS, along with $62.5 million related to the sale of certain SRECs. The Company currently has projects that have not yet closed and are expected to be sold in 2019. See Note 1 to the consolidated financial statements.
In 2018, Marina had a net loss of approximately $78.0 million, which reduced SJI's net income on a consolidated basis by such amount.
SJESP
SJESP receives commissions on service contracts from a third party. In 2018, SJESP contributed approximately $1.5 million to SJI's net income on a consolidated basis.
Midstream
Midstream owns a 20% equity investment in PennEast, through which SJI, along with other investors, expect to construct an approximately 118-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey. Construction is expected to begin in 2019 and is estimated to be completed in late 2020. In 2018, Midstream contributed approximately $3.1 million to SJI's net income on a consolidated basis.
Other
Primary Factors Affecting SJI's Business
SJI's current long-term goals are to: 1) provide safe, reliable natural gas service at the lowest cost reasonably possible; 2) promote natural gas as the fuelto grow Economic Earnings Per Share 6-8% annually while maintaining high quality earnings, a strong balance sheet and a low-to-moderate risk profile. Management established those goals in conjunction with SJI's Board of choice for residential, commercialDirectors based upon a number of different internal and industrial customers;external factors that characterize and 3) aid our customers in becoming more energy efficient.influence SJI's current and expected future activities.
The following is a summary of the primary factors we expect to have the greatest impact on ourSJI's performance and our ability to achieve ourthe long-term goals going forward:
Business Model - We are the primaryIn developing SJI's current business model, our focus has been on our core Utilities and natural extensions of those businesses. That focus enables us to concentrate on business activities that match our parent, SJI, andcore competencies. Going forward we expect to continue to account for the majority of SJI’s net income by maximizing the growth potential of our service territory.pursue business opportunities that fit this model.
Customer Growth - Southern New Jersey, ourSJG's primary area of operations, has not been immune to the issues impacting the new housing market nationally. Residential new construction activity remains steady, supported by growth in higher density and multi-family units. Net customersCustomers for SJG grew 1.2%1.9% for 20162018 as we continue ourSJG continues its focus on customer conversions. In 2016,2018, the 4,6317,191 consumers converting their homes and businesses from other heating fuels, such as electric, propane or oil, represented approximately 65%78% of the total new customer acquisitions for the year. In comparison, conversions over the past five years averaged 5,3175,904 annually. Customers in ourSJG's service territory typically base their decisions to convert on comparisons of fuel costs, environmental considerations and efficiencies. While oil and propane prices have become more competitive with natural gas in the past two years, affecting the number of conversions, SJG began a comprehensive partnership with the State’s Office of Clean Energy to educate consumers on energy efficiency and to promote the rebates and incentives available to natural gas users.
Central and Northern NJ, ETG's primary area of operations continues to grow in multifamily housing and gas infrastructure extensions to unserved areas. While ETG continues to partner with builders in the new construction sector with the view of increasing natural gas burner tips, ETG is pursuing conversions throughout its service territory. As a result, customer additions for ETG grew approximately 1.1%. In 2018, 1,590 consumers converted their homes and businesses from other heating fuels, such as electric, propane or oil, representing approximately 50% of the total new customer acquisitions for the year. In comparison, conversions over the past five years average 1,499 annually while new construction averaged 1,327 over the same period. Customers in ETG service territories typically base their decisions to convert on fuel cost savings, efficiencies, and fuel stability pricing. ETG leverages its comprehensive partnership with the State’s Office of Clean Energy to educate consumers on energy efficiency and to promote the rebates and incentives available to natural gas users.
Regulatory Environment - WeSJG and ETG are primarily regulated by the New Jersey Board of Public Utilities (BPU).BPU; ELK is regulated by the MPSC. The BPU setsBPU/MPSC approve the rates that we charge ourare charged to rate-regulated customers for services provided and establishes the terms of service under which wethe Utilities operate. We expect the BPU to continue to setThe rates and establishestablished terms of service that willare designed to enable usthe Utilities to obtain a fair and reasonable return on capital invested. The
SJG’s BPU approved a Conservation Incentive Program (CIP) effective October 1, 2006, discussed in greater detail under “Results of Operations,” thatCIP protects ourSJG's net income from severe fluctuations in gas used by our residential, commercial and small industrial customers. In addition, in February 2013, the BPU issued an Order approving the Accelerated Infrastructure Replacement Program (AIRP),SJG's AIRP is a $141.2 million program to replace cast iron and unprotected bare steel mains and services over a four-year period, with annual investments of approximately $35.3 million. As of December 1, 2016 allservices. All AIRP investments are reflected in base rates. Additionally, the BPU issued an Order approving an extension of the AIRP for a 5-yearfive-year period (“AIRP II”), commencing October 1, 2016, with authorized investments of up to $302.5 million to continue replacing cast iron and unprotected bare steel mains and associated services. SJG earns a return on AIRP II investments untilonce they are placed in service and thereafter, once they are included in rate base, through annual rate adjustments. The BPU also issued an Order in August 2014 approving the Storm Hardening and Reliability Program (SHARP),filings. SJG's SHARP is a $103.5 million program to replace low-pressure distribution mains and services with high-pressure mains and services onin coastal areas that are susceptible to flooding during major storms. In May 2018, the barrier islands overBPU issued an order approving a second phase of the SHARP ("SHARP II") for a three-year period, commencing June 1, 2018, with annualauthorized investments of approximately $34.5 million. The BPU approved an increase in annual revenues from base rates of $3.9up to $100.3 million to reflectcontinue storm hardening efforts to further improve safety, redundancy and resiliency of SJG’s natural gas system in coastal areas. Pursuant to the roll-in of $33.7 million oforder, SHARP II investments made from July 2015 through June 2016, effective October 1, 2016. SJG earns a return on SHARP investments until they are included in rate baseto be recovered through annual base rate adjustments.
Effective November 1, 2017, the BPU granted SJG a base rate increase of $39.5 million (see Note 10 to the consolidated financial statements).
Effective July 1, 2017, the BPU granted ETG a base rate increase of $13.3 million (see Note 10 to the consolidated financial statements).
Consistent with Acquisition approval, SJI was required to develop a plan, in concert with the BPU and the New Jersey Division of Rate Counsel, to address the replacement of ETG's aging infrastructure. In October 2018, ETG filed an IIP petition with the BPU pursuant to rules adopted by the BPU in December 2017 pertaining to utility infrastructure investments. The IIP petition seeks authority to recover the costs associated with ETG's initial investment of approximately $518.0 million from 2019-2023 to, among other things, replace its cast-iron and low-pressure vintage main and related services. The IIP petition includes a request for timely recovery of ETG's investment on a semi-annual basis through a separate rate mechanism. A resolution of the IIP petition is pending.
Weather Conditions and Customer Usage Patterns - Usage patterns can be affected by a number of factors, such as wind, precipitation, temperature extremes and customer conservation. OurSJG's earnings are largely protected from fluctuations in temperatures by the CIP. The CIP has a stabilizing effect on utility earnings as we adjustSJG adjusts revenues when actual usage per customer experienced during an annual period varies from an established baseline usage per customer. The WNC rate allows ETG to implement surcharges or credits during the months of October through May to compensate for weather-related changes in customer usage from the previous winter period. Our nonutility retail marketing business is directly affected by weather conditions, as it does not have regulatory mechanisms that address weather volatility. The impact of different weather conditions on the earnings of our nonutility businesses is dependent on a range of different factors. Consequently, weather may impact the earnings of SJI's various subsidiaries in different, or even opposite, ways. Further, the profitability of individual subsidiaries may vary from year-to-year despite experiencing substantially similar weather conditions.
Changes in Natural Gas and Electricity Prices - GasThe Utilities' gas costs are passed on directly to customers without any profit margin added. ForThe price the vast majority of ourUtilities charge their periodic customers the price for natural gas is set annually, with a regulatory mechanism in place to make limited adjustments to that price during the course of a year. In the event that gas cost increases would justify customer price increases greater than those permitted under the regulatory mechanism, wethe Utilities can petition the BPUBPU/MPSC for an incremental rate increase. High prices can make it more difficult for our customers to pay their bills and may result in elevated levels of bad-debt expense. Among our nonutility activities, the business most likely to be impacted by changes in natural gas prices is our wholesale gas marketing business. Wholesale gas marketing typically benefits from volatility in gas prices during different points in time. The actual price of the commodity does not typically have an impact on the performance of this business line. Our ability to add and retain customers at our retail marketing business is affected by the relationship between the price that the utility charges customers for electric and the cost available in the market at specific points in time. However, retail marketing accounts for a very small portion of SJI's overall activities.
Fuel Supply Management - SJRG has acquired pipeline transportation capacity that allows SJRG to match end users, many of which are merchant generators, with producers looking to find a long-term solution for their supply. We currently have eleven fuel supply management transactions under contract and expect to continue expanding this business.
Midstream Investments - Midstream owns a 20% equity investment in PennEast, through which SJI, along with other investors, expect to construct an approximately 118-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey. In September 2015, PennEast submitted an application to FERC for a permit to proceed with construction. In January 2018, the Certificate of Public Convenience and Necessity was approved by the FERC. This authorized PennEast to construct, install, own, operate and maintain this pipeline. While opponents of the project have filed a variety appeals and several are still pending, a December 2018 ruling from the U.S. District Court of New Jersey allowed PennEast to proceed with survey work that is expected to enable it to complete and submit permit applications to the NJDEP. We expect to make additional investments in similar midstream projects.
Changes in Interest Rates- We have- SJI has operated in a relatively low interest rate environment over the past several years. Rising interest rates would raise the expense associated with existing variable-rate debt and all issuances of new debt. We have sought to mitigate the impact of a potential rising rate environment by directly issuing fixed-rate debt, or by entering into derivative transactions to hedge against rising interest rates.
Labor and Benefit Costs - Labor and benefit costs have a significant impact on ourSJI's profitability. Benefit costs, especially those related to pension and health care, have risen in recent years. We seek to manage these costs by revising health care plans offered to existing employees, capping postretirement health care benefits, and changing health care and pension packages offered to new hires. In addition, the Company offered an ERIP to non-union, non-Officer employees over the age of 55 years old with 20 or more years of service to the Company as well as to Officers over the age of 55 years old with 5 or more years of service to the Company (see Note 1 to the consolidated financial statements). We expect savings from these changes to gradually increase as new hires replace retiring employees. SJI's workforce totaled approximately 1,100 employees at the end of 2018, approximately 550 of which were SJG employees. Of those totals, 495 of SJI employees are unionized and 317 SJG employees are unionized (all of SJI's unionized employees are with SJG or ETG).
Balance Sheet Strength - OurSJI's and SJG's goal is to maintain a strong balance sheet with ansheet. SJI's average annual equity-to-capitalization ratio was approximately 33% and 47% as calculated for the four quarters of 46%2018 and 2017, respectively, with the decrease in 2018 due to 50%debt incurred to fund the Acquisition (see Note 14 to the consolidated financial statements). OurSJG's average equity-to-capitalization ratio inclusivewas approximately 52% and 54% as calculated for the four quarters of short-term debt, was 53%2018 and 49% at the end of 2016 and 2015,2017, respectively. A strong balance sheet assists us in maintaining the financial flexibility necessary to take advantage of growth opportunities and to address volatile economic and commodity markets while maintaining a low-risklow-to-moderate risk platform.
CRITICAL ACCOUNTING POLICIES - Estimates and AssumptionsESTIMATES AND ASSUMPTIONS - As described in the notes to our consolidated financial statements, management must make estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Actual results could differ from those estimates. FiveCertain types of transactions presented in our consolidated financial statements require a significant amount of judgment and estimation. These relate to regulatory accounting, derivatives, environmental remediation costs, pension and other postretirement benefit costs, revenue recognition, and revenue recognition.goodwill.
Regulatory Accounting- WeThe Utilities maintain ourtheir accounts according to the Uniform System of Accounts as prescribed by the BPU.BPU (SJG and ETG) or the MPSC (ELK). As a result of the ratemaking process, wethe Utilities are required to follow Financial Accounting Standards Board (FASB)FASB ASC Topic 980 –- “Regulated Operations.Operations,” We are required under Topic 980which requires them to recognize the impact of regulatory decisions on ourtheir financial statements. WeThe Utilities are required under our Basic Gas Supply Service (BGSS) clausetheir BGSS clauses to forecast ourtheir natural gas costs and customer consumption in setting ourtheir rates. Subject to BPUregulator approval, wethey are able to recover or return the difference between gas cost recoveries and the actual costs of gas through a BGSS charge to customers. WeThe Utilities record any over/under recoveries as a regulatory asset or liability on the consolidated balance sheets and reflect itthem in the BGSS charge to customers in subsequent years. WeThe Utilities also enter into derivatives that are used to hedge natural gas purchases. The offset ofto the resulting derivative assets or liabilities is recorded as a regulatory asset or liability on the consolidated balance sheets. See additional detailed discussions on Rates and Regulatory Actions in Note 310 to the consolidated financial statements.
Derivatives - We recognizeSJI recognizes assets or liabilities for contracts that qualify as derivatives that are entered into by its subsidiaries when such contracts are executed. We record contracts at their fair value in accordance with FASB ASC Topic 815 –- “Derivatives and Hedging.” We record changes in the fair value of the effective portion of derivatives qualifying as cash flow hedges, net of tax, in Accumulated Other Comprehensive LossAOCL and recognize such changes in the income statement when the hedged item affects earnings. Changes in the fair value of derivatives not designated as hedges are recorded in earnings in the current period. Currently we do not designatehave any energy-related derivative instruments designated as cash flow hedges. Hedge accounting has been discontinued for the remaining interest rate derivatives. As a result, unrealized gains and losses on these derivatives, that were previously recorded in AOCL on the consolidated balance sheets, are being recorded into earnings over the remaining life of the derivative.
Certain derivatives that result in the physical delivery of the commodity may meet the criteria to be accounted for as normal purchases and normal sales, if so designated, in which case the contract is not marked-to-market, but rather is accounted for when the commodity is delivered. Due to the application of regulatory accounting principles under Generally Accepted Accounting Principles (United States),GAAP, derivatives related to SJG's gas purchases that are marked-to-market are recorded through ourthe BGSS. WeSJG periodically enterenters into financial derivatives to hedge against forward price risk. These derivatives are recorded at fair value with an offset to regulatory assets and liabilities through ourSJG's BGSS, subject to BPU approval (See Notes 310 and 411 to the consolidated financial statements). We adjust the fair value of the contracts each reporting period for changes in the market.
As discussed in Notes 1316 and 1417 of the consolidated financial statements, energy-related derivative instruments are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy established by FASB ASC Topic 820 –- “Fair Value Measurements and Disclosures.” Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. Management reviews and corroborates the price quotations with at least one additional source to ensure the prices are observable market information, which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. Derivative instruments that are used to limit our exposure to changes in interest rates on variable-rate, long-term debt are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment, as a result, these instruments are categorized in Level 2 in the fair value hierarchy. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 in the fair value hierarchy as the model inputs generally are not observable. Counterparty credit risk and the credit risk of SJG, isSJI, are incorporated and considered in the valuation of all derivative instruments as appropriate. The effect of counterparty credit risk and the credit risk of SJGSJI on the derivative valuations is not significant.
Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forward contracts, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuationsthese values from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electrical load profiles; therefore, no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
Environmental Remediation Costs - We estimate a range of future costs based on projected investigation and work plans using existing technologies. In preparing consolidated financial statements, we recordSJI records liabilities for future costs using the lower end of the range because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue. We update estimates each year to take into account past efforts, changes in work plans, remediation technologies, government regulations and site specific requirements (see Note 1215 to the consolidated financial statements).
Pension and Other Postretirement Benefit Costs - The costs of providing pension and other postretirement employee benefits are impacted by actual plan experience as well as assumptions of future experience. Employee demographics, plan contributions, investment performance, and assumptions concerning mortality, return on plan assets, discount rates and health care cost trends all have a significant impact on determining our projected benefit obligations. We evaluate these assumptions annually and adjust them accordingly. These adjustments could result in significant changes to the net periodic benefit costs of providing such benefits and the related liabilities recognized by us.SJI.
$1.5 million, due to an increase in 2016. These include increasing discount rates and updated mortality tables released bya full year of the Societyacquired companies. In 2019, the acquired companies are estimated to generate net periodic benefit income of Actuaries in late 2015. Further, the Company changed the structure of its postretirement healthcare plan for retirees to provide them with a fixed contribution to a health reimbursement account and allowing them to obtain coverage from healthcare exchanges, rather than utilizing the Company-provided healthcare plan. These positive factors are partially offset by lower than expected returns on plan assets due to poor performance in the equity markets in 2015.
approximately $1.0 million. Additional information regarding investment returns and assumptions can be found in Pension and Other Postretirement Benefits in Note 1112 to the consolidated financial statements.
Revenue Recognition - Gas and electricity revenues are recognized in the period the commodity is delivered to customers. WeAll SJI entities bill customers monthly at rates approved by the BPU.monthly. A majority of our customers have their meters read on a cycle basis throughout the month. As a result, recognized revenues include estimates. For retail customers that are not billed at the end of each month, we record an estimate to recognize unbilled revenues for gasgas/electricity delivered from the date of the last meter reading to the end of the month. OurThe Utilities' unbilled revenue for natural gas is estimated each month based on natural gas delivered monthly deliveries into the system; unaccounted for natural gas based on historical results; customer-specific use factors, when available; actual temperatures during the period; and applicable customer rates. SJE's unbilled revenue for retail electricity is based on customer-specific use factors and applicable customer rates. We bill SJG and ETG customers at rates approved by the BPU, and ELK customers at rates approved by the MPSC. SJE and SJRG customers are billed at rates negotiated between the parties.
SJRG presents revenues and expenses related to its energy trading activities on a net basis in Operating Revenues - Nonutility in the statements of consolidated income consistent with GAAP. This net presentation has no effect on operating income or net income.
SJESP will receive commissions paid on service contracts from the third party on a go forward basis. These commissions are recognized as revenue as they are earned.
Marina recognizes revenue on a monthly basis as services are provided and for on-site energy production that is delivered to its customers.
On January 1, 2018, SJI and SJG adopted ASU 2014-09 Revenue from Contracts with Customers, and all amendments, in accordance with the guidance in ASC 606. SJI and SJG adopted the new guidance using the modified retrospective method applied to those contracts that were not completed as of January 1, 2018. Results for reporting periods beginning after January 1, 2018 are presented under ASC 606, while prior period amounts are not adjusted and continue to be reported in accordance with the historical accounting under ASC 605. The methods of recognizing revenue for SJI's and SJG's contracts with customers is the same under ASC 605 and ASC 606, as revenues from contracts that SJI and SJG have with customers are currently recorded as gas or electricity is delivered to the customer, which is consistent with the new guidance under ASC 606. As such, there was no significant impact to revenues for the year ended December 31, 2018 for SJI or SJG as a result of applying ASC 606, and there was no cumulative catch-up to retained earnings for SJI or SJG under the modified retrospective method for changes in accounting for revenues. Further, there were no significant changes to SJI's or SJG's business processes, systems or internal controls over financial reporting needed to support recognition and disclosure under the new guidance. Some revenue arrangements, such as alternative revenue programs and derivative contracts, are excluded from the scope of ASC 606 and, therefore, will be presented separately from revenues under ASC 606 on SJI and SJG's footnote disclosures (see Note 19 to the consolidated financial statements). Alternative revenue programs include revenue earned at the Utilities on such programs as the CIP, AIRP, SHARP and WNC.
The BPU allows usBPU/MPSC allow the Utilities to recover gas costs in rates through the BGSS price structure. WeThe Utilities defer over/under recoveries of gas costs and includeincludes them in subsequent adjustments to the BGSS rate. These adjustments result in over/under recoveries of gas costs being included in rates during future periods. As a result of these deferrals, utility revenue recognition does not directly translate to profitability. While wethe Utilities realize profits on gas sales during the month of providing the utility service, significant shifts in revenue recognition may result from the various recovery clauses approved by the BPU.BPU/MPSC. This revenue recognition process does not shift earnings between periods, as these clauses only provide for cost recovery on a dollar-for-dollar basis (See(see Notes 310 and 11 to the consolidated financial statements).
Goodwill - Goodwill represents future economic benefits arising from other assets acquired in a business combination that are not individually identified and separately recognized. Goodwill is initially measured at cost, being the excess of the aggregate of the consideration paid or transferred over the fair value of identifiable net assets acquired. Goodwill is not amortized, but instead is subject to impairment testing on an annual basis, and between annual tests whenever events or changes in circumstances indicate that the fair value of a reporting unit may be below its carrying amount.
Tax Cuts and Jobs Act - On December 22, 2017, Tax Reform was enacted into law, changing various corporate income tax provisions within the existing Internal Revenue Code. The law became effective January 1, 2018 but was required to be accounted for in the period of enactment, as such SJI adopted the new requirements in the fourth quarter of 2017. SJI and SJG were impacted in several ways as a result of Tax Reform, including provisions related to the permanent reduction in the U.S. federal corporate income tax rate from 35% to 21%. See Note 4 to the consolidated financial statements).statements.
NEW ACCOUNTING PRONOUNCEMENTS - See detailed discussions concerning New Accounting Pronouncements and their impact on SJI in Note 1 to the consolidated financial statements.
RATES AND REGULATION - SJG and ETG ("the NJ Utilities" for context of this section) are subject to regulation by the BPU. Additionally, the Natural Gas Policy Act, which was enacted in November 1978, contains provisions for Federal regulation of certain aspects of the NJ Utilities' business. The NJ Utilities are affected by Federal regulation with respect to transportation and pricing policies applicable to pipeline capacity from Transco (both utilities' major supplier), Columbia and Dominion , since such services are provided under rates and terms established under the jurisdiction of the FERC. The NJ Utilities' retail sales are made under rate schedules within a tariff filed with, and subject to the jurisdiction of, the BPU. These rate schedules provide primarily for either block rates or demand/commodity rate structures. The NJ Utilities' primary rate mechanisms include base rates, the BGSS, Accelerated Infrastructure Programs, EET and the CIP for SJG, and BGSS and WNC for ETG.
The CIP is a BPU-approved program that is designed to eliminate the link between SJG profits and the quantity of natural gas SJG sells, and to foster conservation efforts. With the CIP, SJG's profits are tied to the number of customers served and how efficiently SJG serves them, thus allowing SJG to focus on encouraging conservation and energy efficiency among its customers without negatively impacting net income. The CIP tracking mechanism adjusts earnings based on weather, and also adjusts SJG's earnings when actual usage per customer experienced during an annual period varies from an established baseline usage per customer.
Each CIP year begins October 1 and ends September 30 of the subsequent year. On a monthly basis during a CIP year, we recordSJG records adjustments to earnings based on weather and customer usage factors, as incurred. Subsequent to each year, we makeSJG makes filings with the BPU to review and approve amounts recorded under the CIP. BPU-approved cash inflows or outflows generally will not begin until the next CIP year and have no impact on earnings at that time.
Utility earnings are recognized during current periods based upon the application of the CIP. The cash impact of variations in customer usage will result in cash being collected from, or returned to, customers during the subsequent CIP year, which runs from October 1 to September 30.
The effects of the CIP on ourSJG's net income for the last three years and the associated weather comparisons were as follows ($’s's in millions):
| 2016 | 2015 | 2014 | 2018 | 2017 | 2016 | |||||||||||||||
| Net Income Impact: | ||||||||||||||||||||
| CIP – Weather Related | 5.9 | 0.9 | (4.7 | ) | ||||||||||||||||
| CIP – Usage Related | 4.0 | (1.9 | ) | 2.0 | ||||||||||||||||
| CIP - Weather Related | $ | (16.5 | ) | $ | 8.7 | $ | 5.9 | |||||||||||||
| CIP - Usage Related | 7.5 | 3.3 | 4.0 | |||||||||||||||||
| Total Net Income Impact | $ | 9.9 | $ | (1.0 | ) | $ | (2.7 | ) | $ | (9.0 | ) | $ | 12.0 | $ | 9.9 | |||||
| Weather Compared to 20-Year Average | 8.1% warmer | 3.1% warmer | 7.5% colder | 183.0% colder | 11.5% warmer | 8.1% warmer | ||||||||||||||
| Weather Compared to Prior Year | 2.5% warmer | 9.6% warmer | 4.6% colder | 7.7% colder | 0.4% warmer | 2.5% warmer | ||||||||||||||
As part of the CIP, we areSJG is required to implement additional conservation programs, including customized customer communication and outreach efforts, targeted upgrade furnace efficiency packages, financing offers, and an outreach program to speak to local and state institutional constituents. We areSJG is also required to reduce gas supply and storage assets and their associated fees. Note that changes in fees associated with supply and storage assets have no effect on ourSJG's net income as these costs are passed through directly to customers on a dollar-for-dollar basis.
Earnings accrued and payments received under the CIP are limited to a level that will not cause ourSJG's return on equity to exceed 9.75%9.6% (excluding earnings from off-system gas sales and certain other tariff clauses) and CIP recoveries are limited by the annualized savings attained from reducing gas supply and storage assets.
For ETG, the WNC is a BPU-approved program that is designed to recover or refund balances associated with differences between actual and normal weather during the preceding winter period(s). The effective winter period of the WNC is defined as October through May.
In 2018, ETG's net income was reduced by $3.0 million, primarily due to colder than average weather for the applicable months in the 2018 winter period.
See additional detailed discussions on Rates and Regulatory Actions in Note 310 to the consolidated financial statements.
ENVIRONMENTAL REMEDIATION - See detailed discussion concerning EnvironmentEnvironmental Remediation in Note 1215 to the consolidated financial statements.
SJRG competes in the wholesale natural gas market against a wide array of competitors on a cost competitive, term of service, and reliability basis. SJRG has been a reliable energy provider in this arena for more than 20 years.
Marina competes with other companies that develop and operate similar types of on-site energy production. Marina also faces competition from customers' preferences for alternative technologies for energy production, as well as those customers that address their energy needs internally.
RESULTS OF OPERATIONS:
SJI operates in several different reportable operating segments. These segments are as follows:
SJG utility operations consist primarily of natural gas distribution to residential, commercial and industrial customers in southern New Jersey.
ETG utility operations consist primarily of natural gas distribution to residential, commercial and industrial customers in northern and central New Jersey.
ELK utility operations consist of natural gas distribution to residential, commercial and industrial customers in Maryland.
Wholesale energy operations include the activities of SJRG and SJEX.
Retail gas and other operations at SJE included natural gas acquisition and transportation service business lines. This business was sold on November 30, 2018 (see Note 1 to the consolidated financial statements).
Retail electric operations at SJE consist of electricity acquisition and transportation to commercial, industrial and residential customers.
On-site energy production consists of Marina's thermal energy facility and other energy-related projects. Also included in this segment are the activities of ACB, ACLE, BCLE, SCLE, SXLE, along with MCS, NBS and SBS, which were sold in October 2018 (see Note 1 to the consolidated financial statements).
Appliance service operations includes SJESP, which receives commissions on service contracts from a third party.
Midstream was formed to invest in infrastructure and other midstream projects, including a current project to build a natural gas pipeline in Pennsylvania and New Jersey.
Corporate & Services segment includes costs related to the Acquisition, along with other unallocated costs.
Intersegment represents intercompany transactions between the above SJI consolidated entities.
SJI groups its utility businesses under its wholly-owned subsidiary SJIU. This group consists of gas utility operations of SJG, ETG and ELK. SJI groups its nonutility operations into separate categories: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations.
SJI's net income for 2018 increased $21.2 million to $17.7 million compared to 2017. The significant drivers for the overall change were as follows:
The net income contribution from the wholesale energy operations at SJRG increased $89.7 million to $66.2 million. The significant drivers for the overall change were as follows:
| ◦ | $37.5 million increase due to the change in unrealized gains and losses on derivatives used by the wholesale energy operations to mitigate natural gas commodity price risk, as discussed under "Operating Revenues - Energy Group" below. This change was also impacted by Tax Reform. |
| ◦ | $28.9 million increase due to lower legal fees, reserves and interest recorded on a pricing dispute between SJI and a gas supplier as compared with the same period in 2017 (see Note 15 to the consolidated financial statements), along with two other settled cases (see 2017 vs. 2016 discussion below). |
| ◦ | The remaining increase is primarily due to higher margins on daily energy trading activities and an overall increase in sales due to cold weather experienced in the first quarter of 2018, as discussed under "Gross Margin - Energy Group" below. Also contributing was the impact of Tax Reform. |
The net income contribution from the gas utility operations at SJG increased $10.3 million to $82.9 million, primarily due to the base rate case settlement, the roll-in of investments for infrastructure replacement and improvement, along with customer growth, partially offset with an overall increase in depreciation, interest and operations expenses.
SJI recorded $30.4 million (after-tax) of additional financing costs and other charges compared to 2017 in connection with the Acquisition (see Note 14 and 20 to the consolidated financial statements). These costs are recorded in the Corporate & Services segment.
The net income contribution from on-site energy production at Marina decreased $17.5 million to a net loss of $78.0 million, primarily due to $78.7 million (after-tax) of impairment charges taken on solar generating facilities and LFGTE assets in 2018, which were driven by the purchase price in the agreement to sell solar assets being less than the carrying amount of the assets, along with the carrying value of LFGTE assets no longer being recoverable. Also contributing were consulting and legal costs incurred as a result of the agreement to sell solar assets. This was partially offset by $56.1 million (after-tax) of impairment charges recorded in 2017, along with gains recorded on the sale of solar assets (see Note 1 to the consolidated financial statements).
SJI recorded $13.5 million of one-time tax gains in 2017 related to the enactment of Tax Reform. See Note 4 to the consolidated financial statements.
SJI recorded $5.0 million (after-tax) related to the implementation of the ERIP as well as amendments made to the OPEB (see Notes 1 and 12 to the consolidated financial statements).
The net income contribution from the retail gas and electric operations at SJE decreased $7.3 million to a net loss of $6.0 million primarily due to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on retail gas as discussed under "Operating Revenues – Energy Group" below, along with a loss recorded on the sale of the SJE retail gas operations (see Note 1 to the consolidated financial statements).
In connection with the Acquisition (see Note 20 to the consolidated financial statements), SJI consolidated the accounts of ETG and ELK gas utility operations beginning with the third quarter of 2018. This contributed a net loss of $5.2 million in 2018, which included approximately $11.1 million (after-tax) of credits provided to customers of ETG and ELK (see Note 10 to the consolidated financial statements).
SJI's net income for 2017 decreased $122.3 million, or 102.9%, to a net loss of $3.5 million compared to 2016. The significant drivers for the overall change were as follows:
The net income contribution from on-site energy production at Marina decreased $76.5 million to a net loss of $60.5 million, primarily due to the following:
| ◦ | $56.1 million decrease due to several impairment charges recorded during the year, including impairments on solar generating facilities, LFGTE long-lived assets, LFGTE assets customer relationships, and goodwill (see Note 1 to the consolidated financial statements). |
| ◦ | $9.1 million of investment tax credits on renewable energy facilities recorded in 2016, compared with none recorded in 2017, which is consistent with SJI's previously announced strategy of substantially reducing solar development. |
| ◦ | $4.5 million decrease related to gains on two settlements recorded at Marina in 2016 that did not recur in 2017 (see Note 7 to the consolidated financial statements). |
| ◦ | $1.7 million decrease related to the change in unrealized gains and losses on interest rate derivative contracts (see Note 16 to the consolidated financial statements). |
| ◦ | The remaining decrease is primarily due to an overall increase in operating and interest expenses. |
The net income contribution from the wholesale energy operations at SJRG decreased $49.5 million to a net loss of $23.5 million, primarily due to the following:
| ◦ | $32.6 million decrease resulting from an unfavorable court ruling related to a pricing dispute between SJRG and a supplier, including interest (see Note 15 to the consolidated financial statements) |
| ◦ | $20.6 million decrease resulting from the change in unrealized gains and losses on derivatives used by the wholesale energy operations to mitigate natural gas commodity price risk, as discussed under "Operating Revenues - Energy Group" below. |
| ◦ | $5.8 million decrease resulting from a settlement of a legal dispute related to a three-year capacity management contract with a counterparty (see Note 15 to the consolidated financial statements) |
| ◦ | $1.5 million decrease due to legal fees recorded on the two legal disputes noted above |
| ◦ | $5.7 million increase resulting from a favorable FERC decision over a tariff rate dispute with a counterparty, including interest, whereby SJI contended that the counterparty was overcharging for storage demand charges over a ten year period (see Note 15 to the consolidated financial statements). |
| ◦ | $5.3 million increase due to higher margins earned on daily energy trading activities, colder weather conditions experienced in the fourth quarter of 2017 compared to the prior year, additional margins earned during 2017 on gas supply contracts with three electric generation facilities, and an overall decrease in operating expenses (excluding the legal fees discussed above). |
SJI recorded $12.0 million of expenses related to costs incurred on the Acquisition (see Note 1 to the consolidated financial statements). These include finders fees, consulting and legal charges, among others. These costs are recorded in the Corporate & Services segment.
The net income contribution from the retail gas and electric operations at SJE decreased $6.2 million to $1.3 million primarily due to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on retail gas as discussed under "Operating Revenues – Energy Group" below, along with the expiration of a large electric sales contract with a group of school boards.
SJI recorded $13.5 million of tax gains related to the enactment of Tax Reform. See Note 4 to the consolidated financial statements.
The net income contribution from Midstream increased $4.8 million to $4.6 million primarily due to recognition of AFUDC at PennEast, of which Midstream has a 20% equity interest.
The net income contribution from gas utility operations at SJG increased $3.5 million to $72.6 million primarily due to increased margin resulting from investments included in the rate case, AIRP II and SHARP rolling into base rates during the fourth quarter of 2017, along with customer growth. This is partially offset by increases in depreciation, interest and operations expenses.
SJI recognized an additional gain of $1.7 million related to the sale of real estate during 2017.
The types of transactions that typically cause the most significant volatility in operating results are as follows:
The wholesale energy operations at SJRG purchases and holds natural gas in storage and maintains capacity on interstate pipelines to earn profit margins in the future. The wholesale energy operations utilize derivatives to mitigate price risk in order to substantially lock-in the profit margin that will ultimately be realized. However, both gas stored in inventory and pipeline capacity are not considered derivatives and are not subject to fair value accounting. Conversely, the derivatives used to reduce the risk associated with a change in the value of inventory and pipeline capacity are accounted for at fair value, with changes in fair value recorded in operating results in the period of change. As a result, earnings are subject to volatility as the market price of derivatives change, even when the underlying hedged value of inventory and pipeline capacity are unchanged. Additionally, volatility in earnings is created when realized gains and losses on derivatives used to mitigate commodity price risk on expected future purchases of gas injected into storage are recognized in earnings when the derivatives settle, but the cost of the related gas in storage is not recognized in earnings until the period of withdrawal. This volatility can be significant from period to period. Over time, gains or losses on the sale of gas in storage, as well as use of capacity, will be offset by losses or gains on the derivatives, resulting in the realization of the profit margin expected when the transactions were initiated.
The retail electric operations at SJE use forward contracts to mitigate commodity price risk on fixed price electric contracts with customers. In accordance with GAAP, the forward contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. Several related customer contracts are not considered derivatives and, therefore, are not recorded in earnings until the electricity is delivered. As a result, earnings are subject to volatility as the market price of the forward contracts change, even when the underlying hedged value of the customer contract is unchanged. Over time, gains or losses on the sale of the fixed price electric under contract will be offset by losses or gains on the forward contracts, resulting in the realization of the profit margin expected when the transactions were initiated.
As a result, management also uses the non-GAAP financial measures of Economic Earnings and Economic Earnings Per Share when evaluating the results of operations for its operations. These non-GAAP financial measures should not be considered as an alternative to GAAP measures, such as net income, operating income, earnings per share from continuing operations or any other GAAP measure of liquidity or financial performance.
We define Economic Earnings as: Income from continuing operations, (i) less the change in unrealized gains and plus the change in unrealized losses on all derivative transactions; (ii) less realized gains and plus realized losses on all commodity derivative transactions attributed to expected purchases of gas in storage to match the recognition of these gains and losses with the recognition of the related cost of the gas in storage in the period of withdrawal; (iii) less the impact of transactions, contractual arrangements or other events where management believes period to period comparisons of SJI's operations could be difficult or potentially confusing. With respect to part (iii) of the definition of Economic Earnings:
For the year ended December 31, 2018, Economic Earnings excludes impairment charges, including charges taken in 2018 on solar generating facilities (which was primarily driven by the purchase price in the agreement to sell solar assets being less than the carrying amount of the assets) along with LFGTE assets (which was primarily driven by the remaining carrying value of these assets no longer being recoverable. For the year ended December 31, 2017, Economic Earnings excludes impairment charges on solar generating facilities, LFGTE long-lived assets, LFGTE assets customer relationships, and goodwill.
For the years ended December 31, 2018 and 2017, Economic Earnings excludes the impact of a May 2017 jury verdict stemming from a pricing dispute with a gas supplier over costs, including interest charges and legal fees incurred, along with the realized difference in the market value of the commodity (including financial hedges).
For the years ended December 31, 2018 and 2017, Economic Earnings excludes various costs related to the Acquisition, a series of agreements whereby Marina agreed to sell its portfolio of solar energy assets to a third-party buyer, and the agreement to sell the assets of SJE's retail gas business.
For the year ended December 31, 2018, Economic Earnings excludes approximately $15.3 million (pre-tax) of credits to ETG and ELK customers that was required as part of the Acquisition.
For the year ended December 31, 2018, Economic Earnings excludes costs incurred on the Company's ERIP as well as the benefit of amending the Company's OPEB.
For the year ended December 31, 2017, Economic Earnings also excludes the impact of a 2017 settlement of a legal claim stemming from a dispute related to a three-year capacity management contract with a counterparty, including legal fees incurred, along with the impact of a favorable FERC decision over a tariff rate dispute with a counterparty, including interest earned.
For the year ended December 31, 2017, Economic Earnings excludes an approximately $2.4 million pre-tax loss related to a new interest rate derivative and amendments made to an existing interest rate derivative linked to unrealized losses previously recorded in AOCL. SJI reclassified this amount from AOCL to Interest Charges on the consolidated statements of income as a result of the prior hedged transactions being deemed probable of not occurring. Since the economic impact will not be realized until future periods, this amount is excluded from Economic Earnings.
For the year ended December 31, 2017, Economic Earnings excludes the impact of one-time tax adjustments, most notably related to the Tax Reform.
Economic Earnings is a significant performance metric used by our management to indicate the amount and timing of income from continuing operations that we expect to earn after taking into account the impact of derivative instruments on the related transactions, contractual arrangements and other events that management believes make period to period comparisons of SJI's operations difficult or potentially confusing. Specifically regarding derivatives, we believe that this financial measure indicates to investors the profitability of the entire derivative-related transaction and not just the portion that is subject to mark-to-market valuation under GAAP. We believe that considering only the change in market value on the derivative side of the transaction can produce a false sense as to the ultimate profitability of the total transaction as no change in value is reflected for the non-derivative portion of the transaction.
Economic Earnings for 2018 increased $18.1 million, or 18.5%, to $116.2 million compared to 2017. The significant drivers for the overall change were as follows:
The income contribution from the wholesale energy operations at SJRG increased $22.0 million to $43.6 million, primarily due to higher margins on daily energy trading activities and an overall increase in sales due to cold weather experienced in the first quarter of 2018, as discussed under "Gross Margin - Energy Group" below. Also contributing was the impact of Tax Reform, as discussed in Note 1 to the consolidated financial statements.
The income contribution from the gas utility operations at SJG increased $10.3 million to $82.9 million, primarily due to the base rate case settlement, the roll-in of investments for infrastructure replacement and improvement, along with customer growth, partially offset with an overall increase in depreciation, interest and operations expenses.
In connection with the Acquisition, SJI consolidated the results of the ETG and ELK gas utility operations beginning July 2018 (see Note 20 to the consolidated financial statements), contributing net income of $5.8 million for 2018, excluding the customer credits discussed above.
SJI recorded $18.3 million (after-tax) of additional interest charges relating to the debt that was issued during the second quarter of 2018 (see Note 14 to the consolidated financial statements).
Economic Earnings for 2017 decreased $4.8 million, or 4.6%, to $98.1 million compared to 2016. The significant drivers for the overall change were as follows:
The income contribution from on-site energy production at Marina decreased $18.9 million to a net loss of $3.2 million. This was primarily due to the impact of recording no investment tax credits on renewable energy facilities in 2017, compared with $9.1 million in 2016, which is consistent with SJI's previously announced strategy of substantially reducing solar development. Also contributing was $4.5 million for two settlements recorded at Marina during 2016 that did not recur in 2017 (see Note 7 to the consolidated financial statements). The remaining decrease is primarily due to an overall increase in operating and interest expenses.
The income contribution from the retail gas and electric operations at SJE decreased $1.8 million to a net loss of $0.5 million primarily due to the expiration of a large electric sales contract with a group of school boards.
The income contribution from the wholesale energy operations at SJRG increased $5.3 million to $21.6 million, primarily due to higher margins earned on daily energy trading activities, colder weather conditions experienced in the fourth quarter of 2017 compared to the prior year, additional margins earned during 2017 on gas supply contracts with three electric generation facilities, and an overall decrease in operating expenses (excluding the legal fees discussed above).
The income contribution from Midstream increased $4.8 million to $4.6 million primarily due to recognition of AFUDC at PennEast, of which Midstream has a 20% equity interest.
The income contribution from gas utility operations at SJG increased $3.5 million to $72.6 million primarily due to increased margin resulting from investments included in the rate case, AIRP II and SHARP rolling into base rates during the fourth quarter of 2017, along with customer growth. This is partially offset by increases in depreciation, interest and operations expenses.
SJI recognized an additional gain of $1.7 million related to the sale of real estate during 2017.
The following table summarizespresents a reconciliation of our income from continuing operations and earnings per share from continuing operations to Economic Earnings and Economic Earnings per share (in thousands, except per share data):
| 2018 | 2017 | 2016 | |||||||
| Income (Loss) from Continuing Operations | $ | 17,903 | $ | (3,404 | ) | $ | 119,061 | ||
| Minus/Plus: | |||||||||
| Unrealized Mark-to-Market (Gains) Losses on Derivatives | (35,846 | ) | 14,226 | (27,550 | ) | ||||
| Realized Losses on Inventory Injection Hedges | — | 332 | 683 | ||||||
| Loss on Property, Plant and Equipment (A) | 105,280 | 91,299 | — | ||||||
| Net Losses from Legal Proceedings (B) | 5,910 | 56,075 | — | ||||||
| Acquisition/Sale Costs (C) | 34,674 | 19,564 | — | ||||||
| Customer Credits (D) | 15,333 | — | — | ||||||
| ERIP and OPEB (E) | 6,733 | — | — | ||||||
| Other (F) | — | 2,227 | (165 | ) | |||||
| Income Taxes (G) | (33,753 | ) | (70,834 | ) | 10,813 | ||||
| Additional Tax Adjustments (H) | — | (11,420 | ) | — | |||||
| Economic Earnings | $ | 116,234 | $ | 98,065 | $ | 102,842 | |||
| Earnings (Loss) per Share from Continuing Operations | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | ||
| Minus/Plus: | |||||||||
| Unrealized Mark-to-Market (Gains) Losses on Derivatives | (0.42 | ) | 0.18 | (0.36 | ) | ||||
| Realized Losses on Inventory Injection Hedges | — | — | 0.01 | ||||||
| Loss on Property, Plant and Equipment (A) | 1.24 | 1.14 | — | ||||||
| Net Losses from Legal Proceedings (B) | 0.07 | 0.70 | — | ||||||
| Acquisition/Sale Costs (C) | 0.41 | 0.25 | — | ||||||
| Customer Credits (D) | 0.18 | — | — | ||||||
| ERIP and OPEB (E) | 0.08 | — | — | ||||||
| Other (F) | — | 0.03 | — | ||||||
| Income Taxes (G) | (0.39 | ) | (0.89 | ) | 0.13 | ||||
| Additional Tax Adjustments (H) | — | (0.14 | ) | — | |||||
| Economic Earnings per Share | $ | 1.38 | $ | 1.23 | $ | 1.34 | |||
The effect of derivative instruments not designated as hedging instruments under GAAP in the statements of consolidated income (see Note 16 to the consolidated financial statements) is as follows (gains (losses) in thousands):
| 2018 | 2017 | 2016 | |||||||||
| Gains (Losses) on energy-related commodity contracts | $ | 34,509 | $ | (13,667 | ) | $ | 26,935 | ||||
| Gains (Losses) on interest rate contracts | 1,337 | (677 | ) | 647 | |||||||
| Total before income taxes | 35,846 | (14,344 | ) | 27,582 | |||||||
Unrealized mark-to-market gains (losses) on derivatives held by affiliated companies, before taxes | — | 118 | (32 | ) | |||||||
| Total unrealized mark-to-market gains (losses) on derivatives | 35,846 | (14,226 | ) | 27,550 | |||||||
| Realized losses on inventory injection hedges | — | (332 | ) | (683 | ) | ||||||
| Loss on Property, Plant and Equipment (A) | (105,280 | ) | (91,299 | ) | — | ||||||
| Net Losses from Legal Proceedings (B) | (5,910 | ) | (56,075 | ) | — | ||||||
| Acquisition/Sale Costs (C) | (34,674 | ) | (19,564 | ) | — | ||||||
| Customer Credits (D) | (15,333 | ) | — | — | |||||||
| ERIP and OPEB (E) | (6,733 | ) | |||||||||
| Other (F) | — | (2,227 | ) | 165 | |||||||
| Income Taxes (G) | 33,753 | 70,834 | (10,813 | ) | |||||||
| Additional Tax Adjustments (H) | — | 11,420 | — | ||||||||
Total reconciling items between (losses) income from continuing operations and Economic Earnings | $ | (98,331 | ) | $ | (101,469 | ) | $ | 16,219 | |||
(A) Represents impairment charges taken in 2018 on solar generating facilities (which was primarily driven by the purchase price in the agreement to sell solar assets being less than the carrying amount of the assets) along with LFGTE assets (which was primarily driven by the remaining carrying value of these assets no longer being recoverable. Also represents impairment charges taken in 2017 on solar generating facilities, LFGTE long-lived assets, LFGTE assets customer relationships, and goodwill.
(B) Represents net losses from three separate legal proceedings: (a) charges in 2017 and 2018, including interest, legal fees and the realized difference in the market value of the commodity (including financial hedges) resulting from a ruling in a legal proceeding related to a pricing dispute between SJI and a gas supplier that began in October 2014; (b) a charge in 2017, including legal fees, resulting from a settlement with a counterparty over a dispute related to a three-year capacity management contract; and (c) a gain taken in 2017 resulting from a favorable FERC decision, including interest, over a tariff rate dispute with a counterparty, whereby SJI contended that the counterparty was overcharging for storage demand charges over a ten-year period.
(C) Represents costs incurred on the agreement to acquire the assets of ETG and ELK, including legal, consulting and other professional fees. Also included here are costs incurred on the sale of solar and SJE assets, partially offset by gains recorded on the sale of solar assets.
(D) Represents credits to ETG and ELK customers that were required as part of the Acquisition.
(E) Represents costs incurred on the Company's ERIP as well as the benefit of amending the Company's OPEB.
(F) Included in this amount are amendments made to an existing interest rate derivative linked to unrealized losses previously recorded in AOCL. SJI reclassified this amount from AOCL to Interest Charges on the consolidated statements of income as a result of the prior hedged transactions being deemed probable of not occurring. Since the economic impact will not be realized until future periods, this amount is excluded from Economic Earnings. Also included is additional depreciation expense within Economic Earnings on a solar generating facility where an impairment charge was recorded in the past, which reduced the depreciable basis and recurring depreciation expense, and the related reduction in depreciation expense was added back in prior years.
(G) Determined using a combined average statutory tax rate of approximately 25%, 39% and 40% for 2018, 2017 and 2016, respectively.
(H) Represents one-time tax adjustments, most notably for Tax Reform.
SJI Utilities:
SJG Utility Operations - The following tables summarize the composition of selected gasSJG utility dataoperations operating revenues and Utility Margin for the three years ended December 31 (in thousands, except for customer and degree day data):
| 2016 | 2015 | 2014 | ||||||||||||||||||
| Utility Throughput – dth: | ||||||||||||||||||||
| Firm Sales - | ||||||||||||||||||||
| Residential | 22,126 | 15 | % | 23,852 | 17 | % | 24,508 | 18 | % | |||||||||||
| Commercial | 4,956 | 3 | % | 5,980 | 4 | % | 5,530 | 4 | % | |||||||||||
| Industrial | 310 | — | 338 | — | 283 | — | ||||||||||||||
| Cogeneration and electric generation | 1,485 | 1 | % | 1,449 | 1 | % | 1,035 | 1 | % | |||||||||||
| Firm Transportation - | ||||||||||||||||||||
| Residential | 1,975 | 1 | % | 2,427 | 2 | % | 3,291 | 2 | % | |||||||||||
| Commercial | 6,892 | 5 | % | 6,783 | 5 | % | 7,103 | 5 | % | |||||||||||
| Industrial | 11,612 | 8 | % | 11,780 | 9 | % | 13,168 | 10 | % | |||||||||||
| Cogeneration and electric generation | 7,451 | 5 | % | 5,870 | 4 | % | 10,307 | 7 | % | |||||||||||
| Total Firm Throughput | 56,807 | 38 | % | 58,479 | 42 | % | 65,225 | 47 | % | |||||||||||
| Interruptible Sales | 2 | — | 20 | — | — | — | ||||||||||||||
| Interruptible Transportation | 1,149 | 1 | % | 1,338 | 1 | % | 1,401 | 1 | % | |||||||||||
| Off-System | 16,526 | 11 | % | 14,603 | 11 | % | 9,411 | 7 | % | |||||||||||
| Capacity Release | 73,913 | 50 | % | 62,349 | 46 | % | 62,193 | 45 | % | |||||||||||
| Total Utility Throughput | 148,397 | 100 | % | 136,789 | 100 | % | 138,230 | 100 | % | |||||||||||
| Utility Operating Revenues: | ||||||||||||||||||||
| Firm Sales- | ||||||||||||||||||||
| Residential | $ | 259,881 | 56 | % | $ | 317,491 | 59 | % | $ | 279,797 | 56 | % | ||||||||
| Commercial | 55,795 | 12 | % | 69,845 | 13 | % | 63,584 | 13 | % | |||||||||||
| Industrial | 3,126 | 1 | % | 4,083 | 1 | % | 4,070 | 1 | % | |||||||||||
| Cogeneration and electric generation | 5,257 | 1 | % | 5,666 | 1 | % | 6,037 | 1 | % | |||||||||||
| Firm Transportation - | ||||||||||||||||||||
| Residential | 14,989 | 3 | % | 16,594 | 3 | % | 20,648 | 4 | % | |||||||||||
| Commercial | 32,423 | 7 | % | 30,602 | 6 | % | 30,850 | 6 | % | |||||||||||
| Industrial | 19,594 | 4 | % | 22,106 | 4 | % | 25,737 | 5 | % | |||||||||||
| Cogeneration and electric generation | 4,472 | 1 | % | 4,920 | 1 | % | 9,531 | 2 | % | |||||||||||
| Total Firm Revenues | 395,537 | 85 | % | 471,307 | 88 | % | 440,254 | 88 | % | |||||||||||
| Interruptible Sales | 18 | — | 300 | — | 15 | — | ||||||||||||||
| Interruptible Transportation | 928 | — | 1,373 | — | 1,694 | — | ||||||||||||||
| Off-System | 51,661 | 11 | % | 49,624 | 9 | % | 52,809 | 11 | % | |||||||||||
| Capacity Release | 11,778 | 3 | % | 10,296 | 2 | % | 5,835 | 1 | % | |||||||||||
| Other | 1,133 | 1 | % | 1,390 | 1 | % | 1,268 | — | ||||||||||||
| Total Utility Operating Revenues | 461,055 | 100 | % | 534,290 | 100 | % | 501,875 | 100 | % | |||||||||||
| Less: | ||||||||||||||||||||
| Cost of sales | 174,390 | 245,290 | 231,216 | |||||||||||||||||
| Conservation recoveries * | 9,202 | 21,226 | 24,836 | |||||||||||||||||
| RAC recoveries * | 9,326 | 9,134 | 8,255 | |||||||||||||||||
| EET Recoveries * | 2,718 | 3,611 | 4,169 | |||||||||||||||||
| Revenue taxes | 1,109 | 1,250 | 1,141 | |||||||||||||||||
| Utility Margin ** | $ | 264,310 | $ | 253,779 | $ | 232,258 | ||||||||||||||
| Utility Margin: | ||||||||||||||||||||
| Residential | $ | 162,820 | 62 | % | $ | 169,455 | 67 | % | $ | 159,780 | 69 | % | ||||||||
| Commercial and industrial | 69,396 | 26 | % | 72,149 | 28 | % | 65,492 | 29 | % | |||||||||||
| Cogeneration and electric generation | 4,898 | 2 | % | 4,738 | 2 | % | 5,343 | 2 | % | |||||||||||
| Interruptible | 79 | — | 120 | — | 81 | — | ||||||||||||||
| Off-system & capacity release | 4,731 | 2 | % | 4,270 | 2 | % | 3,023 | 1 | % | |||||||||||
| Other revenues | 2,213 | 1 | % | 2,582 | 1 | % | 2,131 | 1 | % | |||||||||||
| Margin before incentive mechanisms | 244,137 | 93 | % | 253,314 | 100 | % | 235,850 | 102 | % | |||||||||||
| CIP mechanism | 16,615 | 6 | % | (1,798 | ) | (1 | )% | (4,529 | ) | (2 | )% | |||||||||
| EET mechanism | 3,558 | 1 | % | 2,263 | 1 | % | 937 | — | ||||||||||||
| Utility Margin ** | $ | 264,310 | 100 | % | $ | 253,779 | 100 | % | $ | 232,258 | 100 | % | ||||||||
| Number of Customers at Year End: | ||||||||||||||||||||
| Residential | 352,427 | 93 | % | 348,093 | 93 | % | 342,155 | 93 | % | |||||||||||
| Commercial | 24,767 | 7 | % | 24,565 | 7 | % | 24,253 | 7 | % | |||||||||||
| Industrial | 431 | — | 442 | — | 446 | — | ||||||||||||||
| Total Customers | 377,625 | 100 | % | 373,100 | 100 | % | 366,854 | 100 | % | |||||||||||
| Annual Degree-Days*** | 4,292 | 4,402 | 4,872 | |||||||||||||||||
| December 31, 2018 | December 31, 2017 | December 31, 2016 | ||||||||||||||||||
| Utility Operating Revenues: | ||||||||||||||||||||
| Firm Sales- | ||||||||||||||||||||
| Residential | $ | 316,593 | 58 | % | $ | 269,721 | 52 | % | $ | 259,881 | 56 | % | ||||||||
| Commercial | 68,286 | 13 | % | 61,514 | 12 | % | 55,795 | 12 | % | |||||||||||
| Industrial | 4,630 | 1 | % | 4,235 | 1 | % | 3,126 | 1 | % | |||||||||||
| Cogeneration and Electric Generation | 9,706 | 2 | % | 5,519 | 1 | % | 5,257 | 1 | % | |||||||||||
| Firm Transportation - | ||||||||||||||||||||
| Residential | 12,614 | 2 | % | 14,162 | 3 | % | 14,989 | 3 | % | |||||||||||
| Commercial | 37,764 | 7 | % | 34,986 | 7 | % | 32,423 | 7 | % | |||||||||||
| Industrial | 23,993 | 4 | % | 20,576 | 4 | % | 19,594 | 4 | % | |||||||||||
| Cogeneration and Electric Generation | 4,595 | 1 | % | 4,360 | 1 | % | 4,472 | 1 | % | |||||||||||
| Total Firm Revenues | 478,181 | 88 | % | 415,073 | 81 | % | 395,537 | 85 | % | |||||||||||
| Interruptible Sales | 349 | — | 25 | — | 18 | — | ||||||||||||||
| Interruptible Transportation | 1,178 | — | 867 | — | 928 | — | ||||||||||||||
| Off-System Sales | 59,157 | 11 | % | 92,376 | 18 | % | 51,661 | 11 | % | |||||||||||
| Capacity Release | 7,963 | 1 | % | 7,695 | 1 | % | 11,778 | 3 | % | |||||||||||
| Other | 1,172 | — | % | 1,218 | — | % | 1,133 | 1 | % | |||||||||||
| 548,000 | 100 | % | 517,254 | 100 | % | 461,055 | 100 | % | ||||||||||||
| Less: Intercompany Sales | 6,192 | 4,772 | 7,236 | |||||||||||||||||
| Total Utility Operating Revenues | 541,808 | 512,482 | 453,819 | |||||||||||||||||
| Less: | ||||||||||||||||||||
| Cost of Sales - Utility | 209,649 | 204,432 | 174,390 | |||||||||||||||||
| Less: Intercompany Cost of Sales | 6,192 | 4,772 | 7,236 | |||||||||||||||||
| Total Cost of Sales - Utility (Excluding Depreciation) | 203,457 | 199,660 | 167,154 | |||||||||||||||||
| Conservation Recoveries * | 14,136 | 7,003 | 9,202 | |||||||||||||||||
| RAC recoveries * | 17,099 | 11,014 | 9,326 | |||||||||||||||||
| EET Recoveries* | 1,772 | 1,284 | 2,718 | |||||||||||||||||
| Revenue Taxes | 1,074 | 1,162 | 1,109 | |||||||||||||||||
| Utility Margin** | $ | 304,270 | $ | 292,359 | $ | 264,310 | ||||||||||||||
| Utility Margin: | ||||||||||||||||||||
| Residential | $ | 213,026 | 70 | % | $ | 180,106 | 62 | % | $ | 162,820 | 62 | % | ||||||||
| Commercial and Industrial | 89,172 | 29 | % | 76,491 | 26 | % | 69,396 | 26 | % | |||||||||||
| Cogeneration and Electric Generation | 4,975 | 1 | % | 4,762 | 1 | % | 4,898 | 2 | % | |||||||||||
| Interruptible | 105 | — | 63 | — | 79 | — | ||||||||||||||
| Off-system Sales & Capacity Release | 4,434 | 2 | % | 5,051 | 2 | % | 4,731 | 2 | % | |||||||||||
| Other Revenues | 1,942 | 1 | % | 2,107 | 1 | % | 2,213 | 1 | % | |||||||||||
| Margin Before Weather Normalization & Decoupling | 313,654 | 103 | % | 268,580 | 92 | % | 244,137 | 93 | % | |||||||||||
| CIP mechanism | (12,382 | ) | (4 | )% | 20,062 | 7 | % | 16,615 | 6 | % | ||||||||||
| EET mechanism | 2,998 | 1 | % | 3,717 | 1 | % | 3,558 | 1 | % | |||||||||||
| Utility Margin** | $ | 304,270 | 100 | % | $ | 292,359 | 100 | % | $ | 264,310 | 100 | % | ||||||||
* Represents expenses for which there is a corresponding credit in operating revenues. Therefore, such recoveries have no impact on ourSJG's financial results.
** Utility Margin is a non-GAAP financial measure and is further defined under the caption "Margin (pre-tax)""Utility Margin" below.
The main driver for the increased revenue was higher firm sales. Total gas throughput decreased 1.5 MMdts,firm revenue increased $63.1 million, or 1.0%15.2%, from 2014 to 2015 due to lower throughput in the firm markets. Residential firm sales and transportation throughput decreased by 1.4 MMdtsfor 2018 compared with 2017 as a result of colder weather that was 9.6% warmer than prior year, however, the largest decline inand additional customers. Additionally, firm throughput was experienced in cogeneration transportation, as reflected under “Firm Transportation - Cogeneration and electric generation” in the Throughput table above. Supply disruptions at a cogeneration facility in our territory during 2014 created opportunity for SJG. That customer was being supplied directly by an interstate pipeline. However, with the disruption, SJG had transported a significant volume of commodity to this cogeneration facility to meet its needs in 2014. That disruption has since been remedied, resulting in lower firm transportation throughput in 2015. Partially offsetting these decreases was a 5.2 MMdts increase in OSS throughput from 2014 to 2015. This was primarilysales increased due to warmer than normal weather, which created less demand in the Company’s service territory and more supply available for OSS.
Partially offsetting these increases was the impact of OSS volume, discussed under "Throughput - Gas Utility Operations" below, which resulted in corresponding decreases of $33.2 million, or 36.0%, in OSS revenues for 2018 compared with 2017. However, the impact of changes in OSS and capacity release activity do not have a material impact on the earnings of SJG, as SJG is required to return 85% of the profits of such activity to its ratepayers. Earnings from OSS can be seen in the “Margin” table above.
Operating Revenues - SJG Utility Operations 2017 vs. 2016 - Revenues increased $56.2 million, or 12.2%, during 2017 compared with 2016. Excluding intercompany transactions, revenues increased $58.7 million, or 12.9%, during 2017 compared with 2016. The main driver for the increased revenue is higher firm sales and OSS. Total firm revenue increased $19.5 million, or 4.9%, in 2017 compared with 2016 as a result of 6,008 additional customers compared with 2016. Additionally, firm sales increased due to base rate increases related to the settlement of SJG’sSJG's base rate case, added $15.5 millioneffective November 1, 2017, as discussed in Note 10 to the consolidated financial statements. While changes in gas costs and BGSS recoveries/refunds fluctuate from period to period, SJG does not profit from the sale of incremental revenue to 2015, compared with 2014. The additionthe commodity. Therefore, corresponding fluctuations in Operating Revenue or Cost of 6,246 additional customers in 2015 also contributed to higher firm revenue; however,Sales have no impact on SJG profitability, as further discussed below under the impact of 9.6% warmer weather more than offset the impact of customer growth during the year.caption "Utility Margin." While warmer weather decreased firm sales volume and revenue, the revenue decrease has little impact on CompanySJG profitability under the operation of the CIP, as discussed below under the caption "Margin (pre-tax)."Utility Margin."
Higher OSS volumes and higher unit prices resulted in a $40.7 million, or 78.8%, increase in OSS revenues during 2017 compared with 2016. The impact of changes in OSS activity does not have a material impact on the earnings of SJG, as SJG is required to return 85% of the profits of such activity to its ratepayers.
Utility Margin (pre-tax)- SJG Utility Operations 2018 vs. 2017 - Our marginManagement uses Utility Margin, a non-GAAP financial measure, when evaluating the operating results of SJG. Utility Margin is defined as natural gas revenues less natural gas costs;costs, regulatory rider expenses and related volumetric and revenue basedrevenue-based energy taxes; and regulatory rider expenses. We believetaxes. Management believes that marginUtility Margin provides a more meaningful basis for evaluating utility operations than revenues since natural gas costs, energy taxes and regulatory rider expenses and related energy taxes are passed through to customers, and, therefore, have no effect on our profitability.customers. Natural gas costs are charged to operating expenses on the basis of therm sales at the prices approved by the BPU through ourSJG’s BGSS tariff.clause. 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 CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. As reflected in the marginUtility Margin table above and the CIP table above,in SJG's Management Discussion section, the CIP mechanism protected $16.6reduced Utility Margin by $12.4 million or $9.9$9.0 million after taxes, for the twelve months ended December 31, 2018, primarily due to the weather that was 7% colder than average and variation in customer usage.
Utility Margin - SJG Utility Operations 2017 vs. 2016 - Utility Margin increased $28.0 million, or 10.6%, during 2017 compared with 2016. The rolling into base rates of SHARP and AIRP II investments of approximately $187.5 million contributed approximately $14.2 million of additional Utility Margin in 2017. In addition, the rolling into base rates of certain infrastructure and system improvement investments and the related expenses, effective November 1, 2017, contributed approximately $10.8 million of additional Utility Margin in 2017. Net customer additions of 6,008 over the twelve-month period ended December 31, 2017, representing 1.6% growth over the prior year, contributed approximately $2.4 million in additional Utility Margin.
The CIP mechanism protected $20.1 million, or $12.0 million after taxes, during 2016,2017, due to weather that was 8.1%11.5% warmer than average and customer usage variations.
ETG Utility Operations:
The CIP mechanism reducedfollowing tables summarize the composition of regulated natural gas utility operations, operating revenues and margin by $1.8at ETG for the period since Acquisition, which is July 1, 2018 through December 31, 2018 (in thousands, except for degree day data).
| Utility Operating Revenues: | |||
| Firm & Interruptible Sales - | |||
| Residential | $ | 80,215 | |
| Commercial & Industrial | 26,784 | ||
| Firm & Interruptible Transportation - | |||
| Residential | 508 | ||
| Commercial & Industrial | 15,148 | ||
| Other | 2,949 | ||
| Total Firm & Interruptible Revenues | 125,604 | ||
| Less: | |||
| Total Cost of Sales - Utility (Excluding depreciation) | 53,491 | ||
| Regulatory Rider Expenses* | 2,068 | ||
| Utility Margin** | $ | 70,045 | |
| Utility Margin: | |||
| Residential | $ | 43,293 | |
| Commercial & Industrial | 26,034 | ||
| Regulatory Rider Expenses* | 718 | ||
| Utility Margin** | $ | 70,045 | |
| Degree Days | 1,724 | ||
*Represents expenses for which there is a corresponding credit in operating revenues. Therefore, such recoveries have no impact on ETG's financial results.
**Utility Margin is a non-GAAP financial measure and is further defined under the caption "Utility Margin" above. The definition of Utility Margin is the same for SJG, ETG and ELK utility operations.
Since ETG was acquired on July 1, 2018, there is no activity for the prior year period. ETG consists of natural gas distribution to residential, commercial and industrial customers in northern and central New Jersey. ETG's operating revenues of $125.6 million for the year ended December 31, 2018 consists of firm sales and transportation, as well as interruptible sales and transportation. ETG does not have any off-system sales. The Utility Margin at ETG of $70.0 million is considered a non-GAAP measure and calculated the same as SJG as discussed under "Utility Margin" above.
ELK Utility Operations - The activities of ELK utility operations are not material to SJI's financial results.
Operating Revenues - Energy Group 2018 vs. 2017 - Combined revenues for Energy Group, net of intercompany transactions, increased $272.2 million, or $1.043.0%, to $904.8 million, after taxes, during 2015,in 2018 compared with 2017. The significant drivers for the overall change were as follows:
Revenues from wholesale energy operations at SJRG, net of intercompany transactions, increased $283.2 million to $634.8 million for 2018 compared with 2017. This increase was primarily due to an overall increase in sales due to cold weather experienced in the first quarter of 2018, along with revenues earned on gas supply contracts with electric generation facilities, including three that began operations in late 2017 or in the first quarter of 2018. Also contributing to the overall comparative period increase was the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total increase of $50.2 million in 2018 compared with 2017.
Revenues from retail gas operations at SJE, net of intercompany transactions, decreased $10.0 million, or 9.2%, to $98.6 million for 2018 compared with 2017 primarily due to the agreement entered into in the fourth quarter of 2018 to sell the retail gas operations at SJE to a third party (see Note 1 to the consolidated financial statements). Also contributing to the comparative period decrease was the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $2.7 million in 2018 compared with 2017. Partially offsetting these decreases was an increase in sales volumes due to cold weather experienced during the first quarter of 2018.
Revenues from retail electric operations at SJE, net of intercompany transactions, decreased $0.9 million, or 0.5%, to $171.2 million for 2018 compared with 2017, primarily due to lower sales volumes in the first two quarters of 2018 resulting from the expiration in the second quarter of 2017 of a large electric sales contract with a group of school boards. Also contributing to the comparative period decrease was the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $2.4 million in 2018 compared with 2017. Partially offsetting these decreases was a higher average LMP per megawatt hour in 2018 compared with 2017.
SJE uses forward financial contracts to mitigate commodity price risk on fixed price electric contracts. In accordance with GAAP, the forward financial contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. The related customer usage variations.contracts are not considered derivatives and, therefore, are not recorded in earnings until the electricity is delivered. As a result, earnings are subject to volatility as the market price of the forward financial contracts change, even when the underlying hedged value of the customer contract is unchanged. Over time, gains or losses on the sale of the fixed price electric under contract will be offset by losses or gains on the forward financial contracts, resulting in the realization of the profit margin expected when the transactions were initiated. The CIP mechanism reduced marginretail electric operations at SJE serve both fixed and market-priced customers.
Operating Revenues - Energy Services 2018 vs. 2017 - Combined revenues for Energy Services, net of intercompany transactions, decreased $32.1 million, or 32.8%, to $65.9 million in 2018 compared with 2017. The significant drivers for the overall change were as follows:
Revenues from on-site energy production at Marina, net of intercompany transactions, decreased $27.6 million, or 30.1%, to$63.9 million in 2018 compared with 2017, primarily due to a lack of SREC revenue in the second half 2018 as a result of the sale of solar assets to a third party buyer (see Note 1 to the consolidated financial statements). This was partially offset by increased production at the thermal facility.
Revenues from appliance service operations at SJESP, net of intercompany transactions, decreased $4.5 million, or $2.769.8%, to$1.9 million after taxes, during 2014,for 2018 compared with 2017 primarily due to weather thatthe sale of certain assets of SJESP's residential and small commercial HVAC and plumbing business to a third party, which was colder than normal.completed on September 1, 2017.
Operating Revenues - Energy Group 2017 vs. 2016 - Combined revenues for Energy Group, net of intercompany transactions, increased $147.2 million, or 30.3%, to $632.6 million in 2017 compared with 2016. The significant drivers for the overall change were as follows:
Revenues from retail gas operations at SJE, net of intercompany transactions, increased $18.0 million, or 19.9%, to $108.7 million in 2017 compared with 2016, primarily due to a 26.3% increase in the average monthly NYMEX settle price, along with a 19.3% increase in sales volumes driven by additional contracts entered into in 2017. This was partially offset with the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings, as defined above, and represented a total decrease of $6.3 million compared to the prior year period.
Revenues from retail electric operations at SJE, net of intercompany transactions, decreased $2.8 million, or 1.6%, to $172.1 million in 2017 compared with 2016 primarily due to the expiration of a large contract with a group of school boards. Also contributing to this decrease was the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $0.8 million compared to the prior year period.
Revenues from wholesale energy operations at SJRG, net of intercompany transactions, increased $131.7 million to $351.6 million in 2017 compared with 2016. This increase was primarily due to revenues earned on gas supply contracts with three electric generation facilities, which represented a total increase of $168.1 million. Partially offsetting this increase was the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $33.5 million in 2017 compared with 2016.
Operating ExpensesRevenues - Energy Services 2017 vs. 2016 - Combined revenues for Energy Services, net of intercompany transactions, increased $0.7 million, or 0.7%, to $98.0 million in 2017 compared with 2016. The significant drivers for the overall change were as follows:
Revenues from on-site energy production at Marina, net of intercompany transactions, increased $2.1 million, or 2.4%, to $91.5 million in 2017 compared with 2016, primarily due to an increase in SRECs transferred as a result of more solar projects being online compared with 2016. Solar revenues, net of intercompany transactions, which is included in revenues from on-site energy production above, increased $1.3 million, or 2.4%, to $56.5 million in 2017 compared with 2016.
SRECs represent the renewable energy attribute of the solar electricity generated that can be sold to customers. Marina does not recognize revenue, or the related margin, until the SREC is certified and transferred to the customer’s electronic account. Customers may purchase SRECs to comply with solar requirements under various state renewable energy regulations. Approximately 73% of Marina’s 2017 solar production is in New Jersey, 9% is in Massachusetts, 15% is in Maryland, and 3% is in Vermont.
Marina hedges a portion of its anticipated SREC production through the use of forward sales contracts. The hedged percentage of projected SREC production related to in-service assets in New Jersey is 93% and 68% for energy years ending May 31, 2018 and 2019, respectively, and in Massachusetts is 54% for energy year ending December 31, 2018. SREC production related to in-service assets in Maryland and Vermont is currently unhedged.
Installed capacity was 201 MW and 198 MW at December 31, 2017 and 2016, respectively.
Revenues from appliance service operations at SJESP, net of intercompany transactions, decreased $1.4 million in 2017 compared with 2016 primarily due to the sale of certain assets of SJESP's residential and small commercial HVAC and plumbing business to a third party, which was completed on September 1, 2017 (see Note 1 to the consolidated financial statements).
Gross Margin - Nonutility - Gross margin for the nonutility businesses is defined as revenue less all costs that are directly related to the production, sale and delivery of SJI's products and services. These costs primarily include natural gas and electric commodity costs as well as certain payroll and related benefits. On the statements of consolidated income, revenue is reflected in Operating Revenues - Nonutility and the costs are reflected in Cost of Sales - Nonutility. As discussed in Note 1 to the consolidated financial statements, revenues and expenses related to the energy trading activities of the wholesale energy operations at SJRG are presented on a net basis in Operating Revenues - Nonutility on the statements of consolidated income.
Gross margin for our nonutility business totaled $174.1 million and $84.0 million for 2018 and 2017, respectively. Gross margin is broken out between Energy Group and Energy Services, which are defined as categories of segments in Note 8 to the consolidated financial statements.
Gross Margin - Energy Group 2018 vs. 2017 - Combined gross margins for Energy Group increased $115.8 million to $108.8 million for 2018 compared with 2017. The significant drivers for the overall change were as follows:
Gross margin from the wholesale energy operations at SJRG increased $122.9 million to $100.8 million for 2018 compared to 2017. The significant drivers for the overall change were as follows:
$50.2 million increase resulting from the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings.
$38.7 million reduction in charges compared to the prior year recorded on a pricing dispute between SJI and a gas supplier (see Note 15 to the consolidated financial statements), along with two other settled cases (see 2017 vs. 2016 discussion below).
The remaining increase is primarily due to higher margins on daily energy trading activities and an overall increase in sales due to cold weather experienced in the first quarter of 2018.
The wholesale energy operations at SJRG expect to continue to add incremental margin from marketing and related opportunities in the Marcellus region, capitalizing on its established presence in the area. Future margins could fluctuate significantly due to the volatile nature of wholesale gas prices. As of December 31, 2018, the wholesale energy operations had 8.6 MMdts of storage and 566,989 dts/day of transportation under contract.
Gross margin from SJE’s retail gas and other operations decreased $2.7 million to $4.7 million for 2018 compared with 2017, primarily due to the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $2.7 million in 2018 compared with 2017.
Gross margin from SJE’s retail electric operations decreased $4.3 million to $3.2 million in 2018 compared with 2017, primarily due to lower sales volumes in the first two quarters of 2018 resulting from the expiration in the second quarter of 2017 of a large electric sales contract with a group of school boards. Also contributing to the comparative period decrease was the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $2.4 million in 2018 compared with 2017.
Gross Margin - Energy Services 2018 vs. 2017 - Combined gross margins for Energy Services decreased $25.6 million to $65.3 million for 2018 compared with 2017. The significant drivers for the overall change were as follows:
Gross margin from on-site energy production at Marina decreased $24.8 million to $63.3 million in 2018 compared with 2017, primarily due to the sale of certain SREC's (see Note 1 to the consolidated financial statements).
Gross margin from appliance service operations at SJESP decreased $0.8 million to $1.9 million in 2018 compared with 2017, primarily due to the impact of the sale of certain assets of SJESP's residential and small commercial HVAC and plumbing business to a third party, which was completed on September 1, 2017.
Gross Margin - Energy Group 2017 vs. 2016 - For 2017, combined gross margins for Energy Group decreased $87.6 million to a loss of $6.9 million compared with 2016. The significant drivers for the overall change were as follows:
Gross margin from SJE’s retail gas and other operations decreased $6.0 million to $7.5 million in 2017 compared with 2016. This was primarily due to the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $6.3 million in 2017 compared with 2016.
Gross margin from SJE’s retail electric operations decreased $3.0 million to $7.5 million in 2017 compared with 2016. This decrease was primarily due to lower sales volumes resulting from the expiration of a large contract with a group of school boards, along with the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings and represented a total decrease of $0.8 million.
Gross margin from the wholesale energy operations at SJRG decreased $78.8 million to a loss of $22.1 million in 2017 compared with 2016. The significant drivers for the overall change were as follows:
$49.6 million decrease resulting from an unfavorable court ruling related to a pricing dispute between SJRG and a supplier (see Note 15 to the consolidated financial statements), which is excluded for Economic Earnings.
$33.5 million decrease resulting from the change in unrealized gains and losses recorded on forward financial contracts due to price volatility, which is excluded for Economic Earnings.
$9.5 million decrease resulting from a settlement of a legal dispute related to a three-year capacity management contract, which is excluded for Economic Earnings.
$7.4 million increase resulting from favorable FERC decision over a tariff rate dispute with a counterparty, whereby SJI contended that the counterparty was overcharging for storage demand charges over a ten year period, which is excluded for Economic Earnings.
The remaining $6.4 million increase resulted from higher margins earned on daily energy trading activities, colder weather conditions in the fourth quarter of 2017, and additional margins earned during 2017 on gas supply contracts with three electric generation facilities.
The wholesale energy operations at SJRG expect to continue to add incremental margin from marketing and related opportunities in the Marcellus region, capitalizing on its established presence in the area. Future margins could fluctuate significantly due to the volatile nature of wholesale gas prices. As of December 31, 2017, the wholesale energy operations had 8.7 MMdts of storage and 584,254 dts/day of firm transportation under contract.
Gross Margin - Energy Services 2017 vs. 2016 - For 2017, combined gross margins for Energy Services increased $2.8 million to $90.9 million compared with 2016. The significant drivers for the overall change were as follows:
Gross margin from on-site energy production at Marina increased $4.1 million to $88.2 million in 2017 compared with 2016, primarily due to an increase in SRECs transferred as a result of more solar projects being online compared to the same period in 2016, along with better production.
Gross margin from appliance service operations at SJESP decreased $1.4 million in 2017 compared with 2016 primarily due to the sale of certain assets of SJESP's residential and small commercial HVAC and plumbing business to a third party, which was completed on September 1, 2017 (see Note 1 to the consolidated financial statements).
Operations Expense - All Segments - A summary of net changes in other operating expensesoperations expense follows (in thousands):
| 2016 vs. 2015 | 2015 vs. 2014 | ||||||
| Operations | $ | (12,227 | ) | $ | 5,408 | ||
| Maintenance | $ | 1,366 | $ | 2,726 | |||
| Depreciation | $ | 6,067 | $ | 4,041 | |||
| Energy and Other Taxes | $ | (411 | ) | $ | 271 | ||
| 2018 vs. 2017 | 2017 vs. 2016 | |||||
| SJI Utilities: | ||||||
| SJG Utility Operations | $ | 16,316 | $ | 3,592 | ||
| ETG Utility Operations | 52,070 | — | ||||
| ELK Utility Operations | 1,218 | — | ||||
| Subtotal SJI Utilities | 69,604 | 3,592 | ||||
| Nonutility: | ||||||
| Energy Group: | ||||||
| Wholesale Energy Operations | (1,560 | ) | (130 | ) | ||
| Retail Gas and Other Operations | 1,705 | 1,221 | ||||
| Retail Electric Operations | (452 | ) | 273 | |||
| Subtotal Energy Group | (307 | ) | 1,364 | |||
| Energy Services: | ||||||
| On-Site Energy Production | 9,432 | 5,918 | ||||
| Appliance Service Operations | (2,227 | ) | (928 | ) | ||
| Subtotal Energy Services | 7,205 | 4,990 | ||||
| Total Nonutility | 6,898 | 6,354 | ||||
| Midstream | 291 | — | ||||
| Corporate & Services and Intercompany Eliminations | 10,302 | 12,765 | ||||
| Total Operations Expense | $ | 87,095 | $ | 22,711 | ||
Operations –- In connection with the Acquisition, SJI consolidated the accounts of ETG and ELK utility operations beginning July 1, 2018 (see Note 20 to the consolidated financial statements), contributing an increase to Operations expense decreased $12.2 million during 2016, as compared with 2015. The decrease is primarily comprisedExpenses of the following:$53.3 million.
SJG utility operations expense increased $3.6 million in 2017 compared with 2016. The increase was primarily due to higher corporate support, governance and compliance costs, higher compensation costs and higher costs related to the operation of SJG's compressed natural gas stations. The increases were partially offset by a decrease associated with the New Jersey Clean Energy Program and Energy Efficiency Programs which experienced net decreases of $12.9 million in 2016, compared with 2015. Such costs are recovered on a dollar-for-dollar basis; therefore, SJG experiences an offsetting decrease in revenue during 2016. This was due to a reduction in the approved level of recovery of such costs, as well as lower recoveries resulting from warmer weather as previously discussed under “Throughput.”
Nonutility operations expense increased $6.9 million in 2018 compared with 2017. This increase is primarily due to costs incurred in the first half of 2018 at the on-site energy production segment to enter into a series of agreements whereby Marina is selling its portfolio of solar energy assets to a third-party buyer, along with costs incurred to enter into the sale of SJE's retail gas business (see Note 1 to the consolidated financial statements). These increases were partially offset with lower legal fees incurred at the wholesale energy operations at SJRG from an unfavorable court ruling related to a pricing dispute between SJRG and a supplier (see Note 15 to the consolidated financial statements), along with a reduction at the appliance service operations at SJESP due to the sale of certain assets of SJESP's residential and small commercial HVAC and plumbing business to a third party, which was completed on September 1, 2017.
Nonutility operations expense increased $6.4 million in 2017 compared with 2016, primarily due to additional personnel, governance and compliance costs incurred to support continued growth.
The Corporate & Services segment had a $10.3 million increase in 2018 compared with 2017, and a $12.8 million increase in 2017 compared with 2016, in total operations expense primarily due to costs incurred on the Acquisition (see Note 1 to the consolidated financial statements). These include finders fees, consulting and legal charges, among others. These increases were partially offset by intercompany eliminations. Also contributing to the 2018 increase were costs associated with the ERIP.
Other Operating Expenses - All Segments - A summary of changes in other consolidated operating expenses (in thousands):
| 2018 vs. 2017 | 2017 vs. 2016 | |||||
| Impairment Charges | $ | 13,981 | $ | 91,299 | ||
| Maintenance | $ | 12,435 | $ | 2,178 | ||
| Depreciation | $ | (3,995 | ) | $ | 10,329 | |
| Energy and Other Taxes | $ | 3,050 | $ | 145 | ||
Impairment Charges - Marina incurred approximately $105.3 million of impairment charges on solar generating facilities and LFGTE assets in 2018, which were driven by the purchase price in the agreement to sell solar assets being less than the carrying amount of the assets, along with the carrying value of LFGTE assets no longer being recoverable (see Note 1 to the consolidated financial statements). Marina incurred approximately $91.3 million of non-cash impairment charges during 2017, including impairments on solar generating facilities, LFGTE long-lived assets, LFGTE assets customer relationships, and goodwill (see Note 1 to the consolidated financial statements). These impairment charges were recorded in the On-Site Energy Production segment.
Maintenance Expense –- Maintenance expense increased $1.4$12.4 million during 2016,in 2018 compared with 2015,2017, of which ETG and ELK contributed $3.4 million. The remaining increase was primarily due to increased field activity related to the maintenance of services.
Depreciation Expense - Depreciation expense decreased $4.0 million in Remediation Adjustment Clause (RAC)2018 compared with 2017 primarily due to reduced depreciation expense amortization of $0.9 million over 2014, primarilyat Marina as a result of increased spending on environmental remediation in recent years. As discussed in Notes 3 and 4the solar assets being classified as held for sale (see Note 1 to the consolidated financial statements, RAC costs are recovered from ratepayers; therefore, SJG experienced anstatements), along with impairment charges taken on solar generating facilities and LFGTE assets in 2018. Partially offsetting changethis decrease is the impact of ETG and ELK, along with increased investment in revenue during 2015. Also contributing toproperty, plant and equipment by the increase in maintenance expense was higher distributiongas utility operations expense. Such expensesof SJG. Depreciation increased $1.1$10.3 million in 2015,2017 compared with 2014, as a result of2016 primarily due to increased field activity related to the maintenance of services.
Energy and Other Taxes – Energy- The change in energy and Other Taxes decreased $0.4 million during 2016,other taxes in 2018 compared with 2015, primarily duethe prior year was attributable to lower revenue-basedthe addition of ETG/ELK. The change in energy and other taxes which decreased as a result of lower revenue during 2016, as previously discussed under “Operating Revenues” above. Changes in Energy and Other Taxes in 2015,2017 compared with 2014, werethe prior year was not significant.
Net Gain on Sales of Assets - In the fourth quarter 2018, the Company recognized net gains on the sale of assets of $15.4 million, which includes gains on the sale of solar assets of $17.6 million, partially offset with a loss incurred on the sale of the retail gas operations at SJE of $2.2 million. See Note 1 to the consolidated financial statements.
Other Income and Expense - Changes in Other income and expense during 2016,decreased $8.6 million in 2018 compared with 2015, were not significant. Other income and expense was $1.7 million lower in 2015, compared to 2014,2017 primarily due to poor financial market performancea gain recorded on a sale of real estate during the latter partfirst quarter of the year. In 2015, SJG realized2017, as well as interest income earned in 2017 from a lossfavorable FERC decision over a tariff rate dispute at SJRG, neither of $0.3 million on its available-for-sale securities, compared to a realized gain of $0.9which recurred in 2018. Other income increased $6.0 million in 2014. Also adding2017 compared with 2016 primarily due to Other Incomehigher AFUDC due to increased capital spending and a new AIRP II program at SJG, a gain recorded on a sale of real estate during the first quarter of 2017, as well as interest income earned from a favorable FERC decision over a tariff rate dispute at SJRG (see Note 15 to the consolidated financial statements). These were partially offset by a settlement at Marina during the second quarter of 2016 as discussed in 2014 was a higher allowance for equity funds used during construction asNote 7 to the Company made significant investment in new technology systems. As those investments in systems grew from 2013 to 2014, so did the resulting income. However, once placed in service in the latter part of 2014, such income ceased.consolidated financial statements.
Interest Charges –- Interest charges decreased $2.0increased $36.3 million in 2016,2018 compared with 2015,2017 primarily due to interest incurred on higher capitalization of interest costs on construction during 2016. This was a result of accumulating capital investments under the AIRP. AIRP investments are approved by the BPU to accrue interest on construction until such time they are rolled into base rates. This is partially offset by interest on $61.0 millionamounts of long-term debt issued in January 2016outstanding at SJI and SJG, including financing for the Acquisition (see Note 714 to the consolidated financial statements).
Interest charges increased $2.0$22.6 million in 2015 2017 compared with 2016 primarily due to the following:
$11.1 million due to higher amounts of long-term debt outstanding at SJI and SJG, along with higher interest rates on variable rate debt outstanding at SJI and SJG.
$5.1 million of charges incurred on the bridge credit facility entered into in conjunction with the Acquisition.
$4.0 million of interest charges incurred from an unfavorable court ruling related to a pricing dispute between SJRG and a supplier (see Note 15 to the consolidated financial statements),
$2.4 million resulting from an amendment of an existing interest rate derivative contract previously linked to unrealized losses recorded in AOCL, which was reclassified to interest expense as a result of rolling in investmentsthe prior hedged transactions being deemed probable of SJG’s accelerated investment programs into rates. Capital investments undernot occurring (see Note 16 to the AIRP and Capital Investment Recovery Tracker (CIRT) programs were rolled into base rates effective October 1, 2014 and 2013, respectively. Such program spend was permitted by the BPU to accrue interest on construction, which reduces interest expense, until such time they were rolled into base rates. The Company also placed two major technology systems into service during the fourth quarter of 2014, thereby lowering the capitalization of interest on construction from 2014 to 2015.consolidated financial statements).
Income Taxes –- Income taxtaxes went from a benefit of $24.9 million in 2017 to expense generally fluctuates asof $0.6 million in 2018 primarily due to income before income taxes changes.in 2018 as opposed to a loss before income taxes in 2017. Income taxes changed from a $54.2 million expense in 2016 to a $24.9 million benefit in 2017 primarily due to $13.5 million of adjustments made as a result of Tax Reform, which was enacted in 2017 (see Note 4 to the consolidated financial statements), which are excluded from Economic Earnings. Also contributing was an overall loss before income taxes, as opposed to income in 2016, primarily due to several impairment charges taken as discussed under "Impairment Charges" above (also see Note 1 to the consolidated financial statements), along with an unfavorable court ruling related to a pricing dispute between SJRG and a supplier (see Note 15 to the consolidated financial statements). These were partially offset with the impact of recording no investment tax credits on renewable energy facilities in 2017 as opposed to $9.1 million in 2016, which is consistent with SJI's previously announced strategy of substantially reducing solar development.
Equity in Earnings of Affiliated Companies - The change in equity in earnings of affiliated companies in 2018 and 2017 compared with the prior year was not significant.
Discontinued Operations - The losses are primarily comprised of environmental remediation and product liability litigation associated with previously disposed of businesses.
LIQUIDITY AND CAPITAL RESOURCES:RESOURCES:
Liquidity needs are driven by factors that include natural gas commodity prices; the impact of weather on customer bills; lags in fully collecting gas costs from customers under the BGSS charge;charge and other regulatory clauses, and environmental remediation expenditures through the RAC; working capital needs of SJI's energy trading and marketing activities; the timing of construction and remediation expenditures and related permanent financings; the timing of equity contributions to unconsolidated affiliates; mandated tax payment dates; both discretionary and required repayments of long-term debt; and the amounts and timing of dividend payments.
Cash Flows from Operating Activities - Cash generated fromLiquidity needs are first met with net cash provided by operating activities. Net cash provided by operating activities constitutes our primary source of liquiditytotaled $143.6 million, $190.3 million and $262.6 million in 2018, 2017 and 2016, respectively. Net cash provided by operating activities varies from year-to-year primarily due to the impact of weather on customer demand and related gas purchases, customer usage factors related to conservation efforts and the price of the natural gas commodity, inventory utilization, and recoveries provided through our various rate mechanisms. Netgas cost recoveries. Operating activities in 2018 produced less net cash provided by operating activities was $142.2 million in 2016, $164.6 million in 2015 and $103.5 million in 2014.
Operating activities in 2017 produced less net cash than 2016, primarily due to under-recoveries in the BGSS clause at SJG. During the second quarter of 2017, SJG provided a customer BGSS bill credit based on a forecasted over-recovered clause balance at the end of 2014, boththe BGSS year. In addition, SJG experienced higher spending for environmental remediation. Finally, during the first quarter of which negatively impacted the funding status of the2017, SJI made a $10.0 million payment to fund its pension plans. The CompanySJI did not make a pension payment in 2016. SJI strives to keep its pension plans fully funded. When factors such as lesser than expected asset performance and/or declining discount rates negatively impact the funding status of the plans, the Company increases its contributions to offset that funding shortfall.
Cash Flows from Investing Activities - We haveSJI has a continuing need for cash resources forand capital, purchases, primarily to invest in new and replacement facilities and equipment. Cash usedNet cash outflows from investing activities, which are primarily construction projects along with the impacts from the Acquisition, for 2018, 2017 and 2016 amounted to $1.79 billion, $287.3 million and $280.3 million, respectively. The high amount of net cash outflows from investing activities for 2018 was due to cash paid for the Acquisition (see Note 20 to the consolidated financial statements). We estimate the cash outflows for investing activities, net of refinancings and returns/advances on investments from affiliates, for 2019, 2020 and 2021 to be approximately $378.9 million, $536.5 million and $506.4 million, respectively. These amounts include the capital expenditures was $225.3 million, $207.8 millionof ETG and $200.0 million in 2016, 2015ELK (post-Acquisition) for all three years. The high level of investing activities for 2019, 2020 and 2014, respectively, primarily2021 is due to the accelerated infrastructure improvements that continue to support SJG’s growth. The increased capital expenditures during the past three years were the direct resultinvestment programs at SJG along with projected SJI Midstream investments, net of the Company’s AIRP and SHARP programs; the AIRP program beganprojected returns, in 2009 and the SHARP program began in 2014. See additional details under “Rates and Regulation.”
Other key investing activities of SJI during 2018 and 2017 were as follows:
SJI received approximately $310.6 million in 2018 from the sale of certain solar assets along with the sale of SJE's retail gas operations. See Note 1 to the consolidated financial statements.
SJI paid $11.3 million to enter into a new asset management agreement. See Note 1 to the consolidated financial statements.
SJI made net investments in unconsolidated affiliates of $6.6 million and $32.1 million in 2018 and 2017, respectively.
During 2017, SJI received approximately $3.1 million related to the sale of real estate. SJI recognized an after-tax gain on this sale of approximately $1.7 million.
During 2017, SJI made an incremental $7.5 million payment above the prior year to fund company-owned life insurance.
During 2017, SJI received the remaining balance in connection with an outstanding note receivable with a third party. Cash proceeds received in 2017 were $22.9 million.
Cash Flows from Financing Activities - Short-term borrowings from the commercial paper program and lines of credit from commercial banks to finance capital expenditures as incurred. From time to time, the Company may refinance the short-term debt incurred to support capital expenditures with long-term debt.
Credit facilities and available liquidity as of December 31, 2018 were as follows (in thousands):
| Company | Total Facility | Usage | Available Liquidity | Expiration Date | ||||||||||
| SJI: | ||||||||||||||
| SJI Syndicated Revolving Credit Facility | $ | 400,000 | $ | 33,100 | (A) | $ | 366,900 | August 2022 | ||||||
| Revolving Credit Facility | 50,000 | 50,000 | — | September 2019 | ||||||||||
| Total SJI | 450,000 | 83,100 | 366,900 | |||||||||||
| SJG: | ||||||||||||||
| Commercial Paper Program/Revolving Credit Facility | 200,000 | 108,300 | (B) | 91,700 | August 2022 | |||||||||
| Uncommitted Bank Line | 10,000 | 10,000 | August 2019 | |||||||||||
| Total SJG | 210,000 | 108,300 | 101,700 | |||||||||||
| ETG/ELK: | ||||||||||||||
| ETG/ELK Revolving Credit Facility | 200,000 | 86,000 | 114,000 | June 2020 | ||||||||||
| Total | $ | 860,000 | $ | 277,400 | $ | 582,600 | ||||||||
(A) Includes letters of credit outstanding in the amount of $6.1 million.
(B) Includes letters of credit outstanding in the amount of $0.8 million.
On June 26, 2018, SJI (as a guarantor to expandELK's obligation under this revolving credit agreement) and upgrade our gas transmissionETG and distribution systemELK (as Borrowers) entered into a $200.0 million, two-year revolving credit agreement with several lenders. The revolving credit agreement provides for the extension of credit to the Borrowers in a total aggregate amount of $200.0 million ($175.0 million for ETG; $25.0 million for ELK), in the form of revolving loans up to a full amount of $200.0 million, swingline loans in an amount not to exceed an aggregate of $20.0 million and letters of credit in an amount not to exceed an aggregate of $50.0 million, each at the applicable interest rates specified in the revolving credit agreement. Subject to certain conditions set forth in the revolving credit agreement, ETG may increase the revolving credit facility up to a maximum aggregate amount of $50.0 million (for a total revolving facility of up to $250.0 million). This facility contains one financial covenant, limiting the ratio of indebtedness to total capitalization (as defined in the credit agreement) of each Borrower to not more than 0.70 to 1, measured at the end of each fiscal quarter. ETG and ELK were in compliance with this covenant at December 31, 2018. As of December 31, 2018, outstanding loans from this credit facility amount to $86.0 million.
The SJG and ETG/ELK facilities are restricted as to use and availability specifically to SJG and ETG/ELK, respectively; however, if necessary, the SJI facilities can also be used to support seasonal workingthe liquidity needs of SJG, ETG or ELK. All committed facilities contain one financial covenant limiting the ratio of indebtedness to total capitalization of the applicable borrowers (as defined in the respective credit agreements), measured on a quarterly basis. SJI, SJG, ETG and ELK were in compliance with these covenants as of December 31, 2018. Borrowings under these credit facilities are at market rates.
SJI's weighted average interest rate on these borrowings (which includes SJG and ETG/ELK), which changes daily, was 3.32%, 2.46% and 1.47% at December 31, 2018, 2017 and 2016, respectively. SJG's weighted average interest rate on these borrowings, which changes daily, was 2.96%, 1.88% and 0.97% at December 31, 2018, 2017 and 2016, respectively.
SJI's average borrowings outstanding under these credit facilities (which includes SJG and ETG/ELK), not including letters of credit, during the years ended December 31, 2018 and 2017 were $265.5 million and $276.7 million, respectively. The maximum amounts outstanding under these credit facilities (which includes SJG and ETG/ELK), not including letters of credit, during the years ended December 31, 2018 and 2017 were $497.0 million and $373.8 million respectively.
SJG's average borrowings outstanding under its credit facilities, not including letters of credit, during the years ended December 31, 2018 and 2017 were $86.0 million and $17.6 million, respectively. The maximum amount outstanding under its credit facilities, not including letters of credit, during the years ended December 31, 2018 and 2017 were $177.0 million and $110.1 million, respectively.
Based upon the existing credit facilities and a regular dialogue with our banks, we believe there will continue to be sufficient credit available to meet our business' future liquidity needs.
The SJI and SJG principal credit facilities are provided by a syndicate of banks. In January 2018, the NPA for Senior Unsecured Notes issued by SJI, as well as the credit agreements with its syndicate of banks, were amended to reflect a financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective NPA or credit agreement) to not more than 0.70 to 1, measured at the end of each fiscal quarter. For SJI, the equity units are treated as equity (as opposed to how they are classified on the consolidated balance sheet, as long-term debt) for purposes of the covenant calculation. Further, in the event that SJI receives less than $500.0 million of net cash proceeds from the issuance of equity or equity-linked securities, that financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective NPA or credit agreement) increases to not more than 0.75 to 1, measured at the end of each fiscal quarter, for a period of one year following the closing of the acquisition of ETG and ELK. SJI and SJG were in compliance with this covenant as of December 31, 2018. However, one SJG bank facility still contains a financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreement) to not more than 0.65 to 1 measured at the end of each fiscal quarter. As a result, SJG must ensure that the ratio of indebtedness to total capitalization (as defined in the respective credit agreement) does not exceed 0.65 to 1, as measured at the end of each fiscal quarter. SJG is was in compliance with this covenant as of December 31, 2018.
SJG has a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million. The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes. SJG uses the commercial paper program in tandem with the new $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.
SJI supplements its operating cash flow, commercial paper program and credit lines with both debt and equity capital. Over the years, SJG has used long-term debt, primarily in the form of First Mortgage Bonds and MTN's, secured by the same pool of utility assets, to finance its long-term borrowing needs. These needs are primarily capital needs related to inventoriesexpenditures for property, plant and customer receivables. equipment.
2018-2019 Activity:
In January 2016,2018, SJI issued the following MTN's: (a) $25.0 million aggregate principal amount of 3.32% Senior Notes, Series 2017A-2, due January 2025 and (b) $25.0 million aggregate principal amount of 3.56% Senior Notes, Series 2017B-2, due January 2028.
In the second quarter of 2018, the Company issued senior unsecured notes as follows: (a) $90.0 million aggregate principal amount of 3.18% Senior Notes, Series 2018A, due April 2021; (b) $80.0 million aggregate principal amount of 3.82% Senior Notes, Series 2018B, due 2028; and (c) $80.0 million aggregate principal amount of 3.92% Senior Notes, Series 2018C, due 2030.
In April 2018, the Company completed the following public offerings, the net proceeds of which were used to fund a portion of the consideration paid for the assets of ETG and ELK (see Notes 1 and 6 to the consolidated financial statements):
SJI offered 12,669,491 shares of its common stock, par value $1.25 per share, at a public offering price of $29.50 per share. Of the offered shares, 5,889,830 shares were issued at closing, including 1,652,542 shares pursuant to the underwriters’ option. The gross proceeds from these shares was $173.7 million, with net proceeds, after deducting underwriting discounts and commissions, of $167.7 million. The remaining 6,779,661 shares of common stock ("Forward Shares") were to be sold by Bank of America, N.A., as forward seller, pursuant to a forward sale agreement. The Company received no proceeds from the sale of the Forward Shares in 2018. In January 2019, the Company settled the equity forward sale agreement by physically delivering 6,779,661 shares of common stock and receiving net cash proceeds of approximately $189.0 million. See Note 22 to the consolidated financial statements.
SJI issued and sold 5,750,000 Equity Units, initially in the form of Corporate Units, which included 750,000 Corporate Units pursuant to the underwriters’ option. Each Corporate Unit has a stated amount of $50 and is comprised of (a) a purchase contract obligating the holder to purchase from the Company, and for the Company to sell to the holder for a price in cash of $50, on the purchase contract settlement date, or April 15, 2021, subject to earlier termination or settlement, a certain number of shares of common stock; and (b) a 1/20, or 5%, undivided beneficial ownership interest in $1,000 principal amount of SJI’s 2018 Series A 3.70% Remarketable Junior Subordinated Notes due 2031. SJI will pay the holder quarterly contract adjustment payments at a rate of 3.55% per year on the stated amount of $50 per Equity Unit, in respect of each purchase contract, subject to the Company's right to defer these payments. No deferral period will extend beyond the purchase contract settlement date. The contract adjustment payments are payable quarterly on January 15, April 15, July 15 and October 15 of each year (except that if such date is not a business day, contract adjustment payments will be payable on the following business day, without adjustment), commencing on July 15, 2018. The contract adjustment payments will be subordinated to all of the Company's existing and future “Priority Indebtedness” and will be structurally subordinated to all liabilities of our subsidiaries. The present value of the contract adjustment payments due through April 15, 2021 are initially charged to Shareholders’ Equity, with an offsetting credit to Other Current and Noncurrent Liabilities on the consolidated balance sheet. These liabilities are accreted over the life of the purchase contract by interest charges to the income statement based on a constant rate calculation. Subsequent contract adjustment payments reduce this liability. This offering resulted in gross proceeds of approximately $287.5 million, with net proceeds, after deducting underwriting discounts and commissions, of $278.9 million. As of December 31, 2018, the net proceeds, after amortization of the underwriting discounts, are recorded as Long-Term Debt on the consolidated balance sheets (see Note 14).
On June 20, 2018, the Company issued an aggregate of $475.0 million of Floating Rate Senior Notes, Series 2018D, due 2019 on the one-year anniversary of the date of initial issuance. These notes will be repaid using the proceeds of the various contemplated asset sales or will be refinanced.
In July 2018, S&P downgraded SJI and SJG, from BBB+ with a negative outlook to BBB with a stable outlook. S&P had revised the outlook for both SJI and SJG from stable to negative after the announcement of the Acquisition in October 2017. Certain of SJI's and SJG's credit agreements are ratings-based so a downgrade could adversely impact the cost of future borrowings. The Company does not believe that the downgrade will negatively impact our ability to refinance any of our debt.
In October 2018, SJG entered into an unsecured, $400.0 million term loan credit agreement (the “Credit Agreement”), under which SJG can borrow up to an aggregate of $400.0 million until October 2019. All loans under the Credit Agreement become due and payable in April 2020. Any amounts repaid prior to the maturity date cannot be reborrowed.
In November 2018, SJG redeemed $8.0 million of 4.01% MTNs.
In December 2018, ETG issued $61.0$530.0 million aggregate principal amount of its First Mortgage Bonds, Series 2018A, which were issued in five Tranches (see Note 14 to the consolidated financial statements). The proceeds from the sale of these bonds were used to repay short-term indebtedness under a previous $530.0 million, 364-day term loan credit agreement dated as of June 26, 2018, which was entered into to help fund the Acquisition. Prior to repayment, the term loans bore interest at a variable base rate or a variable LIBOR at the election of the Company.
On January 15, 2019, SJI settled its equity forward sale agreement (see Note 6 to the consolidated financial statements) by delivering 6,779,661 shares of common stock and receiving net cash proceeds of approximately $189.0 million. The forward price used to determine cash proceeds received by SJI at settlement was calculated based on the initial forward sale price, as adjusted for underwriting fees, interest rate adjustments as specified in the equity forward agreement and any dividends paid on our common stock during the forward period.
On January 17, 2019, SJI provided Notice of Optional Prepayment to the holders of its Floating Rate Senior Notes, Series 2018D, due June 20, 2019 of the Company’s intent to prepay a portion of the $475.0 million aggregate principal amount outstanding. As a result, the Company paid $150.0 million on January 31, 2019. On February 6, 2019, a second Notice of Optional Prepayment was provided by SJI to the holders of its Floating Rate Senior Notes, Series 2018D, due June 20, 2019 of the Company's intent to prepay an additional $125.0 million on February 22, 2019.
CURRENT PORTION OF LONG-TERM DEBT - The Company has $733.9 million of long-term debt that is due within the next year. The Company expects to significantly reduce this debt in 2019 using cash provided from the settlement of its equity forward sale agreement (see Note 22 to the consolidated financial statements), the sale of the remaining solar assets (see Note 1 to the consolidated financial statements), along with the sale of other assets considered non-core to the business. The remaining long-term debt that is due within the next year is expected to be paid by utilizing funds provided from refinancing activity and from the revolving credit facility. The Company anticipates refinancing approximately $500.0 million of outstanding long-term debt during 2019.
2017 Activity:
In January 2017, SJG entered into a Supplemental Indenture Amending and Restating First Mortgage Indenture (the “New Mortgage”), which amended and restated in its entirety that Indenture of Mortgage dated October 1, 1947. The New Mortgage provides for the issuance by SJG of bonds, notes or other securities that are secured by a lien on itssubstantially all of the operating properties and franchises of SJG.
SJG had a $200.0 million multiple-draw term facility offered by a syndicate of banks. This facility bore interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. The total outstanding amount under this facility as of December 31, 2016 was $200.0 million, which was classified in current portion of long-term debt on the consolidated balance sheets as of December 31, 2016 as it was due within one year.in June 2017. In January 2017, SJG issued $200.0 million aggregate principal amount of Medium Term Notes (MTN's),MTN's, Series E, 2017, due January 2047, with principal repayments beginning in 2025. The MTN's bear interest at an annual rate of 3.0% payable semiannually. Proceeds were used to pay down the above-mentioned $200.0 million multiple-draw term facility which was set to expire in June 2017 (see Note 17 to the financial statements).
In January 2017, SJG entered into an unsecured, $200.0 million multiple-draw term loan credit agreement ("Credit Agreement"), which is syndicated among seven banks. Term loans under the Credit Agreement bear interest at a variable base rate or a variable LIBOR rate, at SJG's election. Under the Credit Agreement, SJG can borrow up to an aggregate of $200.0 million until July 2018, of which SJG borrowed $73.0$200.0 million on January 31,during 2017. All loans underProceeds from the Credit Agreement become dueabove-mentioned $400.0 million term loan credit agreement entered into in January 2019.October 2018 were used to pay down this facility.
In May 2017, Marina voluntarily redeemed bonds issued by the NJEDA in an aggregate principal amount of $61.4 million, as follows: Thermal Energy Facilities Revenue Bonds (Marina Energy LLC - 2001 Project) Series A ($20.0 million); Thermal Energy Facilities Federally Taxable Revenue Bonds (Marina Energy LLC - 2001 Project) Series B ($25.0 million); and Thermal Energy Facilities Revenue Bonds (Marina Energy LLC Project) Series 2006A ($16.4 million). In connection with the redemptions, separate related letter of credit reimbursement agreements were terminated (see Note 15 to the consolidated financial statements).
In June 2017, SJI redeemed at maturity $16.0 million of 2.71% Senior Unsecured Notes.
In July 2017, SJG redeemed at maturity $15.0 million of 4.657% MTNs.
In August 2015, SJG retired $10.02017, SJI entered into a note purchase agreement that provides for the issuance of an aggregate of $100.0 million of MTNs. Pursuant to the agreement, SJI issued $50.0 million aggregate principal amount of 5.387% MTN's at maturity.
SJG had previously spent all but $0.1 millionmakes payments of the debt proceeds and was permitted under the debt agreement to utilize those remaining funds to redeem the debt early. In December 2015, SJG paid $0.9 million annually through December 2025 toward the principal amount of 3.63% MTN's, including a payment made in 2017. As such, $0.9 million of the total outstanding amount on this debt is classified in current portion of long-term debt on the consolidated balance sheets as it is due within one year (see Note 14 to the consolidated financial statements).
No other long-term debt was issued or retired during the years ended December 2025.31, 2018 or 2017.
SJI contributed an equity infusionoffers a DRP which allows participating shareholders to purchase shares of $65.0 millionSJI common stock by automatic reinvestment of dividends or optional purchases. SJI currently purchases shares on the open market to fund share purchases by DRP participants, and $25.0 million in 2016 and 2014, respectively.as a result SJI did not contributeraise any equity capital through the DRP in 2017 or 2018. SJI does not intend to SJGissue equity capital via the DRP in 2015.2019.
| Total Facility | Usage | Available Liquidity | Expiration Date | ||||||||||
| Commercial Paper/Revolving Credit Facility | $ | 200,000 | $ | 105,100 | (A) | $ | 94,900 | May 2018 | |||||
| Uncommitted Bank Lines | 10,000 | — | 10,000 | August 2017 | |||||||||
| Total | $ | 210,000 | $ | 105,100 | $ | 104,900 | |||||||
| 2016 | 2015 | As of December 31, | ||||||||
| Common Equity | 53 | % | 49 | % | ||||||
| 2018 | 2017 | |||||||||
| Equity | 28.9 | % | 43.7 | % | ||||||
| Long-Term Debt | 40 | % | 42 | % | 64.9 | % | 43.6 | % | ||
| Short-Term Debt | 7 | % | 9 | % | 6.2 | % | 12.7 | % | ||
| Total | 100 | % | 100 | % | 100.0 | % | 100.0 | % | ||
During 2018, 2017 and 2016, SJI paid quarterly dividends to its common shareholders. SJI has paid dividends on its common stock for 67 consecutive years and has increased that dividend each year for the last 19 years. SJI currently seeks to grow that dividend consistent with earnings growth while targeting a payout ratio of between 55% and 65% of Economic Earnings. In setting the dividend rate, the Board of Directors of SJI considers future earnings expectations, payout ratio, and dividend yield relative to those at peer companies, as well as returns available on other income-oriented investments. However, there can be no assurance that SJI will be able to continue to increase the dividend, meet the targeted payout ratio or pay a dividend at all in the future.
COMMITMENTS AND CONTINGENCIES:
STANDBY LETTERS OF CREDIT — See Note 15 to the RAC mechanism are expected to approximate $9.8 million, $15.6 million and $21.2 million in 2017, 2018, and 2019, respectively.consolidated financial statements.
In 2011, whileaddition, in itsthe normal course of business, SJG and SJRG have entered into long-term contracts for natural gas supplies. SJRG has committed to purchase 832,500 dts/d of natural gas, from various suppliers, for terms ranging from four to ten years at index-based prices. SJG has committed to purchase a minimum of 6,250 dts/d and up to 25,000 dts/d of natural gas, from one supplier, for a term of eight years at index-based prices. SJG has also committed to a purchase of a minimum of 55,000 dts/d and up to 70,000 dts/d, for a term of ten years at index-based prices. The obligations for these purchases have not been included in SJI's contractual obligations discussed below because the actual volumes and prices are not fixed.
The following table summarizes our contractual cash obligations and their applicable payment due dates as of December 31, 2018 (in thousands):
| Up to | Years | Years | More than | ||||||||||||
| Contractual Cash Obligations | Total | 1 Year | 2 & 3 | 4 & 5 | 5 Years | ||||||||||
| Principal Payments on Long-Term Debt | $ | 2,867,764 | $ | 733,909 | $ | 495,818 | $ | 106,168 | $ | 1,531,869 | |||||
| Interest on Long-Term Debt | 1,091,131 | 105,180 | 154,071 | 124,958 | 706,922 | ||||||||||
| Construction Obligations | 320,672 | 320,672 | — | — | — | ||||||||||
| Operating Leases | 1,885 | 838 | 916 | 131 | — | ||||||||||
| Commodity Supply Purchase Obligations | 1,701,676 | 626,361 | 483,359 | 195,228 | 396,728 | ||||||||||
| Environmental Remediation Costs | 253,650 | 47,592 | 131,878 | 46,810 | 27,370 | ||||||||||
| New Jersey Clean Energy Program | 18,832 | 18,832 | — | — | — | ||||||||||
| Other Purchase Obligations | 4,213 | 4,213 | — | — | — | ||||||||||
| Total Contractual Cash Obligations | $ | 6,259,823 | $ | 1,857,597 | $ | 1,266,042 | $ | 473,295 | $ | 2,662,889 | |||||
Long-Term Debt in the table above does not include unamortized debt issuance costs of $27.0 million, which are reclassified to Long-Term Debt on the consolidated balance sheets.
Interest on long-term debt in the table above includes the related interest obligations through maturity on all outstanding long-term debt. Expected asset retirement obligations and the liability for unrecognized tax benefits are not included in the table above as the total obligation cannot be calculated due to the subjective nature of these costs and timing of anticipated payments. SJI did not make contributions to its employee pension plans in 2018. SJI contributed $10.0 million to the pension plans, of which SJG contributed $8.0 million, in January 2017. Future pension contributions cannot be determined at this time. SJG's regulatory obligation to contribute $3.6 million annually to its postretirement benefit plans’ trusts, as discussed in Note 12 to the consolidated financial statements, is also not included as its duration is indefinite.
RC Cape May Holdings, LLC has communicated to SJG that it no longer intends to proceed with a project to re-power the former BL England facility with natural gas. The proposed project was approved by the BPU in 2015 and the New Jersey Pinelands Commission in 2017, and would have supplied natural gas to this facility as well as provided a secondary supply of natural gas to customers in Atlantic and Cape May counties. SJG remains committed to meeting the vitally important needs of residents and businesses in these counties, and SJG is exploring other alternatives.
OFF-BALANCE SHEET ARRANGEMENTS - An off-balance sheet arrangement is any contractual arrangement involving an unconsolidated entity under which the Company has either made guarantees or has certain other interests or obligations.
As of December 31, 2018, SJI had issued $8.6 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable the subsidiary to market retail natural gas.
In April 2018, SJI entered into various agreements relating to public offerings. See "Liquidity and Capital Resources."
NOTES RECEIVABLE-AFFILIATES - As of December 31, 2018, SJI had approximately $13.6 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from Energenic, which is secured by its cogeneration assets for energy service projects. This note is subject to a reimbursement agreement that secures reimbursement for SJI, from its joint venture partner, of a proportionate share of any amounts that are not repaid.
Management will continue to monitor the situation surrounding the cogeneration assets and will evaluate the carrying value of the investment and the note receivable as future events occur.
PENDING LITIGATION - SJI and SJG are subject to claims arising in the ordinary course of business and other legal proceedings. SJI has been named in, among other actions, certain gas supply contract disputes and certain product liability claims related to our former sand mining subsidiary. See Note 15 to the consolidated financial statements for more detail on these claims.
SOUTH JERSEY GAS COMPANY
This section of Management’s Discussion focuses on SJG for the reported periods. In many cases, explanations and disclosures for both SJI and SJG are substantially the same or specific disclosures for SJG are included in the Management's Discussion for SJI.
RESULTS OF OPERATIONS:
The results of operations for the SJG utility operation are described in detail above; therefore, this section primarily focuses on statistical information and other information that is not discussed in the results of operations under South Jersey Industries, Inc. Refer to the section entitled “Results of Operations - SJG Utility Operations” for a detailed discussion of the results of operations for SJG.
The following table summarizes the composition of selected gas utility throughput for the years ended December 31, (in thousands, except for degree day data):
| December 31, 2018 | December 31, 2017 | December 31, 2016 | |||||||||||||||
| Utility Throughput - dts: | |||||||||||||||||
| Firm Sales - | |||||||||||||||||
| Residential | 25,424 | 16 | % | 22,107 | 15 | % | 22,126 | 15 | % | ||||||||
| Commercial | 6,037 | 4 | % | 5,294 | 3 | % | 4,956 | 3 | % | ||||||||
| Industrial | 434 | — | 422 | — | 310 | — | |||||||||||
| Cogeneration and Electric Generation | 2,384 | 1 | % | 1,300 | 1 | % | 1,485 | 1 | % | ||||||||
| Firm Transportation - | |||||||||||||||||
| Residential | 1,504 | 1 | % | 1,635 | 1 | % | 1,975 | 1 | % | ||||||||
| Commercial | 6,978 | 4 | % | 6,422 | 4 | % | 6,892 | 5 | % | ||||||||
| Industrial | 10,278 | 6 | % | 10,894 | 7 | % | 11,612 | 8 | % | ||||||||
| Cogeneration and Electric Generation | 5,113 | 3 | % | 6,199 | 4 | % | 7,451 | 5 | % | ||||||||
| Total Firm Throughput | 58,152 | 35 | % | 54,273 | 35 | % | 56,807 | 38 | % | ||||||||
| Interruptible Sales | 28 | — | 3 | — | 2 | — | |||||||||||
| Interruptible Transportation | 1,039 | 1 | % | 1,140 | 1 | % | 1,149 | 1 | % | ||||||||
| Off-System | 13,582 | 9 | % | 25,560 | 17 | % | 16,526 | 11 | % | ||||||||
| Capacity Release | 86,249 | 55 | % | 70,315 | 47 | % | 73,913 | 50 | % | ||||||||
| Total Throughput - Utility | 159,050 | 100 | % | 151,291 | 100 | % | 148,397 | 100 | % | ||||||||
| Number of Customers at Year End: | |||||||||||||||||
| Residential | 365,009 | 93 | % | 358,026 | 93 | % | 352,427 | 93 | % | ||||||||
| Commercial | 25,657 | 7 | % | 25,184 | 7 | % | 24,767 | 7 | % | ||||||||
| Industrial | 426 | — | 423 | — | 431 | — | |||||||||||
| Total Customers | 391,092 | 100 | % | 383,633 | 100 | % | 377,625 | 100 | % | ||||||||
| Annual Degree Days* | 4,602 | 4,272 | 4,292 | ||||||||||||||
*Each day, each degree of average daily temperature below 65 degrees Fahrenheit is counted as one heating degree-day. Annual degree-days is the sum of the daily totals.
Throughput - Gas Utility Operations 2018 vs. 2017 -Total gas throughput increased 7.8 MMdts or 5.1% in 2018 compared with 2017, primarily due to 15.9 MMdts increase in capacity release. The increase in capacity release volume was primarily related to acquisition of additional pipeline capacity on the Tennessee pipeline system, which was not in service during the same periods in the prior year. In addition, total firm throughput increased by 3.9 MMdts due to weather that was 7.7% colder than the previous year and 7,459 additional customers. These increases were partially offset by 12.0 MMdts decrease in OSS volume, primarily due to production area OSS made for April through October 2017 which did not occur during 2018.
Throughput - Gas Utility Operations 2017 vs. 2016 -Total gas throughput increased 2.9 MMdts, or 2.0%, in 2017 compared with 2016 primarily due to increases in Off-System Sales of 9.0 MMdts. The increase in Off-System volume is primarily relatedto additional Off-System contracts that were entered into April through October of 2017. The increase in Off-System volume was partially offset by a 3.6 MMdts decrease in capacity releases during 2017 compared to 2016. Additionally, third-party supplier deliveries also decreased by 2.8 MMdts during 2017 compared to 2016, primarily due to weather that was 0.4% warmer than the previous year.
Operating Revenues & Utility Margin - See SJI's Management Discussion section above.
Operating Expenses - A summary of changes in other operating expenses (in thousands):
| 2018 vs. 2017 | 2017 vs. 2016 | ||||
| Operations | 16,316 | $ | 3,383 | ||
| Maintenance | 9,015 | $ | 2,178 | ||
| Depreciation | 5,868 | $ | 6,455 | ||
| Energy and Other Taxes | 517 | $ | 109 | ||
Operations - See SJI's Management Discussion section above.
Maintenance- See SJI's Management Discussion section above.
Depreciation - Depreciation expense increased $5.9 million and $6.5 million in 2018 and 2017, respectively, compared with the prior year primarily due to continuing investment in utility plant. The increased spending in recent years is a direct result of New Jersey's infrastructure improvement efforts, which included the approval of SJG’s AIRP and SHARP, in addition to significant investment in new technology systems.
Energy and Other Taxes - The change in energy and other taxes in 2018 and 2017 compared with prior years was not significant.
Other Income and Expense - The changes in Other Income and Expense in 2018 compared to 2017 were not significant. Other Income and Expense increased $2.6 million in 2017 compared with 2016, primarily due to higher AFUDC due to increased capital spending and a new AIRP II program.
Interest Charges– Interest charges increased $3.3 million in 2018 compared with 2017, primarily due to higher amounts of long-term debt outstanding compared with 2017. Interest charges increased $6.8 million in 2017 compared with 2016, primarily due to higher amounts of long-term debt outstanding (see Note 14 to the consolidated financial statements).
Income Taxes– Income tax expense generally fluctuates as income before taxes changes. Minor variations will occur period to period as a result of effective tax rate adjustments. Changes for the year ended December 31, 2018 were also impacted by Tax Reform.
LIQUIDITY AND CAPITAL RESOURCES:
Liquidity and capital resources for SJG are substantially covered in the Management’s Discussion of SJI (except for the items and transactions that relate to SJI and its nonutility subsidiaries). Those explanations are incorporated by reference into this discussion.
Liquidity needs for SJG are driven by factors that include natural gas commodity prices; the impact of weather on customer bills; lags in fully collecting gas costs from customers under the BGSS charge and environmental remediation expenditures through the RAC; the timing of construction and remediation expenditures and related permanent financings; mandated tax payment dates; both discretionary and required repayments of long-term debt; and the amounts and timing of dividend payments.
Cash Flows from Operating Activities - Liquidity needs are first met with net cash provided by operating activities. Net cash provided by operating activities totaled $113.0 million, $106.7 million and $142.2 million for the years ended 2018, 2017 and 2016, respectively. Net cash provided by operating activities varies from year-to-year primarily due to the impact of weather on customer demand and related gas purchases, customer usage factors related to conversion efforts and the price of the natural gas commodity, inventory utilization, and gas cost recoveries.
Operating activities in 2018 produced more net cash than 2017 due to the SJG base rate case settlement and customer growth. In addition, SJG did not make a pension payment in 2018, but did make an $8.0 million contribution in the first quarter of 2017.
These were partially offset with higher costs experienced for environmental remediations.
Operating activities for 2017 produced less net cash than the same period in 2016, primarily due to under-recoveries in the BGSS clause at SJG. During the second quarter of 2017, SJG provided a customer BGSS bill credit based on a forecasted over-recovered clause balance at the end of the BGSS year. In addition, SJG experienced higher spending for environmental remediation. Finally, during the first quarter of 2017, SJG made an $8.0 million payment to fund its pension plans. SJG did not make a contribution to its pension plans in 2016.
Cash Flows from Investing Activities - SJG has a continuing need for cash resources for capital expenditures, primarily to invest in new and replacement facilities and equipment. SJG estimates the net cash outflows for capital expenditures for fiscal years 2019, 2020 and 2021 to be approximately $277.3 million, $283.7 million and $370.4 million, respectively. For capital expenditures, including those under the AIRP and SHARP, SJG expects to use short-term borrowings under both its commercial paper program and lines of credit from commercial banks to finance capital expenditures as incurred. From time to time, SJG may refinance the short-term debt incurred to support capital expenditures with long-term debt.
During 2017, SJG made a $4.9 million payment to fund company-owned life insurance.
Cash Flows from Financing Activities - SJG supplements its operating cash flow and credit lines with both debt and equity capital. Over the years, SJG has used long-term debt, primarily in the form of First Mortgage Bonds and MTN's, secured by the same pool of utility assets, to finance its long-term borrowing needs. These needs are primarily capital expenditures for property, plant and equipment.
SJI did not contribute equity to SJG in 2018. SJI contributed equity infusions of $40.0 million and $65.0 million to SJG during the years ended December 31, 2017 and 2016, respectively. No dividends were declared by SJG in 2018. In December 2017, SJG declared and paid cash dividends of $20.0 million to SJI.
SJG’s capital structure was as follows:
| As of December 31, | ||||||
| 2018 | 2017 | |||||
| Common Equity | 50.2 | % | 51.3 | % | ||
| Long-Term Debt | 44.5 | % | 45.8 | % | ||
| Short-Term Debt | 5.3 | % | 2.9 | % | ||
| Total | 100.0% | 100.0 | % | |||
COMMITMENTS AND CONTINGENCIES:
Costs for remediation projects, net of recoveries from ratepayers, for 2018, 2017 and 2016, amounted to net cash outflows of $53.7 million, $39.9 million and $39.7 million, respectively. Total net cash outflows for remediation projects are expected to be $28.6 million, $42.5 million and $32.5 million for 2019, 2020 and 2021, respectively. Environmental remediation costs are subject to recovery from ratepayers.
SJG has certain commitments for both pipeline capacity and gas supply for which SJG pays fees regardless of usage. Those commitments, as of December 31, 2018, averaged $68.7 million annually and totaled $453.4 million over the contracts’ lives. Approximately 27% of the financial commitments under these contracts expire during the next five years. SJG expects to renew each of these contracts under renewal provisions as provided in each contract. SJG recovers all such prudently incurred fees through rates via the BGSS.
SJG has long-term contracts for natural gas supplies. SJG committed to purchase a minimum of 6,250 dts/d and up to 25,000 dts/d of natural gas, from one supplier, for an original term of eight years at index-based prices. SJG has also committed to a purchase of a minimum of 55,000 dts/d and up to 70,000 dts/d, for a term of ten years at index-based prices. The obligationobligations for this purchase hasthese purchases have not been included in the Company'sSJG's contractual obligations discussedtable below because the actual volumes and prices are not fixed.
The following table summarizes ourSJG's contractual cash obligations and their applicable payment due dates as of December 31, 20162018 (in thousands):
| Contractual Cash Obligations | Total | Up to 1 Year | Years 2 & 3 | Years 4 & 5 | More than 5 Years | Total | Up to 1 Year | Years 2 & 3 | Years 4 & 5 | More than 5 Years | ||||||||||||||||||||||||||||
| Principal Payments on Long-Term Debt | $ | 645,082 | $ | 215,909 | $ | 57,818 | $ | 45,818 | $ | 325,537 | $ | 900,264 | $ | 18,909 | $ | 355,818 | $ | 71,168 | $ | 454,369 | ||||||||||||||||||
| Interest on Long-Term Debt | 180,314 | 21,084 | 34,909 | 29,903 | 94,418 | 235,322 | 32,273 | 45,272 | 37,952 | 119,825 | ||||||||||||||||||||||||||||
| Commodity Supply Purchase Obligations | 356,711 | 88,476 | 105,338 | 37,731 | 125,166 | 295,504 | 295,504 | — | — | — | ||||||||||||||||||||||||||||
| Environmental Remediation Costs | 153,047 | 45,018 | 81,932 | 6,419 | 19,678 | 148,071 | 33,022 | 74,954 | 27,118 | 12,977 | ||||||||||||||||||||||||||||
| Construction Obligations | 144,109 | 144,109 | — | — | — | 477,230 | 87,137 | 130,180 | 65,919 | 193,994 | ||||||||||||||||||||||||||||
| Operating Leases | 391 | 173 | 194 | 24 | — | 175 | 56 | 112 | 7 | — | ||||||||||||||||||||||||||||
| New Jersey Clean Energy Program | 14,969 | 14,969 | — | — | — | 8,323 | 8,323 | — | — | — | ||||||||||||||||||||||||||||
| Other Purchase Obligations | 2,876 | 2,876 | — | — | — | 4,213 | 4,213 | — | — | — | ||||||||||||||||||||||||||||
| Total Contractual Cash Obligations | $ | 1,497,499 | $ | 532,614 | $ | 280,191 | $ | 119,895 | $ | 564,799 | $ | 2,069,102 | $ | 479,437 | $ | 606,336 | $ | 202,164 | $ | 781,165 | ||||||||||||||||||
Long-Term Debt in the table above does not include unamortized debt issuance costs of $6.0$6.8 million, which wereare reclassified to Long-Term Debt on the balance sheets to conform to ASU 2015-03 (see Note 1 to the financial statements).sheets.
Expected asset retirement obligations and the liability for unrecognized tax benefits are not included in the table above as the total obligation cannot be calculated due to the subjective nature of these costs and timing of anticipated payments. SJG did not make a pension plan contribution in 2016. SJG made contributions to its employee pension plans totaling $8.0 million in January 2017.2018. Future pension contributions beyond January 2017 cannot be determined at this time. SJG's regulatory obligation to contribute $3.6 million annually to ourits postretirement benefit plans’ trusts, as discussed in Note 1112 to the consolidated financial statements, is also not included as its duration is indefinite.
Pending Litigation - See SJG's disclosure in the Commitments and Contingencies section of SJI's Management Discussion above.
Off-Balance Sheet Arrangements- We have SJG has no off-balance sheet financing arrangements.
Item 7a.7A. Quantitative and Qualitative Disclosures about Market Risks
Commodity Market Risks - WeCertain SJI subsidiaries, including SJG, are involved in buying, selling, transporting and storing natural gas, and buying and selling retail electricity, for their own accounts as well as managing these activities for third parties. These subsidiaries are subject to market risk due to price fluctuations. To hedge against this risk, we enterSJI enters into a variety of physical and financial transactions including forward contracts, swaps, futures and options agreements. To manage these transactions, we haveSJI has a well-defined risk management policy approved by ourSJI's Board of Directors that includes volumetric and monetary limits. Management reviews reports detailing activity daily. Generally, the derivative activities described above are entered into for risk management purposes.
SJRG manages risk for its own portfolio by entering into the types of transactions noted above. The majorityretail electric operations of ourSJE use forward physical and financial contracts to mitigate commodity price risk on fixed price electric contracts. It is management's policy, to the extent practical, within predetermined risk management policy guidelines, to have limited unmatched positions on a deal or portfolio basis while conducting these activities. As a result of holding open positions to a minimal level, the economic impact of changes in value of a particular transaction is substantially offset by an opposite change in the related hedge transaction.
SJI has entered into certain contracts to buy, sell, and transport natural gas and to buy and sell retail electricity. SJI recorded net pre-tax gains (losses) on these contracts of $34.5 million, $(13.7) million and $26.9 million in earnings during 2018, 2017 and 2016, respectively, which are typically less than twelve-months long.included with realized gains and losses in Operating Revenues - Nonutility on the consolidated statements of income.
The fair value and maturity of these energy trading and hedgingenergy-trading contracts determined usingunder the mark-to-market accountingmethod as of December 31, 20162018 is as follows (in thousands):
| Assets | ||||||||||||
| Source of Fair Value | Maturity < 1 Year | Maturity 1 - 3 Years | Total | |||||||||
| Prices Actively Quoted (NYMEX) | $ | 4,394 | $ | 373 | $ | 4,767 | ||||||
| Prices Provided by Other External Sources (Basis) | — | — | — | |||||||||
| Prices based on internal models or other valuable methods | 1,040 | — | 1,040 | |||||||||
| Total | $ | 5,434 | $ | 373 | $ | 5,807 | ||||||
| Assets | ||||||||||||||||||||||||
| Source of Fair Value | Maturity < 1 Year | Maturity 1 - 3 Years | Maturity Beyond 3 Years | Total | ||||||||||||||||||||
| Prices actively quoted | $ | 9,344 | $ | 554 | $ | 57 | $ | 9,955 | ||||||||||||||||
| Prices provided by other external sources | 19,529 | 3,707 | 193 | 23,429 | ||||||||||||||||||||
| Prices based on internal models or other valuation methods | 25,148 | 2,604 | 54 | 27,806 | ||||||||||||||||||||
| Total | $ | 54,021 | $ | 6,865 | $ | 304 | $ | 61,190 | ||||||||||||||||
| Liabilities | ||||||||||||||||||||||||
| Source of Fair Value | Maturity < 1 Year | Maturity 1 - 3 Years | Maturity Beyond 3 Years | Total | ||||||||||||||||||||
| Maturity | Maturity | |||||||||||||||||||||||
| Source of Fair Value | < 1 Year | 1 - 3 Years | Total | |||||||||||||||||||||
| Prices Actively Quoted (NYMEX) | $ | 6 | $ | — | $ | 6 | ||||||||||||||||||
| Prices Provided by Other External Sources (Basis) | 1,252 | — | 1,252 | |||||||||||||||||||||
| Prices based on internal models or other valuable methods | 114 | — | 114 | |||||||||||||||||||||
| Prices actively quoted | $ | 6,113 | $ | 1,168 | $ | 10 | $ | 7,291 | ||||||||||||||||
| Prices provided by other external sources | 11,048 | 1,279 | 27 | 12,354 | ||||||||||||||||||||
| Prices based on internal models or other valuation methods | 6,973 | 4,537 | 235 | 11,745 | ||||||||||||||||||||
| Total | $ | 1,372 | $ | — | $ | 1,372 | $ | 24,134 | $ | 6,984 | $ | 272 | $ | 31,390 | ||||||||||
•NYMEX (New York Mercantile Exchange) is the primary national commodities exchange on which natural gas is traded. Volumes of our NYMEX contracts included in the table above under "Prices actively quoted" are 47.4 MMdts with a weighted average settlement price of $2.99 per dt.
•Basis represents the differential to the NYMEX natural gas futures contract for delivering gas to a specific location. Volumes of our basis contracts, along with volumes of our discounted index related purchase and sales contracts, included in the table above under "Prices provided by other external sources" and "Prices based on internal models or other valuation methods" are 54.9 MMdts with a weighted average settlement price of $(0.37) per dt.
•Fixed Price Gas Daily represents the price of a NYMEX natural gas futures contract adjusted for the difference in price for delivering the gas at another location. Contracted volumesVolumes of our NYMEXFixed Price Gas Daily contracts included in the table above under "Prices provided by other external sources" are 7.9 MMdt with a weighted-average settlement price of $3.08 per dt. Contracted volumes of our Basis contracts are 1.3 MMdt30.4 MMdts with a weighted average settlement price of $1.62$2.87 per dt.
•Volumes of electric included in the table above under "Prices based on internal models or other valuation methods" are 0.4 MMWh with a weighted average settlement price of $32.60 per MWh.
A reconciliation of ourSJI's estimated net fair value of energy-related derivatives follows (in thousands):
| Net Derivatives — Energy Related Liability, January 1, 2016 | $ | (4,699 | ) |
| Contracts Settled During the Twelve Months ended December 31, 2016, Net | 4,412 | ||
| Other Changes in Fair Value from Continuing and New Contracts, Net | 4,722 | ||
| Net Derivatives — Energy Related Asset, December 31, 2016 | $ | 4,435 | |
| Net Derivatives - Energy Related Liabilities, January 1, 2018 | $ | (4,836 | ) |
| Contracts Settled During 2018, Net | 4,469 | ||
| Other Changes in Fair Value from Continuing and New Contracts, Net | 30,167 | ||
| Net Derivatives - Energy Related Assets, December 31, 2018 | $ | 29,800 | |
As a result of the transaction to sell certain solar sites to a third party (see Note 1 to the consolidated financial statements), Marina will no longer generate SREC's on its own behalf and is no longer exposed to market risk associated with SRECs.
Interest Rate Risk- Our exposure to interest rateinterest-rate risk relates primarily to short-term and long-term variable-rate borrowings. Variable-rate debt outstanding, including short-term and long-term debt, at December 31, 2016,2018 was $304.3$680.5 million and averaged $304.5$846.4 million during 2016.2018. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $1.6$6.3 million increase in our annual interest expense, net of tax. The 100 basis point increase was chosen for illustrative purposes, as it provides a simple basis for calculating the impact of interest rate changes under a variety of interest rate scenarios. Over the past five years, the change in basis points (b.p.) of our average monthly interest rates from the beginning to end of each year was as follows: 2018 - 91 b.p. increase; 2017 - 82 b.p. increase; 2016 - 1947 b.p. increase; 2015 - 2014 b.p. increase; 2014 - 32 b.p. increase; 2013 - 14 b.p. decrease; and 2012 - 1 b.p. decrease. As ofAt December 31, 2016,2018, our average interest rate on variable-rate debt was 1.27%3.40%.
We typically issue long-term debt either at fixed rates or use interest rate derivatives to limit our exposure to changes in interest rates on variable-rate, long-term debt. As of December 31, 2016,2018, the interest costs on all but $200.0$1.97 billion of our long-term debt was either at a fixed rate or hedged via an interest rate derivative.
As of December 31, 2018, SJI's active interest rate swaps were as follows:
| Notional Amount | Fixed Interest Rate | Start Date | Maturity | Obligor | ||||||
| $ | 20,000,000 | 3.049% | 3/15/2017 | 3/15/2027 | SJI | |||||
| $ | 20,000,000 | 3.049% | 3/15/2017 | 3/15/2027 | SJI | |||||
| $ | 10,000,000 | 3.049% | 3/15/2017 | 3/15/2027 | SJI | |||||
| $ | 12,500,000 | 3.530% | 12/1/2006 | 2/1/2036 | SJG | |||||
| $ | 12,500,000 | 3.430% | 12/1/2006 | 2/1/2036 | SJG | |||||
Credit Risk - As of December 31, 2018, SJI had approximately $11.7 million, or 19.1%, of the current and noncurrent Derivatives – Energy Related Assets transacted with three counterparties. These counterparties are investment-grade rated.
As of December 31, 2018, SJRG had $106.8 million of ourAccounts Receivable under sales contracts. Of that total, 37.3% were with regulated utilities or companies rated investment-grade or guaranteed by an investment-grade-rated parent or were with companies where we have a collateral arrangement or insurance coverage. The remainder of the Accounts Receivable were within approved credit limits.
South Jersey Gas Company:
The fair value and maturity of SJG's energy-trading and hedging contracts determined under the mark-to-market method as of December 31, 2018 is as follows (in thousands):
| Assets | ||||||||||||
| Source of Fair Value | Maturity < 1 Year | Maturity 1 - 3 Years | Maturity Beyond 3 Years | Total | ||||||||
| Prices actively quoted | $ | 333 | $ | 15 | $ | — | $ | 348 | ||||
| Prices provided by other external sources | 126 | — | — | 126 | ||||||||
| Prices based on internal models or other valuation methods | 5,005 | — | — | 5,005 | ||||||||
| Total | $ | 5,464 | $ | 15 | $ | — | $ | 5,479 | ||||
| Liabilities | ||||||||||||
| Source of Fair Value | Maturity < 1 Year | Maturity 1 - 3 Years | Maturity Beyond 3 Years | Total | ||||||||
| Prices actively quoted | $ | 992 | $ | 43 | $ | — | $ | 1,035 | ||||
| Prices provided by other external sources | 1,077 | — | — | 1,077 | ||||||||
| Prices based on internal models or other valuation methods | 77 | — | — | 77 | ||||||||
| Total | $ | 2,146 | $ | 43 | $ | — | $ | 2,189 | ||||
Contracted volumes of SJG's NYMEX contracts are 7.9 MMdts with a weighted-average settlement price of $3.02 per dt. Contracted volumes of SJG's Basis contracts are 1.1 MMdts with a weighted-average settlement price of $0.83 per dt.
A reconciliation of SJG's estimated net fair value of energy-related derivatives follows (in thousands):
| Net Derivatives - Energy Related Liabilities, January 1, 2018 | $ | (2,108 | ) |
| Contracts Settled During 2018, Net | 1,943 | ||
| Other Changes in Fair Value from Continuing and New Contracts, Net | 3,455 | ||
| Net Derivatives - Energy Related Assets, December 31, 2018 | $ | 3,290 | |
Interest Rate Risk - SJG's exposure to interest rate risk relates primarily to variable-rate borrowings. Variable-rate debt, including both short-term and long-term debt outstanding at December 31, 2018, was $417.5 million and averaged $297.7 million during 2018. A hypothetical 100 basis point (1%) increase in interest rates on SJG's average variable-rate debt outstanding would result in a $2.2 million increase in SJG's annual interest expense, net of tax. The 100 basis point increase was chosen for illustrative purposes, as it provides a simple basis for calculating the impact of interest rate changes under a variety of interest rate scenarios. Over the past five years, the change in basis points (b.p.) of SJG's average monthly interest rates from the beginning to end of each year was as follows: 2018 - 91 b.p. increase; 2017 - 91 b.p. increase; 2016 - 19 b.p. increase; 2015 - 20 b.p. increase; and 2014 - 32 b.p. increase. As of December 31, 2018, SJG's average interest rate on variable-rate debt was 3.18%.
SJG typically issues long-term debt either at fixed rates or uses interest rate derivatives to limit exposure to changes in interest rates on variable-rate, long-term debt. As of December 31, 2018, the interest costs on $590.3 million of long-term debt was either at a fixed-rate or hedged via an interest rate derivative. Consequently, interest expense on existing long-term debt is not significantly impacted by changes in market interest rates.
Item 8. Financial Statements and Supplementary Data
(In Thousands Except for Per Share Data)
| South Jersey Industries, Inc. and Subsidiaries | |||||||||||
| Year Ended December 31, | |||||||||||
| 2018 | 2017 | 2016 | |||||||||
| Operating Revenues: | |||||||||||
| Utility | $ | 670,715 | $ | 512,482 | $ | 453,819 | |||||
| Nonutility | 970,623 | 730,586 | 582,681 | ||||||||
| Total Operating Revenues | 1,641,338 | 1,243,068 | 1,036,500 | ||||||||
| Operating Expenses: | |||||||||||
| Cost of Sales - (Excluding depreciation and amortization) | |||||||||||
| - Utility | 258,781 | 199,660 | 167,154 | ||||||||
| - Nonutility | 796,627 | 646,567 | 413,833 | ||||||||
| Operations (See Note 1) | 256,862 | 169,767 | 147,056 | ||||||||
| Impairment Charges | 105,280 | 91,299 | — | ||||||||
| Maintenance | 32,162 | 19,727 | 17,549 | ||||||||
| Depreciation | 96,723 | 100,718 | 90,389 | ||||||||
| Energy and Other Taxes | 9,537 | 6,487 | 6,342 | ||||||||
| Net Gain on Sales of Assets | (15,379 | ) | — | — | |||||||
| Total Operating Expenses | 1,540,593 | 1,234,225 | 842,323 | ||||||||
| Operating Income (See Note 1) | 100,745 | 8,843 | 194,177 | ||||||||
| Other Income and Expense (See Note 1) | 2,404 | 11,041 | 5,088 | ||||||||
| Interest Charges | (90,296 | ) | (54,019 | ) | (31,449 | ) | |||||
| Income (Loss) Before Income Taxes | 12,853 | (34,135 | ) | 167,816 | |||||||
| Income Taxes | (561 | ) | 24,937 | (54,151 | ) | ||||||
| Equity in Earnings of Affiliated Companies | 5,611 | 5,794 | 5,396 | ||||||||
| Income (Loss) from Continuing Operations | 17,903 | (3,404 | ) | 119,061 | |||||||
| Loss from Discontinued Operations - (Net of tax benefit) | (240 | ) | (86 | ) | (251 | ) | |||||
| Net Income (Loss) | $ | 17,663 | $ | (3,490 | ) | $ | 118,810 | ||||
| Basic Earnings (Loss) per Common Share: | |||||||||||
| Continuing Operations | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | ||||
| Discontinued Operations | — | — | — | ||||||||
| Basic Earnings (Loss) per Common Share | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | ||||
| Average Shares of Common Stock Outstanding - Basic | 83,693 | 79,541 | 76,362 | ||||||||
| Diluted Earnings (Loss) per Common Share: | |||||||||||
| Continuing Operations | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | ||||
| Discontinued Operations | — | — | — | ||||||||
| Diluted Earnings (Loss) per Common Share | $ | 0.21 | $ | (0.04 | ) | $ | 1.56 | ||||
| Average Shares of Common Stock Outstanding - Diluted | 84,471 | 79,541 | 76,475 | ||||||||
(In Thousands)
| South Jersey Industries, Inc. and Subsidiaries | |||||||||||
| Year Ended December 31, | |||||||||||
| 2018 | 2017 | 2016 | |||||||||
| Net Income (Loss) | $ | 17,663 | $ | (3,490 | ) | $ | 118,810 | ||||
| Other Comprehensive Income (Loss), Net of Tax: | |||||||||||
| Postretirement Liability Adjustment (A) | 10,636 | (10,920 | ) | (3,197 | ) | ||||||
| Unrealized Gain on Available-for-Sale Securities (B) | — | — | 118 | ||||||||
| Unrealized Gain on Derivatives - Other (B) | 34 | 1,536 | 197 | ||||||||
| Other Comprehensive Income (Loss) - Net of Tax | 10,670 | (9,384 | ) | (2,882 | ) | ||||||
| Comprehensive Income (Loss) | $ | 28,333 | $ | (12,874 | ) | $ | 115,928 | ||||
(A) Determined using a combined average statutory tax rate of 25% for 2018; 27% for 2017; and 40% for 2016.
(B) Determined using a combined average statutory tax rate of 25% for 2018; 39% for 2017; and 40% for 2016.
The accompanying notes are an integral part of the consolidated financial statements.
Statements of Consolidated Cash Flows (In Thousands)
| South Jersey Industries, Inc. and Subsidiaries | |||||||||||
| Year Ended December 31, | |||||||||||
| 2018 | 2017 | 2016 | |||||||||
| Cash Flows from Operating Activities: | |||||||||||
| Net Income (Loss) | $ | 17,663 | $ | (3,490 | ) | $ | 118,810 | ||||
| Loss from Discontinued Operations | 240 | 86 | 251 | ||||||||
| Income (Loss) from Continuing Operations | 17,903 | (3,404 | ) | 119,061 | |||||||
| Adjustments to Reconcile Income from Continuing Operations to Net Cash Provided by Operating Activities: | |||||||||||
| Net Gain on Sales of Assets | (15,379 | ) | (2,563 | ) | — | ||||||
| Impairment Charges | 105,280 | 91,299 | — | ||||||||
| Loss on Extinguishment of Debt | — | 543 | — | ||||||||
| Depreciation and Amortization | 132,914 | 123,486 | 109,818 | ||||||||
| Net Unrealized (Gain) Loss on Derivatives - Energy Related | (34,447 | ) | 13,667 | (26,935 | ) | ||||||
| Unrealized (Gain) Loss on Derivatives - Other | (1,337 | ) | 677 | (647 | ) | ||||||
| Provision for Losses on Accounts Receivable | 7,977 | 6,949 | 6,907 | ||||||||
| CIP Receivable/Payable | 32,523 | 915 | (24,943 | ) | |||||||
| Deferred Gas Costs - Net of Recoveries | (46,495 | ) | (28,092 | ) | 11,753 | ||||||
| Deferred SBC Costs - Net of Recoveries | 311 | (5,578 | ) | (7,102 | ) | ||||||
| Stock-Based Compensation Expense | 4,144 | 4,254 | 3,892 | ||||||||
| Deferred and Noncurrent Income Taxes - Net | 10,392 | 10,082 | 55,789 | ||||||||
| Environmental Remediation Costs - Net of Recoveries | (59,307 | ) | (39,860 | ) | (39,731 | ) | |||||
| Gas Plant Cost of Removal | (11,184 | ) | (7,062 | ) | (6,070 | ) | |||||
| Pension Contribution | — | (10,000 | ) | — | |||||||
| Changes in: | |||||||||||
| Accounts Receivable | (106,283 | ) | 21 | (67,160 | ) | ||||||
| Inventories | 566 | 5,589 | 387 | ||||||||
| Prepaid and Accrued Taxes - Net | 13,418 | (23,366 | ) | 4,253 | |||||||
| Accounts Payable and Other Accrued Liabilities | 114,371 | 58,858 | 112,199 | ||||||||
| Derivatives - Energy Related | 5,208 | 899 | 6,723 | ||||||||
| Other Assets and Liabilities | (26,999 | ) | (6,989 | ) | 4,477 | ||||||
| Cash Flows from Discontinued Operations | 7 | (4 | ) | (44 | ) | ||||||
| Net Cash Provided by Operating Activities | 143,583 | 190,321 | 262,627 | ||||||||
| Cash Flows from Investing Activities: | |||||||||||
| Capital Expenditures | (341,120 | ) | (272,965 | ) | (279,423 | ) | |||||
| Cash Paid for Acquisition, Net of Cash Acquired | (1,740,285 | ) | — | — | |||||||
| Cash Paid for Purchase of New Contract | (11,339 | ) | — | — | |||||||
| Proceeds from Sale of Property, Plant and Equipment | 310,644 | 3,547 | — | ||||||||
| Investment in Long-Term Receivables | (8,643 | ) | (9,324 | ) | (10,886 | ) | |||||
| Proceeds from Long-Term Receivables | 9,813 | 9,861 | 10,014 | ||||||||
| Notes Receivable | — | 22,884 | 9,916 | ||||||||
| Purchase of Company-Owned Life Insurance | (1,298 | ) | (9,180 | ) | (2,398 | ) | |||||
| Investment in Affiliate | (9,524 | ) | (29,636 | ) | (12,943 | ) | |||||
| Return of Investment in Affiliate | — | — | 4,750 | ||||||||
| Advances on Notes Receivable - Affiliate | — | (2,451 | ) | — | |||||||
| Net Repayment of Notes Receivable - Affiliate | 2,967 | — | 672 | ||||||||
| Net Cash Used in Investing Activities | (1,788,785 | ) | (287,264 | ) | (280,298 | ) | |||||
| Cash Flows from Financing Activities: | |||||||||||
| Net (Repayments of) Borrowings from Short-Term Credit Facilities | (75,900 | ) | 50,300 | (135,600 | ) | ||||||
| Proceeds from Issuance of Long-Term Debt | 2,432,500 | 450,000 | 61,000 | ||||||||
| Payments for Issuance of Long-Term Debt | (21,574 | ) | (14,204 | ) | (147 | ) | |||||
| Principal Repayments of Long-Term Debt | (768,909 | ) | (293,309 | ) | (49,366 | ) | |||||
| Dividends on Common Stock | (94,756 | ) | (87,308 | ) | (82,380 | ) | |||||
| Net Settlement of Restricted Stock | (776 | ) | (751 | ) | (387 | ) | |||||
| Proceeds from Sale of Common Stock | 173,750 | — | 214,426 | ||||||||
| Payments for the Issuance of Common Stock | (7,149 | ) | — | — | |||||||
| Payment of Lease Obligation | — | — | (10,600 | ) | |||||||
| Net Cash Provided by (Used in) Financing Activities | 1,637,186 | 104,728 | (3,054 | ) | |||||||
| Net (Decrease) Increase in Cash, Cash Equivalents and Restricted Cash | (8,016 | ) | 7,785 | (20,725 | ) | ||||||
| Cash, Cash Equivalents and Restricted Cash at Beginning of Year | 39,695 | 31,910 | 52,635 | ||||||||
| Cash, Cash Equivalents and Restricted Cash at End of Year | $ | 31,679 | $ | 39,695 | $ | 31,910 | |||||
| Supplemental Disclosures of Cash Flow Information | |||||||||||
| Cash paid (received) during the year for: | |||||||||||
| Interest (Net of Amounts Capitalized) | $ | 84,792 | $ | 51,456 | $ | 32,372 | |||||
| Income Taxes (Refunds) Paid | $ | (20,004 | ) | $ | (8,348 | ) | $ | 194 | |||
| Supplemental Disclosures of Non-Cash Investing Activities | |||||||||||
| Capital Expenditures acquired on account but unpaid as of year-end | $ | 44,184 | $ | 32,253 | $ | 39,130 | |||||
| Notes Receivable Exchanged for Accounts Payable | $ | — | $ | 3,841 | $ | 10,168 | |||||
The accompanying notes are an integral part of the consolidated financial statements.
Consolidated Balance Sheets
(In Thousands)
| South Jersey Industries, Inc. and Subsidiaries | |||||||
| December 31, | |||||||
| 2018 | 2017 | ||||||
| Assets | |||||||
| Property, Plant and Equipment: | |||||||
| Utility Plant, at original cost | $ | 4,341,113 | $ | 2,652,244 | |||
| Accumulated Depreciation | (787,243 | ) | (498,161 | ) | |||
| Nonutility Property and Equipment, at cost | 152,232 | 741,027 | |||||
| Accumulated Depreciation | (52,629 | ) | (194,913 | ) | |||
| Property, Plant and Equipment - Net | 3,653,473 | 2,700,197 | |||||
| Investments: | |||||||
| Available-for-Sale Securities | 41 | 36 | |||||
| Restricted | 1,649 | 31,876 | |||||
| Investment in Affiliates | 76,122 | 62,292 | |||||
| Total Investments | 77,812 | 94,204 | |||||
| Current Assets: | |||||||
| Cash and Cash Equivalents | 30,030 | 7,819 | |||||
| Accounts Receivable | 337,502 | 202,379 | |||||
| Unbilled Revenues | 79,538 | 73,377 | |||||
| Provision for Uncollectibles | (18,842 | ) | (13,988 | ) | |||
| Notes Receivable - Affiliate | 1,945 | 4,913 | |||||
| Natural Gas in Storage, average cost | 60,425 | 48,513 | |||||
| Materials and Supplies, average cost | 1,743 | 4,239 | |||||
| Prepaid Taxes | 30,694 | 41,355 | |||||
| Derivatives - Energy Related Assets | 54,021 | 42,139 | |||||
| Assets Held For Sale | 59,588 | — | |||||
| Other Prepayments and Current Assets | 26,548 | 28,247 | |||||
| Total Current Assets | 663,192 | 438,993 | |||||
| Regulatory and Other Noncurrent Assets: | |||||||
| Regulatory Assets | 662,969 | 469,224 | |||||
| Derivatives - Energy Related Assets | 7,169 | 5,988 | |||||
| Notes Receivable - Affiliate | 13,275 | 13,275 | |||||
| Contract Receivables | 27,961 | 28,721 | |||||
| Goodwill | 734,607 | 3,578 | |||||
| Other (See Note 1) | 116,119 | 110,906 | |||||
| Total Regulatory and Other Noncurrent Assets | 1,562,100 | 631,692 | |||||
| Total Assets | $ | 5,956,577 | $ | 3,865,086 | |||
The accompanying notes are an integral part of the consolidated financial statements.
| 2018 | 2017 | ||||||
| Capitalization and Liabilities | |||||||
| Equity: | |||||||
| Common Stock: Par Value $1.25 per share; Authorized 120,000,000 shares; Outstanding Shares: 85,506,218 (2018) and 79,549,080 (2017) | |||||||
| Balance at Beginning of Year | $ | 99,436 | $ | 99,347 | |||
| Common Stock Issued or Granted Under Stock Plans | 7,447 | 89 | |||||
| Balance at End of Year | 106,883 | 99,436 | |||||
| Premium on Common Stock | 843,268 | 709,658 | |||||
| Treasury Stock (at par) | (292 | ) | (271 | ) | |||
| Accumulated Other Comprehensive Loss | (26,095 | ) | (36,765 | ) | |||
| Retained Earnings | 343,258 | 420,351 | |||||
| Total Equity | 1,267,022 | 1,192,409 | |||||
| Long-Term Debt | 2,106,863 | 1,122,999 | |||||
| Total Capitalization | 3,373,885 | 2,315,408 | |||||
| Current Liabilities: | |||||||
| Notes Payable | 270,500 | 346,400 | |||||
| Current Portion of Long-Term Debt | 733,909 | 63,809 | |||||
| Accounts Payable | 410,463 | 284,899 | |||||
| Customer Deposits and Credit Balances | 32,058 | 43,398 | |||||
| Environmental Remediation Costs | 47,592 | 66,372 | |||||
| Taxes Accrued | 5,881 | 2,932 | |||||
| Derivatives - Energy Related Liabilities | 24,134 | 46,938 | |||||
| Derivatives - Other Current | 588 | 748 | |||||
| Deferred Contract Revenues | 1,772 | 259 | |||||
| Interest Accrued | 14,208 | 9,079 | |||||
| Pension Benefits | 3,631 | 2,388 | |||||
| Other Current Liabilities | 36,102 | 15,860 | |||||
| Total Current Liabilities | 1,580,838 | 883,082 | |||||
| Deferred Credits and Other Noncurrent Liabilities: | |||||||
| Deferred Income Taxes - Net | 85,836 | 86,884 | |||||
| Pension and Other Postretirement Benefits | 110,112 | 101,544 | |||||
| Environmental Remediation Costs | 206,058 | 106,483 | |||||
| Asset Retirement Obligations | 80,163 | 59,497 | |||||
| Derivatives - Energy Related Liabilities | 7,256 | 6,025 | |||||
| Derivatives - Other Noncurrent | 7,285 | 9,622 | |||||
| Regulatory Liabilities | 478,499 | 287,105 | |||||
| Other | 26,645 | 9,436 | |||||
| Total Deferred Credits and Other Noncurrent Liabilities | 1,001,854 | 666,596 | |||||
| Commitments and Contingencies (Note 15) | |||||||
| Total Capitalization and Liabilities | $ | 5,956,577 | $ | 3,865,086 | |||
The accompanying notes are an integral part of the consolidated financial statements.
Consolidated Statements of Changes in Equity and Comprehensive Income
(In Thousands)
| South Jersey Industries, Inc. and Subsidiaries | ||||||||||||||||||||||||
| Years Ended December 31, 2016, 2017 and 2018 | ||||||||||||||||||||||||
| Common Stock | Premium on Common Stock | Treasury Stock | Accumulated Other Comprehensive Loss | Retained Earnings | Total | |||||||||||||||||||
| Balance at January 1, 2016 | $ | 88,707 | $ | 499,460 | $ | (296 | ) | $ | (24,499 | ) | $ | 474,167 | $ | 1,037,539 | ||||||||||
| Net Income | — | — | — | — | 118,810 | 118,810 | ||||||||||||||||||
| Other Comprehensive Loss, Net of Tax | — | — | — | (2,882 | ) | — | (2,882 | ) | ||||||||||||||||
| Common Stock Issued or Granted Through Equity Offering or Stock Plans | 10,640 | 207,483 | 30 | — | — | 218,153 | ||||||||||||||||||
| Cash Dividends Declared - Common Stock ($1.07 per share) | — | — | — | — | (82,380 | ) | (82,380 | ) | ||||||||||||||||
| Balance at December 31, 2016 | 99,347 | 706,943 | (266 | ) | (27,381 | ) | 510,597 | 1,289,240 | ||||||||||||||||
| Net Loss | — | — | — | — | (3,490 | ) | (3,490 | ) | ||||||||||||||||
| Other Comprehensive Loss, Net of Tax | — | — | — | (9,384 | ) | — | (9,384 | ) | ||||||||||||||||
| Common Stock Issued or Granted Under Stock Plans | 89 | 2,715 | (5 | ) | — | — | 2,799 | |||||||||||||||||
| Cash Dividends Declared - Common Stock ($1.10 per share) | — | — | — | — | (87,308 | ) | (87,308 | ) | ||||||||||||||||
| Excess Tax Benefit on Restricted Stock | — | — | — | — | 552 | 552 | ||||||||||||||||||
| Balance at December 31, 2017 | 99,436 | 709,658 | (271 | ) | (36,765 | ) | 420,351 | 1,192,409 | ||||||||||||||||
| Net Income | 17,663 | 17,663 | ||||||||||||||||||||||
| Other Comprehensive Loss, Net of Tax | 10,670 | 10,670 | ||||||||||||||||||||||
| Common Stock Issued or Granted Through Equity Offering or Stock Plans | 7,447 | 133,610 | (21 | ) | 141,036 | |||||||||||||||||||
| Cash Dividends Declared - Common Stock ($1.13 per share) | (94,756 | ) | (94,756 | ) | ||||||||||||||||||||
| Balance at December 31, 2018 | $ | 106,883 | $ | 843,268 | $ | (292 | ) | $ | (26,095 | ) | $ | 343,258 | $ | 1,267,022 | ||||||||||
Disclosure of Changes In Accumulated Other Comprehensive Loss Balances (a)
(In Thousands)
Postretirement Liability Adjustment (A) | Unrealized Gain (Loss) on Derivatives-Other (B) | Unrealized Gain (Loss) on Available- for-Sale Securities (B) | Other Comprehensive Income (Loss) of Affiliated Companies (B) | Accumulated Other Comprehensive Loss | ||||||||||||||||
| Balance at January 1, 2016 | $ | (22,145 | ) | $ | (2,129 | ) | $ | (128 | ) | $ | (97 | ) | $ | (24,499 | ) | |||||
| Changes During Year | (3,197 | ) | 197 | 118 | — | (2,882 | ) | |||||||||||||
| Balance at December 31, 2016 | (25,342 | ) | (1,932 | ) | (10 | ) | (97 | ) | (27,381 | ) | ||||||||||
| Changes During Year | (10,920 | ) | 1,536 | — | — | (9,384 | ) | |||||||||||||
| Balance at December 31, 2017 | (36,262 | ) | (396 | ) | (10 | ) | (97 | ) | (36,765 | ) | ||||||||||
| Changes During Year | 10,636 | 34 | 10,670 | |||||||||||||||||
| Balance at December 31, 2018 | $ | (25,626 | ) | $ | (362 | ) | $ | (10 | ) | $ | (97 | ) | $ | (26,095 | ) | |||||
(A) Determined using a combined average statutory tax rate of 25% for 2018; 27% for 2017; and 40% for 2016.
(B) Determined using a combined average statutory tax rate of 25% for 2018; 39% for 2017; and 40% for 2016.
The accompanying notes are an integral part of the consolidated financial statements.
SOUTH JERSEY GAS COMPANY
STATEMENTS OF INCOME
(In Thousands)
| Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||
| 2016 | 2015 | 2014 | 2018 | 2017 | 2016 | |||||||||||||||||
| Operating Revenues | $ | 461,055 | $ | 534,290 | $ | 501,875 | $ | 548,000 | $ | 517,254 | $ | 461,055 | ||||||||||
| Operating Expenses: | ||||||||||||||||||||||
| Cost of Sales (Excluding depreciation) | 174,390 | 245,290 | 231,216 | |||||||||||||||||||
| Operations | 95,609 | 107,836 | 102,428 | |||||||||||||||||||
| Cost of Sales (Excluding depreciation and amortization) | 209,649 | 204,432 | 174,390 | |||||||||||||||||||
| Operations (See Note 1) | 112,920 | 96,604 | 93,012 | |||||||||||||||||||
| Maintenance | 17,549 | 16,183 | 13,457 | 28,742 | 19,727 | 17,549 | ||||||||||||||||
| Depreciation | 47,432 | 41,365 | 37,324 | 59,755 | 53,887 | 47,432 | ||||||||||||||||
| Energy and Other Taxes | 3,620 | 4,031 | 3,760 | 4,246 | 3,729 | 3,620 | ||||||||||||||||
| Total Operating Expenses | 338,600 | 414,705 | 388,185 | 415,312 | 378,379 | 336,003 | ||||||||||||||||
| Operating Income | 122,455 | 119,585 | 113,690 | |||||||||||||||||||
| Other Income and Expense | 3,831 | 3,844 | 5,560 | |||||||||||||||||||
| Operating Income (See Note 1) | 132,688 | 138,875 | 125,052 | |||||||||||||||||||
| Other Income and Expense (See Note 1) | 4,685 | 4,087 | 1,234 | |||||||||||||||||||
| Interest Charges | (17,875 | ) | (19,906 | ) | (17,872 | ) | (28,011 | ) | (24,705 | ) | (17,875 | ) | ||||||||||
| Income Before Income Taxes | 108,411 | 103,523 | 101,378 | 109,362 | 118,257 | 108,411 | ||||||||||||||||
| Income Taxes | (39,366 | ) | (36,945 | ) | (34,895 | ) | (26,413 | ) | (45,700 | ) | (39,366 | ) | ||||||||||
| Net Income | $ | 69,045 | $ | 66,578 | $ | 66,483 | $ | 82,949 | $ | 72,557 | $ | 69,045 | ||||||||||
The accompanying notes are an integral part of the financial statements.
SOUTH JERSEY GAS COMPANY
STATEMENTS OF COMPREHENSIVE INCOME
(In Thousands)
| Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||
| 2016 | 2015 | 2014 | 2018 | 2017 | 2016 | |||||||||||||||||
| Net Income | $ | 69,045 | $ | 66,578 | $ | 66,483 | $ | 82,949 | $ | 72,557 | $ | 69,045 | ||||||||||
| Other Comprehensive Income (Loss), Net of Tax:* | ||||||||||||||||||||||
| Other Comprehensive Income (Loss), Net of Tax: | ||||||||||||||||||||||
| Postretirement Liability Adjustment | (2,197 | ) | 1,617 | (3,165 | ) | 3,606 | (11,090 | ) | (2,197 | ) | ||||||||||||
| Unrealized Gain (Loss) on Available-for-Sale Securities | 98 | (23 | ) | (472 | ) | |||||||||||||||||
| Unrealized Gain on Available-for-Sale Securities (B) | — | — | 98 | |||||||||||||||||||
| Unrealized Gain on Derivatives - Other | 27 | 23 | 27 | 34 | 27 | 27 | ||||||||||||||||
| Other Comprehensive (Loss) Income - Net of Tax* | (2,072 | ) | 1,617 | (3,610 | ) | |||||||||||||||||
| Other Comprehensive Income (Loss) - Net of Tax | 3,640 | (11,063 | ) | (2,072 | ) | |||||||||||||||||
| Comprehensive Income | $ | 66,973 | $ | 68,195 | $ | 62,873 | $ | 86,589 | $ | 61,494 | $ | 66,973 | ||||||||||
(B) Determined using a combined average statutory tax rate of 2016, 201525% for 2018; 39% for 2017; and 2014.
40% for 2016.
The accompanying notes are an integral part of the financial statements.
SOUTH JERSEY GAS COMPANY
STATEMENTS OF CASH FLOWS
(In Thousands)
| Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||
| 2016 | 2015 | 2014 | 2018 | 2017 | 2016 | |||||||||||||||||
| Cash Flows from Operating Activities: | ||||||||||||||||||||||
| Net Income | $ | 69,045 | $ | 66,578 | $ | 66,483 | $ | 82,949 | $ | 72,557 | $ | 69,045 | ||||||||||
| Provided by Operating Activities: | ||||||||||||||||||||||
| Adjustments to Reconcile Income from Continuing Operations to Net Cash Provided by Operating Activities: | ||||||||||||||||||||||
| Depreciation and Amortization | 63,901 | 58,668 | 52,155 | 82,622 | 71,654 | 63,901 | ||||||||||||||||
| Provision for Losses on Accounts Receivable | 6,993 | 14,689 | 9,417 | 7,997 | 6,949 | 6,993 | ||||||||||||||||
| CIP Receivable/Payable | (24,943 | ) | (7,324 | ) | 15,226 | 32,523 | 915 | (24,943 | ) | |||||||||||||
| Deferred Gas Costs - Net of Recoveries | 11,753 | 28,648 | (44,976 | ) | (46,495 | ) | (28,092 | ) | 11,753 | |||||||||||||
| Deferred SBC Costs - Net of Recoveries | (7,102 | ) | 9,557 | 11,048 | 311 | (5,578 | ) | (7,102 | ) | |||||||||||||
| Environmental Remediation Costs - Net of Recoveries | (39,735 | ) | (22,058 | ) | (8,248 | ) | (53,685 | ) | (39,860 | ) | (39,735 | ) | ||||||||||
| Deferred and Noncurrent Income Taxes and Credits - Net | 40,980 | 39,148 | 32,193 | 39,179 | 78,712 | 40,980 | ||||||||||||||||
| Gas Plant Cost of Removal | (6,070 | ) | (5,096 | ) | (4,848 | ) | (6,899 | ) | (7,062 | ) | (6,070 | ) | ||||||||||
| Pension Contribution | — | (12,020 | ) | — | — | (7,997 | ) | — | ||||||||||||||
| Changes in: | ||||||||||||||||||||||
| Accounts Receivable | (24,867 | ) | 8,597 | (14,667 | ) | (21,749 | ) | (28,129 | ) | (24,867 | ) | |||||||||||
| Inventories | 2,696 | 11,198 | (3,820 | ) | (1,198 | ) | (3,222 | ) | 2,696 | |||||||||||||
| Prepaid and Accrued Taxes - Net | 3,980 | (7,129 | ) | (6,508 | ) | 9,685 | (20,993 | ) | 3,980 | |||||||||||||
| Other Prepayments and Current Assets | (448 | ) | (9,717 | ) | 131 | 1,390 | 1,183 | (448 | ) | |||||||||||||
| Gas Purchases Payable | 14,879 | (13,423 | ) | (1,873 | ) | 5,149 | 19,526 | 14,879 | ||||||||||||||
| Accounts Payable and Other Accrued Liabilities | 35,982 | (2,264 | ) | 11,302 | (15,194 | ) | (1,753 | ) | 35,982 | |||||||||||||
| Other Assets | (7,065 | ) | 4,996 | (7,481 | ) | (6,705 | ) | (16,925 | ) | (7,065 | ) | |||||||||||
| Other Liabilities | 2,183 | 1,576 | (2,006 | ) | 3,094 | 14,784 | 2,183 | |||||||||||||||
| Net Cash Provided by Operating Activities | 142,162 | 164,624 | 103,528 | 112,974 | 106,669 | 142,162 | ||||||||||||||||
| Cash Flows from Investing Activities: | ||||||||||||||||||||||
| Capital Expenditures | (225,287 | ) | (207,785 | ) | (200,008 | ) | (241,873 | ) | (248,864 | ) | (225,287 | ) | ||||||||||
| Note Receivable | 9,916 | (9,916 | ) | — | — | 9,916 | ||||||||||||||||
| Net Sale (Purchase) of Restricted Investments in Margin Accounts | 6,737 | 1,091 | (7,281 | ) | ||||||||||||||||||
| Net Sale of Restricted Investments from Escrowed Loan Proceeds | — | 101 | — | |||||||||||||||||||
| Purchase of Company Owned Life Insurance | — | (4,875 | ) | — | ||||||||||||||||||
| Investment in Long-Term Receivables | (10,886 | ) | (19,033 | ) | (13,024 | ) | (8,643 | ) | (9,324 | ) | (10,886 | ) | ||||||||||
| Proceeds from Long-Term Receivables | 10,014 | 8,769 | 6,544 | 9,813 | 9,861 | 10,014 | ||||||||||||||||
| Net Cash Used in Investing Activities | (209,506 | ) | (226,773 | ) | (213,769 | ) | (240,703 | ) | (253,202 | ) | (216,243 | ) | ||||||||||
| Cash Flows from Financing Activities: | ||||||||||||||||||||||
| Net (Repayments of) Borrowings from Short-Term Credit Facilities | (30,100 | ) | 33,000 | 35,900 | ||||||||||||||||||
| Net Borrowings from (Repayments of) Short-Term Credit Facilities | 55,500 | (52,300 | ) | (30,100 | ) | |||||||||||||||||
| Proceeds from Issuance of Long-Term Debt | 61,000 | 80,000 | 89,000 | 310,000 | 400,000 | 61,000 | ||||||||||||||||
| Principal Repayments of Long-Term Debt | (27,909 | ) | (11,009 | ) | (21,000 | ) | (238,909 | ) | (215,909 | ) | (27,909 | ) | ||||||||||
| Payments for Issuance of Long-Term Debt | (63 | ) | (9 | ) | (627 | ) | (219 | ) | (2,030 | ) | (63 | ) | ||||||||||
| Dividends on Common Stock | — | (40,764 | ) | (18,201 | ) | — | (20,000 | ) | — | |||||||||||||
| Additional Investment by Shareholder | 65,000 | — | 25,000 | — | 40,000 | 65,000 | ||||||||||||||||
| Tax Deficiency from Restricted Stock Plan | — | (72 | ) | (73 | ) | |||||||||||||||||
| Net Cash Provided by Financing Activities | 67,928 | 61,146 | 109,999 | 126,372 | 149,761 | 67,928 | ||||||||||||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | 584 | (1,003 | ) | (242 | ) | |||||||||||||||||
| Cash and Cash Equivalents at Beginning of Period | 775 | 1,778 | 2,020 | |||||||||||||||||||
| Net (Decrease) Increase in Cash, Cash Equivalents and Restricted Cash | (1,357 | ) | 3,228 | (6,153 | ) | |||||||||||||||||
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period (See Note 1) | 4,619 | 1,391 | 7,544 | |||||||||||||||||||
| Cash and Cash Equivalents at End of Period | $ | 1,359 | $ | 775 | $ | 1,778 | ||||||||||||||||
| Cash, Cash Equivalents and Restricted Cash at End of Period (See Note 1) | $ | 3,262 | $ | 4,619 | $ | 1,391 | ||||||||||||||||
| Supplemental Disclosures of Cash Flow Information | ||||||||||||||||||||||
| Cash paid during the year for: | ||||||||||||||||||||||
| Interest (Net of Amounts Capitalized) | $ | 18,497 | $ | 19,373 | $ | 17,832 | $ | 28,583 | $ | 23,729 | $ | 18,497 | ||||||||||
| Income Taxes (Net of Refunds) | $ | (1 | ) | $ | (1,665 | ) | $ | (7,690 | ) | $ | (21,742 | ) | $ | (8,476 | ) | $ | (1 | ) | ||||
| Supplemental Disclosures of Noncash Investing Activities | ||||||||||||||||||||||
| Capital Expenditures acquired on account but not paid at year-end | $ | 25,275 | $ | 24,857 | $ | 17,551 | $ | 32,272 | $ | 25,889 | $ | 25,275 | ||||||||||
The accompanying notes are an integral part of the financial statements.
SOUTH JERSEY GAS COMPANY
BALANCE SHEETS
(In Thousands)
| December 31, 2016 | December 31, 2015 | December 31, 2018 | December 31, 2017 | |||||||||||
| Assets | ||||||||||||||
| Property, Plant and Equipment: | ||||||||||||||
| Utility Plant, at original cost | $ | 2,424,134 | $ | 2,211,239 | $ | 2,907,202 | $ | 2,652,244 | ||||||
| Accumulated Depreciation | (471,222 | ) | (440,473 | ) | (523,743 | ) | (498,161 | ) | ||||||
| Property, Plant and Equipment - Net | 1,952,912 | 1,770,766 | 2,383,459 | 2,154,083 | ||||||||||
| Investments: | ||||||||||||||
| Available-for-Sale Securities | — | 8,788 | ||||||||||||
| Restricted Investments | 32 | 6,769 | 1,278 | 2,912 | ||||||||||
| Total Investments | 32 | 15,557 | 1,278 | 2,912 | ||||||||||
| Current Assets: | ||||||||||||||
| Cash and Cash Equivalents | 1,359 | 775 | 1,984 | 1,707 | ||||||||||
| Notes Receivable | — | 9,916 | ||||||||||||
| Accounts Receivable | 69,651 | 64,445 | 101,572 | 78,571 | ||||||||||
| Accounts Receivable - Related Parties | 1,355 | 1,972 | 2,442 | 988 | ||||||||||
| Unbilled Revenues | 41,754 | 25,613 | 43,271 | 54,980 | ||||||||||
| Provision for Uncollectibles | (12,570 | ) | (9,778 | ) | (13,643 | ) | (13,799 | ) | ||||||
| Natural Gas in Storage, average cost | 11,621 | 14,294 | 16,336 | 14,932 | ||||||||||
| Materials and Supplies, average cost | 914 | 937 | 619 | 825 | ||||||||||
| Prepaid Taxes | 16,428 | 21,483 | 28,772 | 38,326 | ||||||||||
| Derivatives - Energy Related Assets | 5,434 | 1,077 | 5,464 | 7,327 | ||||||||||
| Other Prepayments and Current Assets | 13,853 | 13,405 | 11,280 | 12,670 | ||||||||||
| Total Current Assets | 149,799 | 144,139 | 198,097 | 196,527 | ||||||||||
| Regulatory and Other Noncurrent Assets: | ||||||||||||||
| Regulatory Assets | 410,746 | 323,434 | 492,365 | 469,224 | ||||||||||
| Long-Term Receivables | 25,758 | 24,950 | 25,531 | 25,851 | ||||||||||
| Derivatives - Energy Related Assets | 373 | 64 | 15 | 5 | ||||||||||
| Other | 12,303 | 2,666 | 17,491 | 17,372 | ||||||||||
| Total Regulatory and Other Noncurrent Assets | 449,180 | 351,114 | 535,402 | 512,452 | ||||||||||
| Total Assets | $ | 2,551,923 | $ | 2,281,576 | $ | 3,118,236 | $ | 2,865,974 | ||||||
The accompanying notes are an integral part of the financial statements.
SOUTH JERSEY GAS COMPANY
BALANCE SHEETS
(In Thousands, except per share amounts)
| December 31, 2016 | December 31, 2015 | December 31, 2018 | December 31, 2017 | |||||||||||
| Capitalization and Liabilities | ||||||||||||||
| Common Equity: | ||||||||||||||
| Equity: | ||||||||||||||
| Common Stock, Par Value $2.50 per share: | ||||||||||||||
| Authorized - 4,000,000 shares | ||||||||||||||
| Outstanding - 2,339,139 shares | $ | 5,848 | $ | 5,848 | $ | 5,848 | $ | 5,848 | ||||||
| Other Paid-In Capital and Premium on Common Stock | 315,827 | 250,827 | 355,744 | 355,744 | ||||||||||
| Accumulated Other Comprehensive Loss | (14,934 | ) | (12,862 | ) | (22,357 | ) | (25,997 | ) | ||||||
| Retained Earnings | 533,159 | 464,114 | 668,787 | 585,838 | ||||||||||
| Total Common Equity | 839,900 | 707,927 | ||||||||||||
| Total Equity | 1,008,022 | 921,433 | ||||||||||||
| Long-Term Debt (See Note 1) | 423,177 | 577,454 | ||||||||||||
| Long-Term Debt | 874,507 | 758,052 | ||||||||||||
| Total Capitalization | 1,263,077 | 1,285,381 | 1,882,529 | 1,679,485 | ||||||||||
| Current Liabilities: | ||||||||||||||
| Notes Payable | 104,300 | 134,400 | 107,500 | 52,000 | ||||||||||
| Current Portion of Long-Term Debt | 215,909 | 27,909 | 18,909 | 63,809 | ||||||||||
| Accounts Payable - Commodity | 23,815 | 8,936 | 48,490 | 43,341 | ||||||||||
| Accounts Payable - Other | 45,370 | 40,579 | 52,966 | 41,365 | ||||||||||
| Accounts Payable - Related Parties | 11,216 | 7,552 | 12,563 | 17,029 | ||||||||||
| Derivatives - Energy Related Liabilities | 1,372 | 5,489 | 2,146 | 9,270 | ||||||||||
| Derivatives - Other Current | 386 | — | 343 | 389 | ||||||||||
| Customer Deposits and Credit Balances | 45,816 | 19,531 | 23,862 | 41,656 | ||||||||||
| Environmental Remediation Costs | 45,018 | 48,323 | 33,022 | 66,040 | ||||||||||
| Taxes Accrued | 855 | 1,930 | 1,891 | 1,760 | ||||||||||
| Pension Benefits | 2,428 | 2,227 | 3,597 | 2,353 | ||||||||||
| Interest Accrued | 5,369 | 5,989 | 7,134 | 7,615 | ||||||||||
| Other Current Liabilities | 8,011 | 5,686 | 9,444 | 7,027 | ||||||||||
| Total Current Liabilities | 509,865 | 308,551 | 321,867 | 353,654 | ||||||||||
| Regulatory and Other Noncurrent Liabilities: | ||||||||||||||
| Regulatory Liabilities | 49,121 | 42,841 | 286,539 | 287,105 | ||||||||||
| Deferred Income Taxes - Net | 469,408 | 432,674 | 325,886 | 280,746 | ||||||||||
| Environmental Remediation Costs | 108,029 | 74,871 | 115,049 | 105,656 | ||||||||||
| Asset Retirement Obligations | 58,674 | 57,219 | 79,890 | 58,714 | ||||||||||
| Pension and Other Postretirement Benefits | 81,800 | 65,491 | 96,053 | 88,871 | ||||||||||
| Derivatives - Energy Related Liabilities | — | 351 | 43 | 170 | ||||||||||
| Derivatives - Other | 6,979 | 7,631 | ||||||||||||
| Derivatives - Other Noncurrent | 5,524 | 6,639 | ||||||||||||
| Other | 4,970 | 6,566 | 4,856 | 4,934 | ||||||||||
| Total Regulatory and Other Noncurrent Liabilities | 778,981 | 687,644 | 913,840 | 832,835 | ||||||||||
| Commitments and Contingencies (Note 12) | ||||||||||||||
| Commitments and Contingencies (Note 15) | ||||||||||||||
| Total Capitalization and Liabilities | $ | 2,551,923 | $ | 2,281,576 | $ | 3,118,236 | $ | 2,865,974 | ||||||
The accompanying notes are an integral part of the financial statements.
SOUTH JERSEY GAS COMPANY
STATEMENTS OF CHANGES IN COMMON EQUITY AND COMPREHENSIVE INCOME
(In Thousands)
| Common Stock | Other Paid-In Capital and Premium on Common Stock | Accumulated Other Comprehensive Loss | Retained Earnings | Total | Common Stock | Other Paid-In Capital and Premium on Common Stock | Accumulated Other Comprehensive Loss | Retained Earnings | Total | |||||||||||||||||||||||||||||
| Balance at January 1, 2014 | $ | 5,848 | $ | 225,972 | $ | (10,869 | ) | $ | 390,018 | $ | 610,969 | |||||||||||||||||||||||||||
| Balance at January 1, 2016 | $ | 5,848 | $ | 250,827 | $ | (12,862 | ) | $ | 464,114 | 707,927 | ||||||||||||||||||||||||||||
| Net Income | 66,483 | 66,483 | $ | 69,045 | 69,045 | |||||||||||||||||||||||||||||||||
| Other Comprehensive Gain, Net of Tax: (a) | (3,610 | ) | (3,610 | ) | ||||||||||||||||||||||||||||||||||
| Other Comprehensive Loss, Net of Tax | (2,072 | ) | (2,072 | ) | ||||||||||||||||||||||||||||||||||
| Additional Investment by Shareholder | 65,000 | 65,000 | ||||||||||||||||||||||||||||||||||||
| Balance at December 31, 2016 | 5,848 | 315,827 | (14,934 | ) | 533,159 | 839,900 | ||||||||||||||||||||||||||||||||
| Net Income | 72,557 | 72,557 | ||||||||||||||||||||||||||||||||||||
| Other Comprehensive Loss, Net of Tax | (11,063 | ) | (11,063 | ) | ||||||||||||||||||||||||||||||||||
| Cash Dividends Declared – Common Stock | (18,201 | ) | (18,201 | ) | (20,000 | ) | (20,000 | ) | ||||||||||||||||||||||||||||||
| Additional Investment by Shareholder | 25,000 | 25,000 | 40,000 | 40,000 | ||||||||||||||||||||||||||||||||||
| Excess Tax Benefit - See Note 1 | — | 122 | 122 | |||||||||||||||||||||||||||||||||||
| Tax Deficiency from Restricted Stock Plan | (73 | ) | (73 | ) | (83 | ) | — | (83 | ) | |||||||||||||||||||||||||||||
| Balance at December 31, 2014 | 5,848 | 250,899 | (14,479 | ) | 438,300 | 680,568 | ||||||||||||||||||||||||||||||||
| Balance at December 31, 2017 | 5,848 | 355,744 | (25,997 | ) | 585,838 | 921,433 | ||||||||||||||||||||||||||||||||
| Net Income | 66,578 | 66,578 | 82,949 | 82,949 | ||||||||||||||||||||||||||||||||||
| Other Comprehensive Loss, Net of Tax: (a) | 1,617 | 1,617 | ||||||||||||||||||||||||||||||||||||
| Cash Dividends Declared – Common Stock | (40,764 | ) | (40,764 | ) | ||||||||||||||||||||||||||||||||||
| Additional Investment by Shareholder | — | |||||||||||||||||||||||||||||||||||||
| Tax Deficiency from Restricted Stock Plan | (72 | ) | (72 | ) | ||||||||||||||||||||||||||||||||||
| Other Comprehensive Loss, Net of Tax | 3,640 | 3,640 | ||||||||||||||||||||||||||||||||||||
| Balance at December 31, 2015 | 5,848 | 250,827 | (12,862 | ) | 464,114 | 707,927 | ||||||||||||||||||||||||||||||||
| Net Income | 69,045 | 69,045 | ||||||||||||||||||||||||||||||||||||
| Other Comprehensive Gain, Net of Tax: (a) | (2,072 | ) | (2,072 | ) | ||||||||||||||||||||||||||||||||||
| Additional Investment by Shareholder | 65,000 | 65,000 | ||||||||||||||||||||||||||||||||||||
| Tax Deficiency from Restricted Stock Plan | — | — | ||||||||||||||||||||||||||||||||||||
| Balance at December 31, 2016 | $ | 5,848 | $ | 315,827 | $ | (14,934 | ) | $ | 533,159 | $ | 839,900 | |||||||||||||||||||||||||||
| Balance at December 31, 2018 | $ | 5,848 | $ | 355,744 | $ | (22,357 | ) | $ | 668,787 | $ | 1,008,022 | |||||||||||||||||||||||||||
The accompanying notes are an integral part of the financial statements.
Disclosure of Changes in Accumulated Other Comprehensive Loss Balances (a)
(In Thousands)
| Postretirement Liability Adjustment | Unrealized Gain (Loss) on Available-for-Sale Securities | Unrealized Gain (Loss) on Derivatives | Accumulated Other Comprehensive Income (Loss) | Postretirement Liability Adjustment (A) | Unrealized Gain (Loss) on Available-for-Sale Securities (B) | Unrealized Gain (Loss) on Derivatives (B) | Accumulated Other Comprehensive Income (Loss) | |||||||||||||||||||||||
| Balance at January 1, 2014 | $ | (10,672 | ) | $ | 397 | $ | (594 | ) | $ | (10,869 | ) | |||||||||||||||||||
| Changes During Year | (3,165 | ) | (472 | ) | 27 | (3,610 | ) | |||||||||||||||||||||||
| Balance at December 31, 2014 | (13,837 | ) | (75 | ) | (567 | ) | (14,479 | ) | ||||||||||||||||||||||
| Changes During Year | 1,617 | (23 | ) | 23 | 1,617 | |||||||||||||||||||||||||
| Balance at December 31, 2015 | (12,220 | ) | (98 | ) | (544 | ) | (12,862 | ) | ||||||||||||||||||||||
| Balance at January 1, 2016 | $ | (12,220 | ) | $ | (98 | ) | $ | (544 | ) | $ | (12,862 | ) | ||||||||||||||||||
| Changes During Year | (2,197 | ) | 98 | 27 | (2,072 | ) | (2,197 | ) | 98 | 27 | (2,072 | ) | ||||||||||||||||||
| Balance at December 31, 2016 | $ | (14,417 | ) | $ | — | $ | (517 | ) | $ | (14,934 | ) | (14,417 | ) | — | (517 | ) | (14,934 | ) | ||||||||||||
| Changes During Year | (11,090 | ) | — | 27 | (11,063 | ) | ||||||||||||||||||||||||
| Balance at December 31, 2017 | (25,507 | ) | — | (490 | ) | (25,997 | ) | |||||||||||||||||||||||
| Changes During Year | 3,606 | 34 | 3,640 | |||||||||||||||||||||||||||
| Balance at December 31, 2018 | $ | (21,901 | ) | $ | — | $ | (456 | ) | $ | (22,357 | ) | |||||||||||||||||||
(B) Determined using a combined average statutory tax rate of 25% for 2018; 39% for 2017; and 40% for 2016.
The accompanying notes are an integral part of the financial statements.
| 1. | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: |
GENERAL - SJI provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries:
| SJIU is a holding company that owns SJG, and as of July 1, 2018, ETG and ELK (see "Acquisition" below). |
| * | SJG is a regulated natural gas utility which distributes natural gas in the seven southernmost counties of New Jersey. |
| * | ETG is a regulated natural gas utility which distributes natural gas in seven counties in northern and central New Jersey. |
| * | ELK is a regulated natural gas utility which distributes natural gas in northern Maryland. |
| ▪ |
| ▪ |
| ▪ | SJEX owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. |
| ▪ | Marina develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include: |
ACLE, BCLE, SCLE and SXLE, which owns and operates landfill gas-to-energy production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.
MCS, NBS and SBS, which owned and operated solar-generation sites located in New Jersey. These entities were sold in October 2018.
| ▪ | SJESP receives commissions on service contracts from a third party. |
Midstream invests in infrastructure and other midstream projects, including a current project to build an approximately 118-mile natural gas pipeline in Pennsylvania and New Jersey.
BASIS OF PRESENTATION - South Jersey Industries, Inc. (SJI) owns allSJI's consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries (including SJG) and subsidiaries in which SJI has a controlling interest. All significant intercompany accounts and transactions have been eliminated in consolidation. Beginning as of the outstanding common stockdate of South Jersey Gas Company (SJG).their acquisition, July 1, 2018, SJI is reporting on a consolidated basis the combined operations of ETG and ELK, along with its other wholly-owned and controlled subsidiaries. In ourmanagement's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present ourSJI's financial position, and operating results and cash flows at the dates and for the periods presented.
Certain reclassifications have been made to theSJI's and SJG's prior period's balance sheets, as well as the prior period's long-term debt carrying value in Note 8,period consolidated statements of income to conform to the current period presentation. The unamortized debt issuancenon-service cost components of net periodic pension and postretirement benefit costs previouslyare now included in "Regulatoryas a reduction to Other Income and Other Noncurrent Assets" on the balance sheets were reclassifiedExpense, as opposed to "Long-Term Debt"being recorded as an Operations Expense, to conform towith ASU 2015-03,2017-07, which is described below under "New Accounting Pronouncements." This caused a reduction to both Operations Expense and Other Income on the consolidated statement of income for the years ended December 31, 2017 and 2016. This also caused a reclassification caused theto SJI's prior periods long-term debt carrying valueperiod segments disclosure in Note 8 to be adjusted.increase Operating Income within both the SJG Utility Operations and Corporate & Services segments for the years ended December 31, 2017 and 2016. This also caused a reduction to (1) Operations, Impairment Charges and Maintenance Including Fixed Charges and (2) Other Income and Expense within the summarized quarterly results of SJI's and SJG's operations for the year ended December 31, 2017 (see "Quarterly Financial Data (Unaudited)").
Certain reclassifications have been made to SJI's prior period segments disclosures to conform to the current period presentation. The activities of SJI Midstream, which were presented in the Corporate & Services segment during the years ended December 31, 2017 and 2016, are now separated into the Midstream segment for the year ended December 31, 2018. This caused prior period reclassifications to Interest Charges and Income Taxes in Note 8.
Certain reclassifications have been made to SJI's prior period consolidated balance sheet to conform to the current period presentation. Identifiable Intangible Assets are now recorded in Other Noncurrent Assets as of December 31, 2018, causing a prior period reclassification to the consolidated balance sheet as of December 31, 2017.
ACQUISITION - On July 1, 2018, SJI, through its wholly-owned subsidiary SJIU, acquired the assets of ETG and ELK from Pivotal Utility Holdings, Inc., a subsidiary of Southern Company Gas (collectively, the "Acquisition"), for total consideration of $1.74 billion (see Note 20). In the second quarter of 2018, SJI completed public equity offerings and issued long-term debt to help fund the Acquisition (see Notes 6 and 14, respectively).
AGREEMENT TO SELL SOLAR ASSETS - On June 27, 2018, the Company, through its wholly-owned subsidiary, Marina, entered into a series of agreements whereby Marina agreed to sell its portfolio of solar energy assets (the “Transaction”) to a third-party buyer. As part of the Transaction, Marina has agreed to sell its distributed solar energy projects located across New Jersey, Maryland, Massachusetts and Vermont with total capacity of approximately 204 MW (the “Projects”). As part of the Transaction, Marina sold the assets comprising the Projects or, in some cases, 100% of the equity interests of certain special purpose companies wholly-owned by Marina that own the assets comprising certain Projects, including MCS, NBS and SBS. The sale of individual Projects is occurring on a rolling basis as the conditions precedent to each closing have been satisfied, including obtaining certain regulatory filings and receipt of consents to assignment of project contracts and permits. The individual purchase prices for those Projects have been adjusted to account for Project revenues retained by Marina during the period prior to such closings. Also in connection with the Transaction, Marina will lease certain of the Projects that have not yet passed the fifth anniversary of their placed-in-service dates for U.S. federal income tax purposes back from the buyer from the date each such project is acquired by the buyer until the later of the first anniversary of the applicable acquisition date and the fifth anniversary of the applicable placed-in-service date of the project.
In July 2018, as part of the Transaction, Marina received a cash payment of $62.5 million for the sale of certain SRECs.
During the fourth quarter of 2018, the Company closed on the majority of these projects, including the wholly-owned subsidiaries MCS, NBS and SBS, with each project sold having met all conditions to satisfy closing as defined above. Total consideration received in the fourth quarter related to these sales was $228.1 million. The Company currently has projects that have not yet closed and are expected to be sold in 2019. The value of these unsold assets is $59.6 million and is recorded as Assets Held For Sale on the consolidated balance sheets as of December 31, 2018, where they will remain until they are transferred to a buyer.
The Company also closed in the fourth quarter of 2018 on a separate solar project for total consideration of $4.8 million.
In total, the Company recorded pre-tax gains on the sale of all projects discussed above of $17.6 million in Net Gain on Sales of Assets on the consolidated statements of income, with these gains pertaining to those projects that were not impaired as discussed under "Impairment of Long-Lived Assets" below.
SALE OF RETAIL GAS OPERATIONS OF SJE - On November 30, 2018, SJI sold the retail gas assets of SJE for total consideration of $15.0 million. As a result of this agreement, SJE no longer acquires, transports or markets natural gas for retail markets. The Company recognized a pre-tax loss on this sale of $2.2 million, which is recorded in Net Gain on Sales of Assets on the consolidated statements of income.
EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on ourthe consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss.AOCL. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary. Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. SJI includes the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in Earnings (Loss) of Affiliated Companies (see Note 3). An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary. No impairment losses were recorded on Investmentsequity investments during 2016, 20152018, 2017 or 2014.2016. SJG does not hold any equity investments.
ESTIMATES AND ASSUMPTIONS - We prepare ourThe consolidated financial statements were prepared to conform with accounting principles generally accepted in the United States of America (GAAP).GAAP. Management makes estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, revenue recognition and revenue recognition.goodwill.
| 2016 | 2015 | ||||||
| Utility Plant: | |||||||
| Production Plant | $ | 296 | $ | 296 | |||
| Storage Plant | 60,661 | 20,872 | |||||
| Transmission Plant | 257,169 | 252,934 | |||||
| Distribution Plant | 1,871,703 | 1,702,148 | |||||
| General Plant | 169,464 | 163,420 | |||||
| Other Plant | 1,855 | 1,855 | |||||
| Utility Plant in Service | 2,361,148 | 2,141,525 | |||||
| Construction Work in Progress | 62,986 | 69,714 | |||||
| Total Utility Plant | $ | 2,424,134 | $ | 2,211,239 | |||
ARO activity during 2016 and 2015 was as follows (in thousands):
| 2016 | 2015 | 2018 | 2017 | ||||||||||||
| ARO as of January 1, | $ | 57,219 | $ | 41,976 | |||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | |||||||||||||||
| AROs as of January 1, | $ | 59,497 | $ | 59,427 | |||||||||||
| Accretion | 1,908 | 1,658 | 1,909 | 1,955 | |||||||||||
| Additions | 1,098 | 621 | 297 | 1,008 | |||||||||||
| Settlements | (1,551 | ) | (1,110 | ) | (3,402 | ) | (2,893 | ) | |||||||
| Revisions in Estimated Cash Flows * | — | 14,074 | |||||||||||||
| ARO as of December 31, | $ | 58,674 | $ | 57,219 | |||||||||||
| Revisions in Estimated Cash Flows (A) | 21,862 | — | |||||||||||||
| ARO's as of December 31, | $ | 80,163 | $ | 59,497 | |||||||||||
| 2018 | 2017 | ||||||||||||||
| SJG: | |||||||||||||||
| AROs as of January 1, | $ | 58,714 | $ | 58,674 | |||||||||||
| Accretion | 1,880 | 1,925 | |||||||||||||
| Additions | 297 | 1,008 | |||||||||||||
| Settlements | (2,863 | ) | (2,893 | ) | |||||||||||
| Revisions in Estimated Cash Flows (A) | 21,862 | — | |||||||||||||
| ARO's as of December 31, | $ | 79,890 | $ | 58,714 | |||||||||||
Utility Plant balances and Nonutility Property and Equipment as of December 31, 2018 and 2017 were comprised of the following (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | SJG | |||||||||||||||
| 2018 | 2017 | 2018 | 2017 | |||||||||||||
| Utility Plant | ||||||||||||||||
| Production Plant | $ | 1,281 | $ | 296 | $ | 296 | $ | 296 | ||||||||
| Storage Plant | 92,769 | 61,909 | 61,996 | 61,909 | ||||||||||||
| Transmission Plant | 326,906 | 258,598 | 306,654 | 258,598 | ||||||||||||
| Distribution Plant | 3,466,101 | 2,044,421 | 2,212,831 | 2,044,421 | ||||||||||||
| General Plant | 303,219 | 175,599 | 241,095 | 175,599 | ||||||||||||
| Other Plant | 1,964 | 1,855 | 1,855 | 1,855 | ||||||||||||
| Utility Plant In Service | 4,192,240 | 2,542,678 | 2,824,727 | 2,542,678 | ||||||||||||
| Construction Work In Progress | 148,873 | 109,566 | 82,475 | 109,566 | ||||||||||||
| Total Utility Plant | $ | 4,341,113 | $ | 2,652,244 | $ | 2,907,202 | $ | 2,652,244 | ||||||||
| Nonutility Property and Equipment | ||||||||||||||||
| Solar Assets (A) | $ | — | $ | 582,379 | $ | — | $ | — | ||||||||
| Cogeneration Assets | 126,228 | 125,614 | — | — | ||||||||||||
| Other Assets | 26,004 | 33,034 | — | — | ||||||||||||
| Total Nonutility Property and Equipment | $ | 152,232 | $ | 741,027 | $ | — | $ | — | ||||||||
(A) All remaining solar assets are recorded as Assets Held for Sale in the consolidated balance sheets as of December 31, 2018.
DEPRECIATION - We depreciate utility plant on a straight-line basis over the estimated remaining lives of the various property classes. These estimates are periodically reviewed and adjusted as required after BPUBPU/MPSC approval. The composite annual rate for all depreciable utility property was approximately 2.3% in 2018, and 2.2% in each of 2016, 20152017 and 2014.2016. The actual composite rate may differ from the approved rate as the asset mix changes over time. Except for retirements outside of the normal course of business, accumulated depreciation is charged with the cost of depreciable utility property retired, less salvage. Nonutility property depreciation is computed on a straight-line basis over the estimated useful lives of the property, ranging up to 50 years. Gain or loss on the disposition of nonutility property is recognized in operating income. As of December 31, 2018, total accumulated depreciation for utility and nonutility property and equipment was $787.2 million and $52.6 million, respectively. As of December 31, 2018, total accumulated depreciation for SJG utility property and equipment was $523.7 million.
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 14 for the total unamortized debt issuance costs that are recorded as a reduction to long-term debt on the consolidated balance sheets of SJI and SJG.
IMPAIRMENT OF LONG-LIVED ASSETS - Long-lived assets that are held and $4.4 million in 2014. The increase in 2016 represents the interest on the Company's investment in Utility Plant under the BPU-approved AIRP program. Under the AIRP, qualified capital expenditures continued to accrue interest on construction until such projects were rolled into customer rates and recovery of the expenditures commenced.
The Transaction described above under "Agreement to Sell Solar Assets" triggered an indicator of impairment in the second quarter of 2018 as the purchase price was less than the carrying amount for several of the assets sold and, as a result, several assets were considered to be impaired. The Company measured the impairment loss as the difference between the carrying amount of the respective assets and the fair value, which was determined using the purchase price and the expected cash flows from the assets, including potential price reductions resulting from the timing needed to satisfy all required closing conditions. As a result, the Company recorded an impairment charge within the on-site energy production segment of $99.2 million (pre-tax) in Impairment Charges on the consolidated statements of income for the year ended December 31, 2018, to reduce the carrying amount of several assets to their fair market value.
In 2017, SJI had reason to believe that, due to a significant decline in the market prices of Maryland SRECs, combined with increase of operating expenses, the full carrying value of SJI's Maryland solar facilities may not be recoverable. As a result, SJI performed an impairment test on the respective assets which led to an impairment charge of $43.9 million for the year ended December 31, 2017. Also, during the fourth quarter of 2017, as the Company updated its estimated future cash flows for the rest of its solar portfolio, the Company determined that the expected future undiscounted cash flows for certain individual solar facilities were below their carrying value and the assets were considered impaired. As a result, SJI recorded an additional impairment charge of $27.4 million in 2017. The fair values of the impaired solar facilities were determined using an income approach by applying a discounted cash flow methodology to the future estimated cash flows, which were Level 3 fair value measurements. The key inputs to the methodology were forecasted SREC and electric revenues, operating expenses, salvage values, and discount rates.
Also in the fourth quarter of 2017, SJI observed its LFGTE assets were incurring continuing cash flow losses specifically due to larger than expected decreases in electric generation and increasing operating expenses, and as a result had reason to believe the carrying value of these assets may no longer be recoverable. As a result, SJI performed an impairment test on the respective assets which led to an impairment charge of $16.5 million for the year ended December 31, 2017. The fair values of the LFGTE assets were determined using a combination of market and cost approaches, which considers similar market transactions that are specific to the LFGTE assets. The cost and market approaches used were deemed Level 3 fair value measurements. In the fourth quarter of 2018, SJI observed its LFGTE assets were continuing to incur cash flow losses for similar reasons, and as a result had reason to believe the remaining carrying value of these assets may no longer be recoverable. As a result, the remaining carrying value of all such assets was written off via an impairment charge of $6.1 million (pre-tax) during the fourth quarter of 2018.
For the years ended 2016, 2015December 31, 2018 and 2014, no significant impairments2017, SJI had total long-lived asset impairment charges (pre-tax) of $105.3 million and $87.8 million, respectively. These impairment charges are recorded within Impairment Charges on the consolidated statements of income and are included within the On-Site Energy Production segment. No impairment charges were identified.recorded at SJI for the year ended December 31, 2016. No impairment charges were recorded at SJG for the years ended December 31, 2018, 2017 and 2016. Additional impairment charges on assets other than long-lived assets were recorded during the year ended December 31, 2017, see Note 21.
Initially and on an ongoing basis, we assess whether derivatives designated as hedges are highly effective in offsetting changes in cash flows or fair values of the hedged items. We discontinue hedge accounting prospectively if we decide to discontinue the hedging relationship; determine that the anticipated transaction is no longer likely to occur; or determine that a derivative is no longer highly effective as a hedge. In the event that hedge accounting is discontinued, we will continue to carry the derivative on the balance sheet at its current fair value and recognize subsequent changes in fair value in current period earnings. Unrealized gains and losses on the discontinued hedges that were previously included in AOCL will be reclassified into earnings when the forecasted transaction occurs, or when it is probable that it will not occur. Hedge accounting has been discontinued for all remaining derivatives that were designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives – Energy Related Assets or Derivatives – Energy Related Liabilities on the balance sheets. The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval.instruments. As a result, the net unrealized pre-tax gains and losses foron these energyderivatives, that were previously recorded in AOCL on the consolidated balance sheets, are being recorded into earnings over the remaining life of the derivative. In March 2017, SJI entered into a new interest rate derivative and amended the existing interest rate derivative linked to unrealized losses previously recorded in AOCL (see Note 16).
GAS EXPLORATION AND DEVELOPMENT - SJI capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related commodity contractsto unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment charges were recorded on these costs during the years ended December 31, 2018, 2017 and 2016. As of December 31, 2018 and 2017, $8.6 million and $8.7 million , respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with realized gainsNonutility Property and losses in RegulatoryEquipment and Other Noncurrent Assets or Regulatory Liabilities on the consolidated balance sheets.
TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of December 31, 2018 and 2017, SJI held 233,482 and 216,642 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI.
AFUDC - SJI and SJG has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives,record AFUDC, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives-Other on the balance sheets. The fair value represents the amount SJG would haveestimated debt and equity costs of capital funds that are necessary to payfinance the counterparty to terminate these contracts asconstruction of those dates. Subject to BPU approval,new regulated facilities. While cash is not realized currently, AFUDC increases the market value upon termination of these interest rate derivatives can be recovered in ratesregulated revenue requirement and therefore, these unrealized losses have beenis included in Other Regulatory Assets inrate base and recovered over the balance sheets.service life of the asset through a higher rate base and higher depreciation.
CASH AND CASH EQUIVALENTS - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents.
BUSINESS COMBINATION - The Company applies the acquisition method to account for business combinations. The consideration transferred for an acquisition is the fair value of the assets transferred, the liabilities incurred by the acquirer and the equity interests issued by the acquirer. Acquisition-related costs are expensed as incurred. Identifiable assets acquired and liabilities and contingent liabilities assumed in a business combination are measured initially at their fair values at the acquisition date. The excess of the consideration transferred over the fair value of the identifiable net assets acquired is recorded as goodwill (see Note 20).
AMA - On July 1, 2018, SJRG purchased from a third party an AMA whereby SJRG will manage the pipeline capacity of ETG. Total cash payment was $11.3 million. The AMA expires on March 31, 2022. Under the AMA, SJRG will pay ETG an annual fee of $4.25 million, plus additional profit sharing as defined in the AMA. The amounts received by ETG will be credited to its BGSS clause and returned to its ratepayers. The total purchase price was allocated as follows (in thousands):
| Natural Gas in Storage | $ | 9,685 | ||
| Intangible Asset | 19,200 | |||
| Profit Sharing - Other Liabilities | (17,546 | ) | ||
| Total Consideration | $ | 11,339 | ||
As of December 31, 2018 the balance of the intangible asset is $16.6 million and is recorded to Other Current and Noncurrent Assets on the consolidated balance sheets of SJI, with the reduction being due to amortization. As of December 31, 2018, the balance in the liability is $17.0 million and is recorded to Regulatory Liabilities on the consolidated balance sheets of SJI, with the change resulting from profit sharing earned.
ERIP - The Company offered an ERIP to non-union, non-Officer employees over the age of 55 years old with 20 or more years of service to the Company as well as to Officers over the age of 55 years old with 5 or more years of service to the Company. Communication was made to these employees in the fourth quarter 2018, with acceptance made by non-union employees by December 15, 2018 and by Officers by December 31, 2018. Total cost to the Company for the ERIP was $13.4 million, of which $8.3 million is included in Operations Expense on the consolidated statements of income as of December 31, 2018, and $5.1 million was related to employees of SJG and recorded as a Regulatory Asset on the consolidated balance sheets. These costs include severances, curtailments and special termination benefits on the Company's pension, SERP and OPEB plans.
CURRENT PORTION OF LONG-TERM DEBT - The Company has $733.9 million of long-term debt that is due within the next year. The Company expects to significantly reduce this debt in 2019 using cash provided from the settlement of its equity forward sale agreement (see Note 22), the sale of the remaining solar assets as noted above, along with the sale of other assets considered non-core to the business. The remaining long-term debt that is due within the next year is expected to be paid off by utilizing funds provided from refinancing activity and from the revolving credit facility. The Company anticipates refinancing approximately $500.0 million of outstanding long-term debt during 2019.
Management believes that actions presently being taken to pay off the long-term debt that is due within the next year will be successful as the Company has been successful in refinancing debt in the past. However, there can be no assurance that success will continue in the future. No adjustments have been made to the financial statements to account for this uncertainty.
NEW ACCOUNTING PRONOUNCEMENTS- Other than as described below, no new accounting pronouncement issued or effective during 2016, 2015 or 2014 had, or is expected to have, a material impact on the consolidated financial statements.
In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition ofunder this new standard is for an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services.services, with a five-step model for recognizing and measuring revenue from contracts with customers. The new standard also requires enhanced disclosure regarding the nature, amount, timing and uncertainty of revenues and the related cash flows arising from contracts with customers. In connection with this new standard, the FASB has issued several amendments to ASU 2014-09, as follows:
In March 2016, the FASB issued ASU 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net). This standard improves the implementation guidance on principal versus agent considerations and whether an entity reports revenue on a gross or net basis.
In April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing. This standard clarifies identifying performance obligations and the licensing implementation guidance.
In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients. This standard provides additional guidance on (a) the objective of the collectibility criterion, (b) the presentation of sales tax collected from customers, (c) the measurement date of non-cash consideration received, (d) practical expedients in respect of contract modifications and completed contracts at transition, and (e) disclosure of the effects of the accounting change in the period of adoption.
In December 2016, the FASB issued ASU No. 2016-20, Technical Corrections and Improvements to (Topic 606), Revenue from Contracts with Customers, which amends certain narrow aspects of the guidance, including the disclosure of remaining performance obligations and prior-period performance obligations, as well as other amendments to the guidance on loan guarantee fees, contract costs, refund liabilities, advertising costs and the clarification of certain examples.
The new guidance in ASU 2014-09, as well as all amendments discussed above, iswas effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Management has formed an implementation team that is currently evaluating
On January 1, 2018, SJI and SJG adopted ASU 2014-09 and all amendments, in accordance with the impact that adoption of this guidance will have on the Company's financial statement results. Based on the review of customer contracts to date, the Company is not anticipating a material impact to its statements of consolidated income, cash flows or consolidated balance sheets upon adoption. The Company expects to transition toin ASC 606. SJI and SJG adopted the new guidance using the modified retrospective approach.
In January 2016, the FASB issued ASU 2016-01, Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities, which enhances the reporting model for financial instruments and includes amendments to address aspects of recognition, measurement, presentation and disclosure. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017. Early adoption is permitted for only certain portions of the new guidance. Management is currently determining the impact that adoptionAdoption of this guidance willdid not have an impact on the Company's financial statement results.results of SJI or SJG.
In FebruaryMarch 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which establishes a new lease accounting model for lessees. The new standard requires lessees to recognize substantially all leases be recognized by lessees on their balance sheet as a right-of-use asset and corresponding lease liability, including leases currently accounted for as operating leases. The new standard also will result in enhanced quantitative and qualitative disclosures, including significant judgments made by management, to provide greater insight into the extent of revenue and expense recognized and expected to be recognized from existing leases. The accounting for leases by the lessor remains relatively the same. In connection with this new standard, the FASB has issued the following amendments to ASU 2016-02:
In January 2018, the FASB issued an amendment to clarify the application of the new lease guidance to land easements and provided relief concerning adoption efforts for existing land easements that are not accounted for as leases under current GAAP.
In July 2018, the FASB issued ASU 2018-10 and 2018-11, which included a number of technical corrections and improvements to this standard, including an additional option for transition. The guidance initially required a modified retrospective transition method of adoption, under which lessees and lessors were to recognize and measure leases at the beginning of the earliest period presented. The additional, optional transition method allows an entity to initially apply the requirements of the lease standard at the adoption date, and avoid restating the comparative periods.
In December 2018, the FASB issued ASU 2018-20, Narrow-Scope Improvements for Lessors. The amendments in this ASU permit lessors, as an accounting policy election, to not evaluate whether certain sales taxes and other similar taxes are lessor costs or lessee costs. A lessor making this election will exclude from the consideration in the contract all collections from lessees of taxes within the scope of the election and will provide certain disclosures. The amendments in this ASU related to certain lessor costs also require lessors to exclude from variable payments, and therefore revenue, lessor costs paid by lessees directly to third parties, and require lessors to account for costs excluded from the consideration of a contract that are paid by the lessor and reimbursed by the lessee as variable payments, and record those reimbursed costs as revenue. Lastly, the amendments in this ASU related to recognizing variable payments for contracts with lease and nonlease components require lessors to allocate (rather than recognize as currently required) certain variable payments to the lease and nonlease components when the changes in facts and circumstances on which the variable payment is based occur.
The new guidance in ASU 2016-02, as well as all amendments discussed above, is effective for annual periods, includingfiscal years, and interim periods within those annual periods,years, beginning after December 15, 2018, with early adoption permitted.
Management is currentlyhas formed an implementation team that has completed the process of inventorying all current contracts, including those of ETG and ELK, and has determined the population of leases that will be in scope under the new guidance. Management will elect the optional transition guidance granted by ASU 2018-11 and will apply the requirements of the lease standard at the adoption date, January 1, 2019, and will not restate comparative periods. Management has elected to apply certain of the practical expedients included in ASU 2016-02 and its related amendments to its entire population of leases. Specifically, the Company will elect the transition practical expedient package which states that for all leases that have commenced before the effective date, an entity need not reassess whether any expired or existing contracts are or contain leases, an entity need not reassess the lease classification for any expired or existing leases, and an entity need not reassess initial direct costs for any existing leases. The Company has elected not to use hindsight when determining lease term at the effective date.
Management believes that the impact that adoptionon its statement of this guidance will have on the Company's financial position, its statement results.
date.
In October 2016, the FASB issued ASU 2016-16, Income Taxes (Topic 740);: Intra-Entity Transfers of Assets Other Than Inventory.This standard requires recognition of the current and deferred income tax effects of an intra-entity asset transfer, other than inventory, when the transfer occurs, as opposed to current GAAP, which requires companies to defer the income tax effects of intra-entity asset transfers until the asset has been sold to an outside party. The income tax effects of intra-entity inventory transfers will continue to be deferred until the inventory is sold. ASU 2016-16 is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within those annual reporting periods, with early adoption permitted. The standard is required to be adopted on a modified retrospective basis with a cumulative-effect adjustment recorded to retained earnings as of the beginning of the period of adoption. Management is currently determining the impact that adoptionAdoption of this guidance willdid not have an impact on the Company's financial statement results.
In January 2017, the FASB issued ASU 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business. This new standard provides amended and clarifying guidance regarding whether an integrated set of assets and activities acquired is deemed the acquisition of a business (and, thus, accounted for as a business combination) or the acquisition of assets. This ASU is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years, with early adoption permitted. Management is currently determining the impact that adoptionAdoption of this guidance willdid not have an impact on the Company's financial statement results.results of SJI or SJG.
In January 2017, the FASB issued ASU 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment. The update simplifies how an entity is required to test goodwill for impairment by eliminating Step 2 from the goodwill impairment test. Step 2 measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount. The amendments in this Update are effective for annual and any interim impairment tests performed in periods beginning after December 31, 2019. Management is currently determining the impact that adoption of this guidance will have on the Company'sfinancial statements of SJI and SJG.
In March 2017, the FASB issued ASU 2017-07, Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. This ASU is designed to improve guidance related to the presentation of defined benefit costs in the income statement. In particular, this ASU requires an employer to report the service cost component in the same line item(s) as other compensation costs and requires the other components of net periodic pension and postretirement benefit costs to be separately presented in the consolidated statements of income outside of operating income. The standard is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. Adoption of this guidance was applied retroactively and did not have a material impact on the financial statements of SJI or SJG; however, current and prior period presentation on the consolidated statements of income were modified for SJI and SJG to conform to this guidance, as described under "Basis of Presentation" above.
In May 2017, the FASB issued ASU 2017-09, Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting. This ASU clarifies and reduces both (i) diversity in practice and (ii) cost and complexity when applying the guidance in Topic 718, to a change to the terms and conditions of a share-based payment award. This standard is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods, with early adoption permitted. The amendments in this ASU should be applied prospectively to an award modified on or after the adoption date. Adoption of this guidance did not have an impact on the financial statement results.results of SJI or SJG.
In August 2017, the FASB issued ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities. This ASU is intended to improve the financial reporting of hedging relationships so that it represents a more faithful portrayal of an entity’s risk management activities (i.e., to help financial statement users understand an entity’s risk exposures and the manner in which hedging strategies are used to manage them), as well as to further simplify the application of the hedge accounting guidance in GAAP. The standard is effective for annual periods beginning after December 15, 2018, including interim periods within those annual periods. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
In February 2018, the FASB issued ASU 2018-02, Reclassification of Certain Tax Effects From Accumulated Other Comprehensive Income. This ASU allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act (Tax Reform). Consequently, the amendments eliminate the stranded tax effects resulting from the Tax Reform and will improve the usefulness of information reported to financial statement users. The standard is effective for all entities for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. Early adoption is permitted. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
In February 2018, the FASB issued ASU 2018-03, Technical Corrections and Improvements to Financial Instruments—Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities, which gave improvements and enhancements to ASU 2016-01 discussed above. This ASU is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years beginning after June 15, 2018. SJI and SJG adopted this guidance during the first quarter of 2018 in conjunction with adopting ASU 2016-01 discussed above. Adoption of this guidance did not have an impact on the financial statement results of SJI or SJG.
In March 2018, the FASB issued ASU 2018-04, Investments-Debt Securities (Topic 320) and Regulated Operations (Topic 980): Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 117 and SEC Release No. 33-9273 (SEC Update). This ASU incorporates recent SEC guidance which was issued in order to make the relevant interpretive guidance consistent with current authoritative accounting and auditing guidance and SEC rules and regulation. ASU No. 2018-04 was effective upon issuance. Adoption of this guidance did not have an impact on the financial statement results of SJI or SJG.
In March 2018, the FASB issued ASU 2018-05, Income Taxes (Topic 740): Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118 (SEC Update). This ASU incorporates recent SEC guidance related to the income tax accounting implications of Tax Reform. ASU No. 2018-05 was effective upon issuance. Adoption of this guidance did not have an impact on the financial statement results of SJI or SJG.
In June 2018, the FASB issued ASU 2018-07, Compensation-Stock Compensation (Topic 718): Improvements to Non-employee Share-Based Payment Accounting. This ASU aligns the accounting for share-based payment awards issued to employees and non-employees. Under the new guidance, equity-classified share-based payment awards issued to non-employees will now be measured on the grant date, instead of the previous requirement to remeasure the awards through the performance completion date. For performance conditions, compensation cost associated with the award will be recognized when achievement of the performance condition is probable, rather than upon achievement of the performance condition. The current requirement to reassess the classification (equity or liability) for non-employee awards upon vesting will be eliminated, except for awards in the form of convertible instruments. The standard is effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. Early adoption is permitted. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement. This ASU modifies the disclosure requirements on the timing of liquidation of an investee's assets and the description of measurement uncertainty at the reporting date. Entities are now required to disclose: (1) the changes in unrealized gains and losses for the period included in other comprehensive income for recurring Level 3 fair value measurements; and (2) the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. Further, the standard eliminates disclosure requirements with respect to: (1) the transfers between Level 1 and Level 2 of the fair value hierarchy; (2) the policy for timing of transfers between levels; and (3) the valuation process for Level 3 fair value measurements. The standard is effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years. The new disclosure requirement for unrealized gains and losses, the range and weighted average of significant unobservable inputs and the narrative description of measurement uncertainty should be applied prospectively. All other amendments should be applied retrospectively to all periods presented upon their effective date. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
In August 2018, the FASB issued ASU 2018-14, Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20) Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plan. This ASU eliminates requirements for certain disclosures such as the amount and timing of plan assets expected to be returned to the employer and the amount of future annual benefits covered by insurance contracts. The standard added new disclosures such as for sponsors of the defined benefit plans to provide information relating to the weighted-average interest crediting rate for cash balance plans and other plans with promised interest crediting rates and an explanation for significant gains or losses related to changes in the benefit obligations for the period. The standard is effective for fiscal years ending after December 15, 2020. Early adoption is permitted. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
In August 2018, the FASB issued ASU 2018-15, Intangibles, Goodwill and Other Internal-Use Software (Topic 350): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement that is a Service Contract. This ASU aligns the requirements for capitalizing implementation costs for hosting arrangements (services) with costs for internal-use software (assets). As a result, certain implementation costs incurred in hosting arrangements will be deferred and amortized. This standard is effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years. Early adoption is permitted. SJI and SJG early adopted this ASU during the third quarter of 2018, which resulted in capitalizing implementation costs for hosting arrangements per the new guidance. This did not represent a change to the financial statements of SJI and SJG.
In October 2018, the FASB issued ASU 2018-16, Derivatives and Hedging (Topic 815): Inclusion of the Secured Overnight Financing Rate (SOFR) Overnight Index Swap (OIS) Rate as a Benchmark Interest Rate for Hedge Accounting Purposes. The amendments in this ASU permit the use of the OIS rate based on SOFR as a U.S. benchmark interest rate for hedge accounting purposes under Topic 815 in addition to the UST, the LIBOR swap rate, the OIS rate based on the Fed Funds Effective Rate, and the SIFMA Municipal Swap Rate. The amendments should be adopted on a prospective basis for qualifying new or re-designated hedging relationships entered into on or after the date of adoption. The amendments in this ASU are required to be adopted concurrently with the amendments in ASU 2017-12 for entities that have not already adopted the ASU 2017-12. For public companies that already have adopted the amendments in ASU 2017-12, the amendments are effective for fiscal years, including interim periods within those annual periods, beginning after December 15, 2018. Early adoption is permitted in any interim period upon issuance of this ASU if an entity already has adopted ASU 2017-12. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
In October 2018, the FASB issued ASU 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities. The amendments in this ASU for determining whether a decision-making fee is a variable interest require reporting entities to consider indirect interests held through related parties under common control on a proportional basis rather than as the equivalent of a direct interest in its entirety (as currently required by GAAP). These amendments will create alignment between determining whether a decision-making fee is a variable interest and determining whether a reporting entity within a related party group is the primary beneficiary of a VIE. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2019 for public companies. Early adoption is permitted. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
In November 2018, the FASB issued ASU 2018-18, Collaborative Arrangements (Topic 808): Clarifying the Interaction between Topic 808 and Topic 606. This ASU provides guidance on whether certain transactions between collaborative arrangement participants should be accounted for with revenue under Topic 606, specifically when the collaborative arrangement participant is a customer in the context of a unit-of-account. It provides more comparability in the presentation of revenues for certain transactions between collaborative arrangement participants, including adding unit-of-account guidance in Topic 808 to align with the guidance in Topic 606 (that is, a distinct good or service) when an entity is assessing whether the collaborative arrangement or a part of the arrangement is within the scope of Topic 606. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2019 for public companies. Early adoption is permitted. Management is currently determining the impact that adoption of this guidance will have on the financial statements of SJI and SJG.
| 2. | STOCK-BASED COMPENSATION |
Under SJI's 2015 Omnibus Equity Compensation Plan (Plan), shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. No options were granted or outstanding during the years ended December 31, 2018, 2017 and 2016. No stock appreciation rights have been issued under the plans. During the years ended December 31, 2018, 2017 and 2016, SJI granted 201,858 167,734 and 194,347 restricted shares, respectively, to Officers and other key employees of SJG participate inunder the plans of SJI.plans. Performance-based restricted shares vest over a three-year period and are subject to SJI achieving certain market and earnings-based performance targets, which can cause the actual amount of shares that ultimately vest to range from 0% to 200% of the original share unitsshares granted.
Grants containing market-based performance targets use SJI's total shareholder return (TSR)TSR relative to a peer group to measure performance. As TSR-based grants are contingent upon market and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant on a straight-line basis over the requisite three-year period of each award. In addition, SJI identifies specific forfeitures of share-based awards, and compensation expense is adjusted accordingly over the requisite service period. Compensation expense is not adjusted based on the actual achievement of performance goals. The fair value of TSR-based restricted stock awards on the date of grant is estimated using a Monte Carlo simulation model.
The following table summarizes the SJI nonvested restricted stock awards pertaining to SJG outstanding at December 31, 2016,2018, and the assumptions used to estimate the fair value of the awards:
| Grant Date | Shares Outstanding | Fair Value Per Share | Expected Volatility | Risk-Free Interest Rate | |||||||||
| 2015 - TSR | 6,884 | $ | 26.31 | 16.0 | % | 1.10 | % | ||||||
| 2015 - EPS, ROE, Time | 15,211 | $ | 29.47 | n/a | n/a | ||||||||
| 2016 - TSR | 11,472 | $ | 22.53 | 18.1 | % | 1.31 | % | ||||||
| 2016 - CEGR, Time | 21,305 | $ | 23.52 | n/a | n/a | ||||||||
| Grants | Shares Outstanding | Fair Value Per Share | Expected Volatility | Risk-Free Interest Rate | ||||||||||
| Officers & Key Employees - | 2016 - TSR | 50,531 | $ | 22.53 | 18.1 | % | 1.31 | % | ||||||
| 2016 - CEGR, Time | 63,747 | 23.52 | N/A | N/A | ||||||||||
| 2017 - TSR | 43,615 | $ | 32.17 | 20.8 | % | 1.47 | % | |||||||
| 2017 - CEGR, Time | 71,796 | $ | 33.69 | N/A | N/A | |||||||||
| 2018 - TSR | 59,973 | $ | 31.05 | 21.9 | % | 2.00 | % | |||||||
| 2018 - CEGR, Time | 122,147 | $ | 31.23 | N/A | N/A | |||||||||
| Directors - | 2018 | 26,416 | $ | 31.16 | N/A | N/A | ||||||||
Expected volatility is based on the actual volatility of SJI’s share price over the preceding three-year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three-year term of the Officers' and other key employees' restricted shares. As notional dividend equivalents are credited to the holders during the three yearthree-year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant.
The following table summarizes the total stock-based compensation cost for restricted stock awards was $0.6 million, $0.3 million and $0.2 million in 2016, 2015 and 2014, respectively. Of these costs, approximately one half was capitalized to Utility Plant in each of those years.the years ended December 31 (in thousands):
| 2018 | 2017 | 2016 | |||||||||
| Officers & Key Employees | $ | 3,321 | $ | 3,232 | $ | 3,051 | |||||
| Directors | 823 | 1,022 | 841 | ||||||||
| Total Cost | 4,144 | 4,254 | 3,892 | ||||||||
| Capitalized | (386 | ) | (288 | ) | (385 | ) | |||||
| Net Expense | $ | 3,758 | $ | 3,966 | $ | 3,507 | |||||
The table above reflects the reversal of approximately $0.3 million $1.1 million and $0.1 million of previously recorded costs in 2018, 2017 and 2016, respectively. These reversals are associated with EPS-based grants for which performance goals were not met.
As of December 31, 2016,2018, there was $0.7$5.1 million of total unrecognized compensation cost related to nonvested share-basedstock-based compensation awards granted under the plans. That cost is expected to be recognized over a weighted average period of 1.7 years.
The following table summarizes information regarding restricted stock award activity during 2016,2018, excluding accrued dividend equivalents:
| Shares | Weighted Average Grant Date Fair Value | |||||
| Nonvested Shares Outstanding, January 1, 2016 | 46,475 | $ | 26.67 | |||
| Granted | 33,218 | $ | 23.17 | |||
| Vested* | (21,995 | ) | $ | 24.88 | ||
| Cancelled/Forfeited** | (2,826 | ) | $ | 25.89 | ||
| Nonvested Shares Outstanding, December 31, 2016 | 54,872 | $ | 25.31 | |||
| Officers & Other Key Employees | Directors | Weighted Average Fair Value | |||||||
| Nonvested Shares Outstanding, January 1, 2018 | 342,793 | 30,394 | $ | 28.60 | |||||
| Granted | 201,858 | 26,416 | $ | 31.17 | |||||
| Vested | (44,902 | ) | (30,394 | ) | $ | 26.24 | |||
| Cancelled/Forfeited | (87,940 | ) | — | $ | 28.75 | ||||
| Nonvested Shares Outstanding, December 31, 2018 | 411,809 | 26,416 | |||||||
During the filing of this report, management expectsyears ended December 31, 2018, 2017 and 2016, SJI awarded 67,130, 65,628 and 13,247, respectively, shares to award 5,593 shares associated with the 2014 grants toits Officers and other key employees in 2017.
SJI has a policy of making cash payments to SJIissuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the Plan. Cash payments to SJI during 2016, 2015 and 2014 were approximately $0.2 million, $0.2 million and $0.4 million, respectively, relating to stock awards. Additionally,However, a change in control could result in the nonvestedsuch shares becoming nonforfeitable or immediately payable in cash. At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods. These deferred shares are included in Treasury Stock on the consolidated balance sheets.
SJG - Officers and other key employees of SJG participate in the stock-based compensation plans of SJI. During the years ended December 31, 2018, 2017 and 2016, SJG officers and other key employees were granted 32,924, 24,001 and 33,218 shares of SJI restricted stock, respectively. The cost of outstanding stock awards for SJG during the years ended December 31, 2018, 2017 and 2016 was $0.6 million and $0.4 million and $0.6 million, respectively. Approximately 65% of these costs were capitalized on SJG's balance sheets to Utility Plant.
| 3. | AFFILIATIONS, DISCONTINUED OPERATIONS AND RELATED-PARTY TRANSACTIONS: |
AFFILIATIONS — The following affiliated entities are accounted for under the equity method:
Energenic - Marina and a joint venture partner formed Energenic, in which Marina has a 50% equity interest. Energenic developed and operated on-site, self-contained, energy-related projects. Energenic currently does not have any projects that are operational.
Potato Creek - SJI and a joint venture partner formed Potato Creek, in which SJI has a 30% equity interest. Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania.
PennEast - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 118-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey.
Millennium - SJI and a joint venture partner formed Millennium, in which SJI has a 50% equity interest. Millennium reads utility customers’ meters on a monthly basis for a fee.
EnergyMark - SJE has a 33% investment in EnergyMark, an entity that acquires and markets natural gas to retail end users.
For the years ended December 31, 2018, 2017 and 2016, SJRG had net sales to EnergyMark of $41.6 million, $37.5 million and $31.4 million, respectively.
EnerConnex - In the second quarter of 2018, SJI entered into an agreement to obtain a 25% investment in EnerConnex, which is a retail and wholesale broker and consultant that matches end users with suppliers for the procurement of natural gas and electricity. The investment made by SJI in EnerConnex was not material.
The Company made net investments in unconsolidated affiliates of $6.6 million and $32.1 million in 2018 and 2017, respectively. As of December 31, 2018 and 2017, the outstanding balance of Notes Receivable – Affiliate was $15.2 million and $18.2 million, respectively. As of December 31, 2018, approximately $13.6 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025. The remaining $1.6 million of these notes are unsecured and accrue interest at variable rates.
SJI holds significant variable interests in these entities but is not the primary beneficiary. Consequently, these entities are accounted for under the equity method because SJI does not have both (a) the power to direct the activities of the entity that most significantly impact the entity’s economic performance and (b) the obligation to absorb losses of the entity that could potentially be significant to the entity or the right to receive benefits from the entity that could potentially be significant to the entity. As of December 31, 2018, the Company had a net asset of approximately $76.1 million included in Investment in Affiliates on the consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of December 31, 2018 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the aggregate amount of $91.3 million.
DISCONTINUED OPERATIONS - Discontinued Operations consist of the environmental remediation activities related to the properties of SJF and the product liability litigation and environmental remediation activities related to the prior business of Morie. SJF is a subsidiary of EMI, an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996.
SJI conducts tests annually to estimate the environmental remediation costs for these properties (see Note 15).
Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts):
| 2018 | 2017 | 2016 | |||||||||
| Loss before Income Taxes: | |||||||||||
| Sand Mining | $ | (118 | ) | $ | (84 | ) | $ | (205 | ) | ||
| Fuel Oil | (184 | ) | (175 | ) | (179 | ) | |||||
| Income Tax Benefits | 62 | 173 | 133 | ||||||||
| Loss from Discontinued Operations — Net | $ | (240 | ) | $ | (86 | ) | $ | (251 | ) | ||
| Earnings Per Common Share from | |||||||||||
| Discontinued Operations — Net: | |||||||||||
| Basic and Diluted | $ | — | $ | — | $ | — | |||||
SJG RELATED-PARTY TRANSACTIONS - SJG conducts business with its parent, SJI, and several other related parties. A description of each of these affiliates and related transactions is as follows:
SJES - a wholly-owned subsidiary of SJI that serves as a holding company for all of SJI’s nonutility operating businesses:
SJE - Prior to the sale of SJE's retail gas business (see Note 1), for SJE’s commercial customers for which SJG performed billing services, SJG purchased the related accounts receivable at book value and charged them a purchase of receivable fee for potential uncollectible accounts, and assumed all risk associated with collection.
SJRG - SJG sells natural gas for resale and capacity release to SJRG and also meets some of SJG's gas purchasing requirements by purchasing natural gas from SJRG.
Marina - SJG provides natural gas transportation services to Marina under BPU-approved tariffs.
Millennium - Reads SJG's utility customers’ meters on a monthly basis for a fee.
Sales of gas to SJRG and SJE comply with Section 284.02 of the Regulations of the FERC.
In addition to the above, SJG provides various administrative and professional services to SJI and each of the affiliates discussed above. Likewise, SJI provides substantial administrative services on SJG's behalf. For certain types of transactions, SJG served as central processing agents for the related parties discussed above. Amounts due to and due from these related parties for pass-through items are not considered material to SJG's financial statements as a whole.
A summary of related party transactions involving SJG, excluding pass-through items, included in SJG's Operating Revenues were as follows (in thousands):
| 2018 | 2017 | 2016 | |||||||||
| Operating Revenues/Affiliates: | |||||||||||
| SJRG | $ | 5,813 | $ | 4,458 | $ | 6,934 | |||||
| Marina | 379 | 314 | 302 | ||||||||
| Other | 91 | 86 | 83 | ||||||||
| Total Operating Revenues/Affiliates | $ | 6,283 | $ | 4,858 | $ | 7,319 | |||||
Related-party transactions involving SJG, excluding pass-through items, included in SJG's Cost of Sales and Operating Expenses were as follows (in thousands):
| 2018 | 2017 | 2016 | |||||||||
| Costs of Sales/Affiliates (Excluding depreciation and amortization) | |||||||||||
| SJRG* | $ | 33,313 | $ | 24,337 | $ | 16,306 | |||||
| Operations Expense/Affiliates: | |||||||||||
| SJI | $ | 31,740 | $ | 22,154 | $ | 20,296 | |||||
| Millennium | 2,920 | 2,856 | 2,803 | ||||||||
| Other | (569 | ) | (653 | ) | (198 | ) | |||||
| Total Operations Expense/Affiliates | $ | 34,091 | $ | 24,357 | $ | 22,901 | |||||
*These costs are included in either SJG's Cost of Sales on the statements of income, or Regulatory Assets on the balance sheets. As discussed in Note 1, revenues and expenses related to the energy trading activities of the wholesale energy operations at SJRG are presented on a net basis in Operating Revenues - Nonutility on the statements of consolidated income.
| 4. | INCOME TAXES: |
SJI files a consolidated federal income tax return and various state income tax returns, some of which are combined or unitary.
Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for SJI and SJG for the following reasons (in thousands):
| 2018 | 2017 | 2016 | ||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||
| Tax at Statutory Rate* | $ | 3,877 | $ | (9,915 | ) | $ | 60,624 | |||||
| Increase (Decrease) Resulting from: | ||||||||||||
| State Income Taxes | 622 | 2,778 | 6,438 | |||||||||
| ESOP Dividend | (791 | ) | (1,314 | ) | (1,300 | ) | ||||||
| Tax Reform Adjustments | (588 | ) | (13,521 | ) | — | |||||||
| AFUDC | (1,835 | ) | (3,094 | ) | (900 | ) | ||||||
| Amortization of Excess Deferred Taxes | (893 | ) | — | — | ||||||||
| Investment and Other Tax Credits | (93 | ) | (666 | ) | (10,706 | ) | ||||||
| Other - Net | 262 | 795 | (5 | ) | ||||||||
| Income Taxes: | ||||||||||||
| Continuing Operations | 561 | (24,937 | ) | 54,151 | ||||||||
| Discontinued Operations | (62 | ) | (173 | ) | (133 | ) | ||||||
| Total Income Tax (Benefit) Expense | $ | 499 | $ | (25,110 | ) | $ | 54,018 | |||||
| SJG: | ||||||||||||
| Tax at Statutory Rate* | 22,966 | 41,390 | 37,944 | |||||||||
| Increase (Decrease) Resulting from: | ||||||||||||
| State Income Taxes | 5,220 | 5,955 | 4,096 | |||||||||
| ESOP Dividend | (712 | ) | (1,182 | ) | (1,170 | ) | ||||||
| AFUDC | (1,126 | ) | (1,446 | ) | (900 | ) | ||||||
| Research and Development Credits | — | — | (613 | ) | ||||||||
| Other - Net | 65 | 983 | 9 | |||||||||
| Total Income Tax Expense | 26,413 | 45,700 | 39,366 | |||||||||
| The provision for Income Taxes is comprised of the following (in thousands): | ||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | 2018 | 2017 | 2016 | |||||||||
| Current: | ||||||||||||
| Federal | $ | (13,790 | ) | $ | (34,971 | ) | $ | — | ||||
| State | 3,959 | (48 | ) | (1,638 | ) | |||||||
| Total Current | (9,831 | ) | (35,019 | ) | (1,638 | ) | ||||||
| Deferred: | ||||||||||||
| Federal | 13,564 | 5,761 | 44,246 | |||||||||
| State | (3,172 | ) | 4,321 | 11,543 | ||||||||
| Total Deferred | 10,392 | 10,082 | 55,789 | |||||||||
| Income Taxes: | ||||||||||||
| Continuing Operations | 561 | (24,937 | ) | 54,151 | ||||||||
| Discontinued Operations | (62 | ) | (173 | ) | (133 | ) | ||||||
| Total Income Tax (Benefit) Expense | $ | 499 | $ | (25,110 | ) | $ | 54,018 | |||||
| SJG: | ||||||||||||
| Current: | ||||||||||||
| Federal | $ | (12,766 | ) | $ | (33,012 | ) | $ | — | ||||
| State | — | — | (1,614 | ) | ||||||||
| Total Current | (12,766 | ) | (33,012 | ) | (1,614 | ) | ||||||
| Deferred: | ||||||||||||
| Federal | 32,571 | 69,550 | 33,064 | |||||||||
| State | 6,608 | 9,162 | 7,916 | |||||||||
| Total Deferred | 39,179 | 78,712 | 40,980 | |||||||||
| Total Income Tax Expense | $ | 26,413 | $ | 45,700 | $ | 39,366 | ||||||
*See Tax Reform discussion below.
For the year ended December 31, 2018, SJI tax expense increased primarily due to higher income before taxes compared to 2017, as 2017 resulted in a loss before taxes compared to income in 2018. For the year ended December 31, 2017, SJI's tax expense decreased primarily due to adjustments made as a result of the Tax Reform (discussed below) along with an overall loss before income taxes, as opposed to income in 2016. These were partially offset with the impact of recording no investment tax credits in 2017. For SJG, tax expense decreased as income before taxes decreased as well.
TAX REFORM - On December 22, 2017, Tax Reform was enacted into law, changing various corporate income tax provisions within the existing Internal Revenue Code. The law became effective January 1, 2018 but was required to be accounted for in the period of enactment, as such SJI adopted the new requirements in the fourth quarter of 2017. SJI and SJG were impacted in several ways as a result of Tax Reform, including provisions related to the permanent reduction in the U.S. federal corporate income tax rate from 35% to 21%, modification of bonus depreciation and changes to the deductibility of certain business related expenses. As a result of the change in the federal corporate income tax rate, SJI and SJG revalued deferred tax assets and liabilities to reflect the rates expected to be in effect as a result of Tax Reform. This resulted in SJI recording a $14.1 million income tax benefit in total for the decrease of its net deferred tax liabilities. SJG also recorded a $260.5 million total decrease in its net deferred tax liabilities, which resulted in an increase to SJG's regulatory liabilities as such amounts are probable of settlement or recovery through customer rates. The amounts noted above were the total recorded between 2017 and 2018 as a result of Tax Reform. The amount and timing of potential settlements of the established net regulatory liability will be determined by the BPU, subject to certain IRS "normalization" provisions. All adjustments related to Tax Reform were recorded in the Corporate & Services segment.
The SEC staff issued SAB 118, which provides guidance on accounting for the tax effects of Tax Reform. SAB 118 provides a measurement period that should not extend beyond one year from the enactment date of Tax Reform for companies to complete the accounting under ASC 740. In accordance with SAB 118, a company must reflect the income tax effects of those aspects of Tax Reform for which the accounting under ASC 740 is complete.
As of December 31, 2018, SJI and SJG consider the impacts from Tax Reform to be complete. While we still expect additional guidance from the U.S. Department of the Treasury and the IRS, we have finalized our calculations using available guidance. Any additional issued guidance or future actions of our regulators could potentially affect the final determination of the accounting effects arising from the implementation of Tax Reform.
On August 3, 2018, the U.S. Department of Treasury, in conjunction with the IRS, released proposed regulations clarifying the immediate expensing provisions enacted by Tax Reform, specifically that regulated utility property acquired after September 27, 2017, and placed in service by December 31, 2017, qualifies for 100% expensing. Until the proposed regulations are finalized, taxpayers may rely on the proposed regulations for tax years ending after September 28, 2017. SJI and SJG recorded the impact of these proposed regulations and the adjustment was immaterial.
In November 2018, the IRS issued proposed regulations that allow all interest expense of a consolidated group to be deductible as long as a public utility comprises at least 90 percent of the total consolidated business. Under these proposed regulations, SJI expects to meet the de minimis safe harbor rule in 2018 and therefore, the full amount of SJI’s 2018 consolidated interest expense would be deductible.
The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax assets and liabilities for SJI and SJG at December 31 (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | 2018 | 2017 | ||||||
| Deferred Tax Assets: | ||||||||
| Net Operating Loss Carryforward | $ | 125,418 | $ | 152,541 | ||||
| Investment and Other Tax Credits | 214,698 | 214,605 | ||||||
| Derivatives / Unrealized Loss | — | 2,068 | ||||||
| Conservation Incentive Program | 1,701 | — | ||||||
| Deferred State Tax | 16,087 | 16,905 | ||||||
| Income Taxes Recoverable Through Rates | 103,434 | 76,426 | ||||||
| Pension & Other Post Retirement Benefits | 16,560 | 16,624 | ||||||
| Deferred Revenues | 5,736 | 5,726 | ||||||
| Provision for Uncollectibles | 5,319 | 3,854 | ||||||
| Other | 4,639 | 1,949 | ||||||
| Total Deferred Tax Asset | $ | 493,592 | $ | 490,698 | ||||
| Deferred Tax Liabilities: | ||||||||
| Book versus Tax Basis of Property | $ | 458,772 | $ | 486,854 | ||||
| Deferred Gas Costs - Net | 25,812 | 10,254 | ||||||
| Derivatives / Unrealized Gain | 4,463 | — | ||||||
| Environmental Remediation | 20,250 | 31,393 | ||||||
| Deferred Regulatory Costs | 14,351 | 3,554 | ||||||
| Budget Billing - Customer Accounts | 4,550 | 4,043 | ||||||
| Deferred Pension & Other Post Retirement Benefits | 34,095 | 21,349 | ||||||
| Conservation Incentive Program | — | 7,721 | ||||||
| Equity In Loss Of Affiliated Companies | 1,417 | 1,377 | ||||||
| Other | 15,718 | 11,037 | ||||||
| Total Deferred Tax Liability | $ | 579,428 | $ | 577,582 | ||||
| Deferred Tax Liability - Net | $ | 85,836 | $ | 86,884 | ||||
| SJG: | ||||||||
| Deferred Tax Assets: | ||||||||
| Net Operating Loss and Tax Credits | $ | 60,986 | $ | 73,785 | ||||
| Deferred State Tax | 16,754 | 14,688 | ||||||
| Provision for Uncollectibles | 3,776 | 3,811 | ||||||
| Conservation Incentive Program | 1,701 | — | ||||||
| Income Taxes Recoverable Through Rates | 67,372 | 76,426 | ||||||
| Pension & Other Post Retirement Benefits | 16,699 | 15,031 | ||||||
| Deferred Revenues | 5,906 | 6,066 | ||||||
| Other | 2,599 | 2,413 | ||||||
| Total Deferred Tax Assets | $ | 175,793 | $ | 192,220 | ||||
| Deferred Tax Liabilities: | ||||||||
| Book Versus Tax Basis of Property | $ | 395,371 | $ | 386,642 | ||||
| Deferred Fuel Costs - Net | 23,642 | 10,254 | ||||||
| Environmental Remediation | 40,753 | 31,637 | ||||||
| Deferred Regulatory Costs | 5,061 | 3,554 | ||||||
| Deferred Pension & Other Post Retirement Benefits | 21,870 | 21,349 | ||||||
| Budget Billing - Customer Accounts | 4,550 | 4,043 | ||||||
| Section 461 Prepayments | 1,081 | 866 | ||||||
| Conservation Incentive Program | — | 7,721 | ||||||
| Other | 9,351 | 6,900 | ||||||
| Total Deferred Tax Liabilities | $ | 501,679 | $ | 472,966 | ||||
| Deferred Tax Liability - Net | $ | 325,886 | $ | 280,746 | ||||
SJG is included in the consolidated federal income tax return filed by SJI. The actual taxes, including credits, are allocated by SJI to its subsidiaries, generally on a separate return basis except for net operating loss and credit carryforwards. As of December 31, 2018 and 2017, there were no income taxes due to or from SJI.
As of December 31, 2018, SJI has the following federal and state net operating loss carryforwards (in thousands):
| Net Operating Loss Carryforwards | |||||||
| Expire in: | Federal | State | |||||
| 2031 | $ | 36,126 | $ | 3,142 | |||
| 2032 | 42,988 | 17,982 | |||||
| 2033 | 57,363 | 35,232 | |||||
| 2034 | 106,899 | 28,853 | |||||
| 2035 | 51,308 | 9,956 | |||||
| 2036 | 72,199 | 170,497 | |||||
| 2037 | 75,606 | 89,714 | |||||
| 2038 | — | 68,865 | |||||
| $ | 442,489 | $ | 424,241 | ||||
As of December 31, 2018, SJI has the following investment tax credit carryforwards (in thousands):
| Expire in: | Investment Tax Credit Carryforward | |||
| 2030 | $ | 11,628 | ||
| 2031 | 25,664 | |||
| 2032 | 32,031 | |||
| 2033 | 45,606 | |||
| 2034 | 37,699 | |||
| 2035 | 45,005 | |||
| 2036 | 11,744 | |||
| 2037 | 636 | |||
| 2038 | 93 | |||
| $ | 210,106 | |||
SJI has $1.2 million of federal alternative minimum tax credits which have no expiration date. SJI also has research and development credits of $3.2 million that will expire between 2031 and 2035. As of December 31, 2018 and 2017, SJG has total federal net operating loss carryforwards of $200.0 million and $261.1 million, respectively, that will expire between 2031 and 2037. SJG has a state net operating loss carryforward of $207.9 million and $208.8 million that will expire between 2036 and 2037. SJG has research and development credits of $2.7 million which will expire between 2031 and 2035. A valuation allowance is recorded when it is more likely than not that any of SJI's or SJG's deferred tax assets will not be realized. SJI and SJG believe that they will generate sufficient future taxable income to realize the income tax benefits related to their net deferred tax assets.
A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | 2018 | 2017 | 2016 | |||||||||
| Balance at January 1, | $ | 1,445 | $ | 1,445 | $ | 559 | ||||||
| Increase as a result of tax positions taken in prior years | — | — | 886 | |||||||||
| Decrease in prior year positions | (298 | ) | — | — | ||||||||
| Balance at December 31, | $ | 1,147 | $ | 1,445 | $ | 1,445 | ||||||
| SJG: | ||||||||||||
| Balance at January 1, | $ | 1,361 | $ | 1,361 | $ | 559 | ||||||
| Increase as a result of tax position taken in prior years | — | — | 802 | |||||||||
| Decrease in prior year positions | (298 | ) | — | — | ||||||||
| Balance at December 31, | $ | 1,063 | $ | 1,361 | $ | 1,361 | ||||||
The total unrecognized tax benefits reflected in the table above exclude $0.8 million of accrued interest and penalties as of December 31, 2018, $0.8 million as of December 31, 2017 and $0.7 million as of December 31, 2016 for both SJI and SJG. The amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is not significant. The Company's policy is to record interest and penalties related to unrecognized tax benefits as interest expense and other expense, respectively. These amounts were not significant in 2018, 2017 or 2016. The majority of the increased tax position in 2016 is attributable to research and development credits. The Company does not anticipate any significant changes in the total unrecognized tax benefits within the next 12 months.
The unrecognized tax benefits are primarily related to an uncertainty of state income tax issues relating to the Company's nexus in certain states and tax credits. Federal income tax returns from 2014 forward and state income tax returns from 2008 forward are open and subject to examination.
| 5. | PREFERRED STOCK: |
REDEEMABLE CUMULATIVE PREFERRED STOCK - SJI has 2,500,000 authorized shares of Preference Stock, no par value, which has not been issued.
| 6. | COMMON STOCK: |
The following shares were issued and outstanding at December 31 (See Note 1):
| 2018 | 2017 | 2016 | ||||||
| Beginning of Year | 79,549,080 | 79,478,055 | 70,965,622 | |||||
| New Issuances During Year: | ||||||||
| Dividend Reinvestment Plan | — | — | 417,095 | |||||
| Stock-Based Compensation Plan | 67,308 | 71,025 | 45,338 | |||||
| Public Equity Offering | 5,889,830 | — | 8,050,000 | |||||
| End of Year | 85,506,218 | 79,549,080 | 79,478,055 | |||||
The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value at December 31, 2018 of approximately $133.6 million was recorded in Premium on Common Stock.
There were 2,339,139 shares of SJG's common stock (par value $2.50 per share) outstanding as of December 31, 2018. SJG did not issue any new shares during the period. SJIU, a wholly-owned subsidiary of SJI, owns all of the outstanding common stock of SJG.
PUBLIC OFFERINGS - In April 2018, the Company completed the following public offerings, the net proceeds of which were used to fund a portion of the consideration paid for the assets of ETG and ELK (see Notes 1 and 20):
SJI offered 12,669,491 shares of its common stock, par value $1.25 per share, at a public offering price of $29.50 per share. Of the offered shares, 5,889,830 shares were issued at closing, including 1,652,542 shares pursuant to the underwriters’ option. The gross proceeds from these shares was $173.7 million, with net proceeds, after deducting underwriting discounts and commissions, of $167.7 million. The remaining 6,779,661 shares of common stock ("Forward Shares") were to be sold by Bank of America, N.A., as forward seller, pursuant to a forward sale agreement. The Company received no proceeds from the sale of the Forward Shares in 2018. In January 2019, the Company settled the equity forward sale agreement; see Note 22.
SJI issued and sold 5,750,000 Equity Units, initially in the form of Corporate Units, which included 750,000 Corporate Units pursuant to the underwriters’ option. Each Corporate Unit has a stated amount of $50 and is comprised of (a) a purchase contract obligating the holder to purchase from the Company, and for the Company to sell to the holder for a price in cash of $50, on the purchase contract settlement date, or April 15, 2021, subject to earlier termination or settlement, a certain number of shares of common stock; and (b) a 1/20, or 5%, undivided beneficial ownership interest in $1,000 principal amount of SJI’s 2018 Series A 3.70% Remarketable Junior Subordinated Notes due 2031. SJI will pay the holder quarterly contract adjustment payments at a rate of 3.55% per year on the stated amount of $50 per Equity Unit, in respect of each purchase contract, subject to the Company's right to defer these payments. No deferral period will extend beyond the purchase contract settlement date. The contract adjustment payments are payable quarterly on January 15, April 15, July 15 and October 15 of each year (except that if such date is not a business day, contract adjustment payments will be payable on the following business day, without adjustment), commencing on July 15, 2018. The contract adjustment payments will be subordinated to all of the Company's existing and future “Priority Indebtedness” and will be structurally subordinated to all liabilities of our subsidiaries. The present value of the contract adjustment payments due through April 15, 2021 are initially charged to Shareholders’ Equity, with an offsetting credit to Other Current and Noncurrent Liabilities on the consolidated balance sheet. These liabilities are accreted over the life of the purchase contract by interest charges to the income statement based on a constant rate calculation. Subsequent contract adjustment payments reduce this liability. This offering resulted in gross proceeds of approximately $287.5 million, with net proceeds, after deducting underwriting discounts and commissions, of $278.9 million. As of December 31, 2018, the net proceeds, after amortization of the underwriting discounts, are recorded as Long-Term Debt on the consolidated balance sheets (see Note 14).
SJI's EPS — SJI's Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 777,603 and 112,590 shares for the years ended December 31, 2018 and 2016, respectively. For the year ended December 31, 2017, incremental shares of 141,750 were not included in the denominator for the diluted EPS calculation because they would have an antidilutive effect on EPS. These shares relate to SJI’s restricted stock as discussed in Note 2, along with, for the year ended December 31, 2018, the impact of the Forward Shares and Equity Units discussed above, accounted for under the treasury stock method.
DIVIDENDS PER SHARE - Dividends per share were $1.13, $1.10 and $1.07 for the years ended December 31, 2018, 2017 and 2016, respectively.
DRP — SJI offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. SJI currently purchases shares on the open market to fund share purchases by DRP participants, and as a result SJI did not raise any equity capital through the DRP in 2017 or 2018. SJI does not intend to issue equity capital via the DRP in 2019.
RETAINED EARNINGS:
The Utilities are limited by their regulatory authorities on the amount of cash dividends or other distributions they are able to transfer to their parent, specifically of which could impact their capitalization structure. In addition, various loan agreements may contain restrictions regarding the amount of cash dividends or other distributions that the Utilities may pay on its common stock. As of December 31, 2018, these loan restrictions did not affect the amount that may be distributed from the Utilities's retained earnings.
SJG declared and paid cash dividends of $20.0 million in 2017 to SJI. Cash dividends were not declared or paid by SJG to SJI in 2018 or 2016. SJG received a $40.0 million and $65.0 million equity contribution from SJI in 2017 and 2016, respectively; there was no equity contribution to SJG in 2018. Future equity contributions will occur on an as needed basis.
| 7. | FINANCIAL INSTRUMENTS: |
RESTRICTED INVESTMENTS — SJI and SJG maintain margin accounts with selected counterparties to support their risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy-related contracts with the respective counterparties decrease. As of December 31, 2018 and 2017, SJI's balances (including SJG) in these accounts totaled $1.6 million and $31.6 million, respectively, held by the counterparty, which is recorded in Restricted Investments on the consolidated balance sheets. The Restricted Investments balance as of December 31, 2017 also included $0.3 million related to capital project escrow funds that Marina was previously required to maintain. SJI also had balances held by SJRG as collateral of $7.9 million which is recorded in Accounts Payable on the consolidated balance sheets. As of December 31, 2018 and 2017, SJG's balance held by the counterparty totaled $1.3 million and $2.9 million, respectively, which is recorded in Restricted Investments on the balance sheets.
The carrying amounts of the Restricted Investments for both SJI and SJG approximate their fair values at December 31, 2018 and 2017, which would be included in Level 1 of the fair value hierarchy (see Note 17).
The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the consolidated balance sheets that sum to the total of the same such amounts shown in the statement of cash flows (in thousands):
| As of December 31, 2018 | |||||||
| Balance Sheet Line Item | SJI | SJG | |||||
| Cash and Cash Equivalents | 30,030 | 1,984 | |||||
| Restricted Investments | 1,649 | 1,278 | |||||
| Total cash, cash equivalents and restricted cash shown in the statement of cash flows | $ | 31,679 | $ | 3,262 | |||
| As of December 31, 2017 | |||||||
| Balance Sheet Line Item | SJI | SJG | |||||
| Cash and Cash Equivalents | 7,819 | 1,707 | |||||
| Restricted Investments | 31,876 | 2,912 | |||||
| Total cash, cash equivalents and restricted cash shown in the statement of cash flows | $ | 39,695 | $ | 4,619 | |||
NOTES RECEIVABLE-AFFILIATES - As of December 31, 2018, SJI had approximately $13.6 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from Energenic, which is secured by its cogeneration assets for energy service projects. This note is subject to a reimbursement agreement that secures reimbursement for SJI, from its joint venture partner, of a proportionate share of any amounts that are not repaid.
LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over periods ranging from five to ten years, with no interest. The carrying amounts of such loans were $5.3 million and $7.0 million as of December 31, 2018 and 2017, respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $0.7 million and $0.7 million as of December 31, 2018 and 2017, respectively. The annual amortization to interest is not material to SJI's or SJG's consolidated financial statements. The carrying amounts of these receivables approximate their fair value at December 31, 2018 and 2017, which would be included in Level 2 of the fair value hierarchy (see Note 17).
CREDIT RISK - As of December 31, 2018, SJI had approximately $11.7 million, or 19.1%, of current and noncurrent Derivatives–Energy Related Assets transacted with three counterparties. These counterparties are investment-grade rated.
FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJI's and SJG's financial instruments approximate their fair values at December 31, 2018 and 2017, except as noted below.
For Long-Term Debt, in estimating the fair value, SJI and SJG use the present value of remaining cash flows at the balance sheet date. SJI and SJG based the estimates on interest rates available at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy, see Note 17).
The estimated fair values of SJI's long-term debt (which includes SJG and all consolidated subsidiaries), including current maturities, as of December 31, 2018 and 2017, were $2.91 billion and $1.22 billion, respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of December 31, 2018 and 2017, were $2.84 billion and $1.19 billion, respectively. The carrying amounts as of December 31, 2018 and 2017 are net of unamortized debt issuance costs of $27.0 million and $17.4 million, respectively.
The estimated fair values of SJG's long-term debt, including current maturities, as of December 31, 2018 and 2017, were $895.1 million and $838.5 million, respectively. The carrying amount of SJG's long-term debt, including current maturities, as of December 31, 2018 and 2017, was $893.4 million and $821.9 million, respectively. The carrying amounts as of December 31, 2018 and 2017 are net of unamortized debt issuance costs of $6.8 million and $7.3 million, respectively.
OTHER FINANCIAL INSTRUMENTS - The carrying amounts of SJI's and SJG's other financial instruments approximate their fair values at December 31, 2018 and 2017.
| 8. | SEGMENTS OF BUSINESS: |
SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the CODM. These segments are as follows:
SJG utility operations consist primarily of natural gas distribution to residential, commercial and industrial customers in southern New Jersey.
ETG utility operations consist primarily of natural gas distribution to residential, commercial and industrial customers in northern and central New Jersey.
ELK utility operations consist of natural gas distribution to residential, commercial and industrial customers in Maryland.
Wholesale energy operations include the activities of SJRG and SJEX.
Retail gas and other operations at SJE included natural gas acquisition and transportation service business lines. This business was sold on November 30, 2018 (see Note 1).
Retail electric operations at SJE consist of electricity acquisition and transportation to commercial, industrial and residential customers.
On-site energy production consists of Marina's thermal energy facility and other energy-related projects. Also included in this segment are the activities of ACB, ACLE, BCLE, SCLE, SXLE, along with MCS, NBS and SBS, which were sold in October 2018 (see Note 1).
Appliance service operations includes SJESP, which receives commissions on service contracts from a third party.
Midstream was formed to invest in infrastructure and other midstream projects, including a current project to build a natural gas pipeline in Pennsylvania and New Jersey.
Corporate & Services segment includes costs related to the Acquisition, along with other unallocated costs.
Intersegment represents intercompany transactions between the above SJI consolidated entities.
SJI groups its utility businesses under its wholly-owned subsidiary SJIU. This group consists of gas utility operations of SJG, ETG and ELK. SJI groups its nonutility operations into separate categories: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations. The accounting policies of the segments are the same as those described in the summary of significant accounting policies.
Information about SJI’s operations in different reportable operating segments is presented below (in thousands). The results for ETG and ELK utility operations are included from the date of the Acquisition, July 1, 2018, through December 31, 2018.
| 2018 | 2017 | 2016 | |||||||||
| Operating Revenues: | |||||||||||
| SJI Utilities: | |||||||||||
| SJG Utility Operations | $ | 548,000 | $ | 517,254 | $ | 461,055 | |||||
| ETG Utility Operations | 125,604 | — | — | ||||||||
| ELK Utility Operations | 3,302 | — | — | ||||||||
| Subtotal SJI Utilities | 676,906 | 517,254 | 461,055 | ||||||||
| Energy Group: | |||||||||||
| Wholesale Energy Operations | 636,005 | 352,613 | 220,707 | ||||||||
| Retail Gas and Other Operations | 101,543 | 111,048 | 92,371 | ||||||||
| Retail Electric Operations | 176,945 | 179,534 | 182,540 | ||||||||
| Subtotal Energy Group | 914,493 | 643,195 | 495,618 | ||||||||
| Energy Services: | |||||||||||
| On-Site Energy Production | 72,374 | 99,517 | 94,375 | ||||||||
| Appliance Service Operations | 1,957 | 6,488 | 7,898 | ||||||||
| Subtotal Energy Services | 74,331 | 106,005 | 102,273 | ||||||||
| Corporate & Services | 51,000 | 45,024 | 35,147 | ||||||||
| Subtotal | 1,716,730 | 1,311,478 | 1,094,093 | ||||||||
| Intersegment Sales | (75,392 | ) | (68,410 | ) | (57,593 | ) | |||||
| Total Operating Revenues | $ | 1,641,338 | $ | 1,243,068 | $ | 1,036,500 | |||||
| 2018 | 2017 | 2016 | |||||||||
| Operating Income (See Note 1): | |||||||||||
| SJI Utilities: | |||||||||||
| SJG Utility Operations | $ | 132,688 | $ | 138,875 | $ | 125,052 | |||||
| ETG Utility Operations | 2,164 | — | — | ||||||||
| ELK Utility Operations | (256 | ) | — | — | |||||||
| Subtotal SJI Utilities | 134,596 | 138,875 | 125,052 | ||||||||
| Energy Group: | |||||||||||
| Wholesale Energy Operations | 87,895 | (36,815 | ) | 41,667 | |||||||
| Retail Gas and Other Operations | (8,721 | ) | (2,468 | ) | 4,680 | ||||||
| Retail Electric Operations | (359 | ) | 3,620 | 7,007 | |||||||
| Subtotal Energy Group | 78,815 | (35,663 | ) | 53,354 | |||||||
| Energy Services: | |||||||||||
| On-Site Energy Production | (88,230 | ) | (83,654 | ) | 13,301 | ||||||
| Appliance Service Operations | 1,818 | 217 | 582 | ||||||||
| Subtotal Energy Services | (86,412 | ) | (83,437 | ) | 13,883 | ||||||
| Midstream | (292 | ) | — | — | |||||||
| Corporate and Services | (25,962 | ) | (10,932 | ) | 1,888 | ||||||
| Total Operating Income | $ | 100,745 | $ | 8,843 | $ | 194,177 | |||||
| Depreciation and Amortization: | |||||||||||
| SJI Utilities: | |||||||||||
| SJG Utility Operations | $ | 82,622 | $ | 71,654 | $ | 63,901 | |||||
| ETG Utility Operations | 13,580 | — | — | ||||||||
| ELK Utility Operations | 222 | — | — | ||||||||
| Subtotal SJI Utilities | 96,424 | 71,654 | 63,901 | ||||||||
| Energy Group: | |||||||||||
| Wholesale Energy Operations | 105 | 125 | 484 | ||||||||
| Retail Gas and Other Operations | 279 | 323 | 337 | ||||||||
| Subtotal Energy Group | 384 | 448 | 821 | ||||||||
| Energy Services: | |||||||||||
| On-Site Energy Production | 23,123 | 46,928 | 43,395 | ||||||||
| Appliance Service Operations | — | 153 | 301 | ||||||||
| Subtotal Energy Services | 23,123 | 47,081 | 43,696 | ||||||||
| Corporate and Services | 12,983 | 4,303 | 1,400 | ||||||||
| Total Depreciation and Amortization | $ | 132,914 | $ | 123,486 | $ | 109,818 | |||||
| Interest Charges (See Note 1): | |||||||||||
| SJI Utilities: | |||||||||||
| SJG Utility Operations | $ | 28,011 | $ | 24,705 | $ | 17,875 | |||||
| ETG Utility Operations | 10,478 | — | — | ||||||||
| ELK Utility Operations | 4 | — | — | ||||||||
| Subtotal SJI Utilities | 38,493 | 24,705 | 17,875 | ||||||||
| Energy Group: | |||||||||||
| Wholesale Energy Operations | — | 3,150 | — | ||||||||
| Retail Gas and Other Operations | 487 | 250 | 350 | ||||||||
| Subtotal Energy Group | 487 | 3,400 | 350 | ||||||||
| Energy Services: | |||||||||||
| On-Site Energy Production | 15,364 | 16,838 | 11,961 | ||||||||
| Midstream | 1,966 | 985 | — | ||||||||
| Corporate and Services | 54,107 | 23,819 | 12,118 | ||||||||
| Subtotal | 110,417 | 69,747 | 42,304 | ||||||||
| Intersegment Borrowings | (20,121 | ) | (15,728 | ) | (10,855 | ) | |||||
| Total Interest Charges | $ | 90,296 | $ | 54,019 | $ | 31,449 | |||||
| 2018 | 2017 | 2016 | |||||||||
| Income Taxes (See Note 1): | |||||||||||
| SJI Utilities: | |||||||||||
| SJG Utility Operations | $ | 26,413 | $ | 45,700 | $ | 39,366 | |||||
| ETG Utility Operations | (3,086 | ) | — | — | |||||||
| ELK Utility Operations | (70 | ) | — | — | |||||||
| Subtotal SJI Utilities | 23,257 | 45,700 | 39,366 | ||||||||
| Energy Group: | |||||||||||
| Wholesale Energy Operations | 22,473 | (14,720 | ) | 15,882 | |||||||
| Retail Gas and Other Operations | (2,360 | ) | (544 | ) | 2,118 | ||||||
| Retail Electric Operations | (101 | ) | 1,480 | 2,862 | |||||||
| Subtotal Energy Group | 20,012 | (13,784 | ) | 20,862 | |||||||
| Energy Services: | |||||||||||
| On-Site Energy Production | (26,397 | ) | (39,262 | ) | (6,353 | ) | |||||
| Appliance Service Operations | 534 | 4 | 232 | ||||||||
| Subtotal Energy Services | (25,863 | ) | (39,258 | ) | (6,121 | ) | |||||
| Midstream | (190 | ) | (41 | ) | — | ||||||
| Corporate and Services | (16,655 | ) | (17,554 | ) | 44 | ||||||
| Total Income Taxes | $ | 561 | $ | (24,937 | ) | $ | 54,151 | ||||
| Property Additions: | |||||||||||
| SJI Utilities: | |||||||||||
| SJG Utility Operations | $ | 253,617 | $ | 253,545 | $ | 228,275 | |||||
| ETG Utility Operations | 90,259 | — | — | ||||||||
| ELK Utility Operations | 1,820 | — | — | ||||||||
| Subtotal SJI Utilities | 345,696 | 253,545 | 228,275 | ||||||||
| Energy Group: | |||||||||||
| Wholesale Energy Operations | 34 | 14 | 7 | ||||||||
| Retail Gas and Other Operations | 495 | 889 | 1,642 | ||||||||
| Subtotal Energy Group | 529 | 903 | 1,649 | ||||||||
| Energy Services: | |||||||||||
| On-Site Energy Production | 2,686 | 12,588 | 38,193 | ||||||||
| Appliance Service Operations | — | 260 | 431 | ||||||||
| Subtotal Energy Services | 2,686 | 12,848 | 38,624 | ||||||||
| Midstream | 119 | 218 | 505 | ||||||||
| Corporate and Services | 1,826 | 2,233 | 636 | ||||||||
| Total Property Additions | $ | 350,856 | $ | 269,747 | $ | 269,689 | |||||
(1) The property additions for ETG Utility Operations and ELK Utility Operations in 2018 do not include the approximately $1.077 billion and $12.3 million, respectively, of Property, Plant and Equipment obtained through the Acquisition as discussed in Note 20.
| 2018 | 2017 | ||||||
| Identifiable Assets: | |||||||
| SJI Utilities: | |||||||
| SJG Utility Operations | $ | 3,118,236 | $ | 2,865,974 | |||
| ETG Utility Operations | 2,148,175 | — | |||||
| ELK Utility Operations | 16,482 | — | |||||
| Subtotal SJI Utilities | 5,282,893 | 2,865,974 | |||||
| Energy Group: | |||||||
| Wholesale Energy Operations | 266,417 | 208,785 | |||||
| Retail Gas and Other Operations | 12,736 | 56,935 | |||||
| Retail Electric Operations | 39,345 | 34,923 | |||||
| Subtotal Energy Group | 318,498 | 300,643 | |||||
| Energy Services: | |||||||
| On-Site Energy Production | 195,329 | 582,587 | |||||
| Appliance Service Operations | — | 1,338 | |||||
| Subtotal Energy Services | 195,329 | 583,925 | |||||
| Discontinued Operations | 1,777 | 1,757 | |||||
| Midstream | 72,333 | 63,112 | |||||
| Corporate and Services | 387,482 | 711,038 | |||||
| Intersegment Assets | (301,735 | ) | (661,363 | ) | |||
| Total Identifiable Assets | $ | 5,956,577 | $ | 3,865,086 | |||
9. LEASES:
Marina is considered to be the lessor of certain thermal energy generating property and equipment under an operating lease which expires in May 2027. As of December 31, 2018 and 2017, the carrying costs of this property and equipment under operating lease was $71.5 million and $74.2 million, respectively (net of accumulated depreciation of $37.7 million and $34.5 million , respectively), and is included in Nonutility Property and Equipment in the consolidated balance sheets.
Minimum future rentals to be received on this operating lease of property and equipment as of December 31, 2018 for each of the next five years and in the aggregate are (in thousands):
| Year ended December 31, | |||
| 2019 | $ | 5,396 | |
| 2020 | 5,396 | ||
| 2021 | 5,396 | ||
| 2022 | 5,396 | ||
| 2023 | 5,396 | ||
| Thereafter | 18,438 | ||
| Total minimum future rentals | 45,418 | ||
Minimum future rentals do not include additional amounts to be received based on actual use of the leased property.
| 10. | RATES AND REGULATORY ACTIONS: |
In January 2017, SJG filed a base rate case with the BPU to increase its base rates in order to obtain a return on new capital investments made by SJG since the settlement of its last base rate case in 2014. In October 2017, SJG expects thesettled its base rate case, pursuant to be concluded duringwhich the BPU granted SJG a base rate increase, effective November 1, 2017, (see Note 17).of $39.5 million, which was predicated in part upon a 6.80% rate of return on rate base that included a 9.60% return on common equity. The BPU Order allows SJG to recover revenues associated with certain infrastructure and system improvement investments made and the related expenses incurred since the approval of its previous base rate case proceeding in September 2014.
January 2016 - SJG provided a BGSS bill credit of approximately $20.0 million to its residential and small commercial customers. This credit was in addition to the overall rate reduction that was approved by the BPU and took effect in 2015.
June 2016 - SJG filed its annual BGSS filing with the BPU, requesting a $47.1 million decrease in gas cost recoveries.
September 2016 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $47.1 million decrease in gas cost recoveries, effective October 2016.
December 2016 - SJG provided a BGSS bill credit of approximately $10.0 million to its residential and small commercial customers. The credit was in addition to the overall rate reduction that was approved by the BPU and took effect in October 2016.
April 2017 - SJG provided a BGSS bill credit of approximately $8.0 million to its residential and small commercial customers. The credit was in addition to the overall rate reduction that was approved by the BPU and took effect in October 2016.
June 2017 - SJG filed its annual BGSS filing with the BPU, requesting a $4.7 million decrease in gas cost recoveries.
September 2017 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $4.7 million decrease in gas cost recoveries associated with the 2017-2018 BGSS year, effective October 2017.
May 2018 - SJG received BPU final approval of provisional rates that were authorized in a BPU order during September 2017, as they relate to SJG's 2017-2018 BGSS filing, as submitted to the BPU in June 2017. The impact of the final rates was a $4.7 million decrease in revenue.
June 2018 - SJG filed its annual BGSS filing with the BPU requesting a $65.5 million increase in gas recoveries, which included a $53.7 million under-recovered deferred balance.
September 2018 - The BPU issued an Order approving, on a provisional basis, SJG's request for a $65.5 million increase in the gas cost recoveries associated with the 2018-2019 BGSS year, effective October 1, 2018. The matter was thereafter referred to the Office of Administrative Law for further proceedings. Presently, the parties are engaged in settlement negotiations. In the event a settlement is not reached, evidentiary hearings are scheduled for April 2019. A range of potential outcomes include, among other things, provisional rates will be made final, a reduction in rates to minimize negative financial impacts on ratepayers for a set period of time, a disallowance of part or all of the under-recovered deferred balance, modifications to the Company’s existing risk/hedging policies, limitations on affiliate transactions, and/or additional filing requirements associated with future annual BGSS filings.
December 2018 - SJG submitted a notice of intent to self-implement a BGSS rate adjustment based on a 5% increase of the monthly bill of a typical residential customer, effective February, 1, 2019.
June 2016 - SJG filed its annual CIP filing with the BPU, requesting a $46.5 million increase in revenues, which includes a $9.9 million increase in non-weather related revenues and a $36.6 million increase in weather related revenues.
September 2016 - The BPU issued an Order approving, on a provisional basis, the 2016-2017 CIP rates filed in June 2016, effective October 2016.
June 2017 - SJG filed its annual CIP filing with the BPU requesting a $0.2 million increase in revenues, which included a $1.1 million increase in non-weather related revenues and a $0.9 million decrease in weather related revenues.
September 2017 - The BPU issued an Order approving the 2017-2018 CIP Year rates filed in June 2017, effective October 2017.
May 2018 - SJG received BPU final approval of provisional rates that were authorized in a BPU order during September 2017, as they relate to SJG's 2017-2018 CIP filing, as submitted to the BPU in June 2017. The impact of the final rates was a $0.2 million increase in revenue.
September 2018 - SJG received BPU final approval of a $26.4 million decrease in CIP annual revenues, effective October 1, 2018, on a provisional basis, associated with the 2018-2019 CIP year, which runs from October 1, 2018 through September 30, 2019.
February 2016 - SJG filed a petition with the BPU for approval to continue its AIRP, which was set to expire at the end of 2016. In its petition, SJG requested to extend the AIRP for an additional seven years with program investments totaling approximately $500.0 million. In its petition,Petition, SJG also requested to increase revenues by $13.0 million to reflect in base rates all AIRP investments made from the time of SJG’s last base rate case to the end of the initial AIRP.
October 2016 - The BPU issued an Order approving an extension of the AIRP for a five-year period (“AIRP II”), commencing October 1, 2016, with authorized investments of up to $302.5 million to continue replacing cast iron and unprotected bare steel mains and associated services. The BPU also approved an $11.0 million increase in revenues associated with the roll in of $80.2 million of AIRP investments, inclusive of $5.7 million of AFUDC into base rates, effective December 1, 2016.
April 2017 - SJG filed a petition, pursuant to the October 2016 BPU approval of the AIRP II, seeking a base rate adjustment to increase annual revenues by approximately $4.5 million to reflect the roll-in of $42.0 million of AIRP II investments made from October 1, 2016 through June 30, 2017.
September 2017 - The BPU issued an Order approving an increase in annual revenues from base rates of $5.0 million to reflect the roll-in of $46.1 million AIRP II investments made from October 2016 through June 2017, effective October 1, 2017.
April 2018 - SJG submitted its second annual filing, pursuant to the October 2016 BPU approval of the AIRP II, seeking a base rate adjustment to increase annual revenues by approximately $6.6 million to reflect the roll-in of $60.4 million of AIRP II investments placed in service from July 1, 2017 through June 30, 2018. This was approved in September 2018.
April 2016 - SJG filed a petition seeking a base rate adjustment to increase annual revenues by approximately $4.3 million to reflect approximately $33.7 million of SHARP investments made from July 2015 through June 2016.
September 2016 - The BPU approved an increase in annual revenues from base rates of $3.9 million to reflect the roll-in of $33.7 million of SHARP investments made from July 2015 through June 2016, effective October 1, 2016.
April 2017 - SJG filed a petition seeking a base rate adjustment to increase annual revenues by approximately $4.0 million to reflect approximately $35.7 million of SHARP investments made from July 2016 through June 2017.
September 2017 - The BPU issued an Order approving an increase in annual revenues from base rates of $3.6 million to reflect the roll-in of $33.3 million SHARP investments made from July 2016 through June 2017, effective October 1, 2017.
November 2017 - SJG filed a petition with the BPU for approval to continue its storm hardening efforts under a second phase of SHARP (“SHARP II”). Phase one of SJG’s initial SHARP expired in June of 2017. In its petition, SJG proposed a three-year program, with a total investment level of approximately $110.3 million, focused on four system enhancement projects within the coastal regions. SJG also proposed to recover the SHARP II through annual base rate adjustments, with no impact to customer bills until October 2019. This was approved by the BPU in May 2018 with a total of $100.3 million recoverable through SHARP II. Pursuant to the order, SHARP II investments are to be recovered through annual base rate adjustments.
February 2016 - The BPU approved a revenue decrease of $7.9 million associated with the two most recent annual EET rate adjustment filings, effective April 1, 2016.
June 2016 - SJG filed its annual EET rate adjustment petition, requesting a $0.8 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with EEPs.
October 2016 - The BPU approved a revenue decrease of $1.6 million associated with SJG's annual EET rate adjustment filing, effective November 10, 2016.
November 2016 - SJG filed a letter petition requesting an extension of its current Energy Efficiency Program (“EEP III”)III through December 31, 2018, allowing SJG to spend the remainder of its existing BPU approved budget over the extended term.
January 2017 - The BPU approved this extensionissued an Order approving SJG’s request to extend the expiration date of EEP III from August 2017 to December 2018, without any modification to the subprograms or the amount of the previously authorized budget of $36.3 million, inclusive of operation and maintenance expenses.
June 2017 - SJG filed its Eighth Annual EET Filing, requesting a $3.0 million increase in Januaryrevenues to continue recovering the costs of, and the allowed return on, prior investments associated with EEPs.
November 2017 - The BPU issued an Order approving a revenue increase of $2.6 million associated with the Eighth Annual EET Filing, effective December 1, 2017.
March 2018 - SJG filed a petition with the BPU seeking to continue its existing EEP's, with modifications, and to implement new programs (the “EEP IV”) for a five-year period with a proposed budget of approximately $195.4 million and with the same rate recovery mechanism that exists for its current EEP's. Under its existing EEP's, SJG is permitted to recover incremental operating and maintenance expenses and earn a return of, and return on, program investments.
June 2018 - SJG filed its ninth annual EET rate adjustment petition, requesting a $1.6 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with its EEPs.
October 2018 - The BPU issued an Order approving SJG's request to continue its existing EEPs with modifications, and to implement several new EEP's for a period of three years (the "EEP IV"), with a total budget of $81.3 million and a revenue increase of $3.5 million, effective November 1, 2018.
January 2019 - The BPU issued an Order approving a revenue decrease of $1.6 million associated with SJG's annual EET rate adjustment filing, effective February, 1, 2019.
July 2016 - SJG made its annual 2016-2017 SBC filing, requesting a $16.0 million increase in SBC revenues. This petition is currently pending.The BPU approved this filing in May 2017.
July 2017 - SJG made its annual 2017-2018 SBC filing, requesting an $8.5 million increase in annual revenues. The BPU approved this filing in January 2018.
July 2018 - SJG made its annual 2018-2019 SBC filing, requesting $3.4 million decrease in annual revenues.
Separate regulatory actions regarding the USF were as follows:follows:
June 2016 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to increase the statewide gas revenues by $56.0 million. This proposal was designed to increase SJG’s annual USF revenue by $1.1 million.
September 2016 - The BPU approved the statewide budget of $56.0 million for all the State’s gas utilities. SJG's portion of the total is approximately $5.6 million, which increased rates effective October 1, 2016, resulting in a $1.1 million increase to its USF recoveries.
June 2017 - SJG made its annual USF filing, along with the State’s other gas utilities, proposing to decrease the statewide gas revenues by $16.3 million. This proposal was designed to decrease SJG’s annual USF revenue by $2.0 million.
September 2017 - The BPU approved the statewide budget of $38.3 million for all the State’s gas utilities. SJG's portion of the total was approximately $3.2 million, resulting in a $2.2 million decrease to its USF recoveries effective October 1, 2017.
June 2018 - SJG made its annual USF filing, along with the State's other gas utilities, proposing to decrease statewide electric and gas revenues by $10.4 million. This proposal included an increase to SJG's annual USF recoveries of $0.9 million.
September 2018 - The BPU approved the Statewide USF annual 2018-2019 budget for all of New Jersey's gas utilities. SJG's portion of the total is approximately $3.7 million, resulting in a $0.9 million increase to its USF recoveries, effective October 1, 2018.
The BGSS, CIP and USF approvals discussed above do not impact SJG's earnings. They represent changes in the cash requirements of SJG corresponding to cost changes and/or previously over/under recoveries from ratepayers associated with each respective mechanism.
Other Regulatory Matters-
Unbundling - This allows all natural gas consumers to select their natural gas commodity supplier. As of December 31, 2016, 33,4672018, 29,141 of SJG's customers were purchasing their gas commodity from someone other than us.SJG. Customers choosing to purchase natural gas from providers other than the utility are charged for the cost of gas by the marketer. The resulting decrease in SJG'sutility revenues is offset by a corresponding decrease in gas costs. While customer choice can reduce utility revenues, it does not negatively affect SJG's net income or financial condition. The BPU continues to allow for full recovery of prudently incurred natural gas costs through the BGSS. Unbundling did not change the fact that SJG still recoverrecovers cost of service, including certain deferred costs, through base rates.
Pipeline Integrity Costs - SJG is permitted to defer and recover incremental costs incurred as a result of Pipeline Integrity Management regulations, which are aimed at enhancing public safety and reliability. The regulations require that utilities use a comprehensive analysis to assess, evaluate, repair and validate the integrity of certain transmission lines in the event of a leak or failure. As part of SJG's 20142017 base rate case, it was permitted to recover previously deferred pipeline integrity costs incurred from October 2010July 2014 through June 2014.August 2017, with the costs to be amortized over a three year period. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in ourthe next base rate case proceeding, subject to review by the BPU. As
Tax Reform - In March 2018, SJG filed a petition with the BPU for a change in rates, customer refund and rider associated with the implementation of Tax Reform. The BPU subsequently approved an interim rate reduction, effective April 1, 2018, to reflect the change in the corporate tax rate within SJG's base rates. In September 2018, the BPU approved SJG's request to implement changes in the corporate tax rate, from 35% to21%, within SJG's base rate, in accordance with Tax Reform, including:December
A final base rate adjustment to reflect an annual revenue reduction of approximately $25.9 million;
A one-time customer refund of approximately $13.8 million, including interest, for over collected tax during the period January 1, 2018 through September 30, 2018; and
A customer refund of approximately $27.5 million for the "Unprotected" Excess Deferred Income Tax through a separate tariff rider over a five-year period. The refund related to the "Protected" Excess Deferred Tax will be addressed no later than March 31, 2016 and 2015, deferred pipeline integrity costs totaled $4.0 million and $2.7 million, respectively, and are included in other regulatory assets (see Note 4).2019.
Filings and petitions described above are still pending, unless otherwise indicated.
ETG:
As part of the Acquisition approval by the BPU, the Company was required to provide ETG customers with a credit of $15.0 million within ninety days of the Acquisition closing date, which was July 1, 2018. ETG provided a one-time bill credit to all customer by September 2018.
ETG's most recent base rate case was resolved by a settlement that was approved by a BPU order issued in June 2017. The settlement, as approved by the BPU, granted ETG an annual base rate increase of $13.3 million and reflected a 9.6% return on equity, a $720.0 million rate base, and a 5.77% overall after-tax rate of return.
Tax Reform - In March 2018, ETG filed a petition with the BPU requesting an annual reduction of $10.9 million, effective April 1, 2018, which reflected the reduced corporate tax rate as a result of Tax Reform. The BPU authorized ETG to implement its proposed base rate reduction on April 1, 2018 on an interim basis. In June 2018, the BPU approved a final base rate reduction of $12.1 million which was implemented by ETG on July 1, 2018.
In June 2018, the BPU authorized ETG to issue a one-time customer refund for over-collected tax during the period January 1, 2018 though June 30, 2018. ETG issued a one-time customer refund of $5.2 million, including interest, for the over-collected taxes in July and August 2018 as bill credits.
IIP - Consistent with Acquisition approval, SJI was required to develop a plan, in concert with the BPU and the New Jersey Division of Rate Counsel, to address the replacement of ETG's aging infrastructure. In October 2018, ETG filed an IIP petition with the BPU pursuant to rules adopted by the BPU in December 2017 pertaining to utility infrastructure investments. The IIP petition seeks authority to recover the costs associated with ETG's initial investment of approximately $518.0 million from 2019-2023 to, among other things, replace its cast-iron and low-pressure vintage main and related services. The IIP petition includes a request for timely recovery of ETG's investment on a semi-annual basis through a separate rate mechanism. A resolution of the IIP petition is pending.
The currently effective rate mechanisms reflected in ETG’s tariff are as follows:
BGSS Clause - The BGSS for ETG is similar to that of SJG defined above. For the preceding year, inclusive of the period following the Acquisition of ETG by SJI, regulatory actions regarding the BGSS were as follows:
May 2018 - The BPU issued an Order approving, on a final basis, the provisional rates that were authorized by the BPU in its September 2017 Order, effective June 2018.
May 2018 - ETG filed its annual BGSS filing with the BPU, requesting a $7.1 million decrease in gas cost recoveries. This was approved in September 2018.
December 2018 - ETG submitted a notice of intent to self-implement a BGSS rate adjustment based on a 5% increase of the monthly bill of a typical residential customer, effective February 1, 2019; that adjustment took effect on February 1, 2019.
EEP - The EEP rate enables ETG to recover the costs of its EEP as authorized by the BPU. ETG’s EEP consists of a range of rebates and related offers, including, for example, various customer education and outreach initiatives, as well as an on-line customer dashboard, that are designed to encourage customers to conserve energy and to provide them with information on how to lower their gas bills. ETG has authorization from the BPU to offer its EEP through February 28, 2019 and has entered into a Stipulation that is pending BPU approval to continue the EEP through February 29, 2020 at a total budget of approximately $3.0 million. For the preceding year, inclusive of the period following the Acquisition of ETG by SJI, regulatory actions regarding the EEP were as follows:
June 2018 - ETG filed to extend its EEPs through December 2019.
August 2018 - The BPU issued an Order on ETG’s November 2017 filing approving a revenue increase of $1.2 million to an annual revenue of $2.2 million effective September 2018 to continue recovering the costs of, and the allowed return on, prior investments associated with its EEPs.
August 2018 - ETG filed its annual EEP rate adjustment petition, requesting a revenue increase of $1.3 million to an annual revenue of $2.2 million to continue recovering the costs of, and the allowed return on, prior investments associated with its EEPs.
October 2018 - The Board approved EEPs extension through February 2019, consistent in all other respects with the Board's April 2017 Order.
January 2019 - ETG entered into a Stipulation with Board Staff and the New Jersey Division of Rate Counsel extending its EEP through February 29, 2020 at a total budget of approximately $3.0 million.
WNC - The WNC rate allows ETG to implement surcharges or credits during the months of October through May to compensate for weather-related changes in customer usage from the previous winter period. For the preceding year, inclusive of the period following the Acquisition of ETG by SJI, regulatory actions regarding the WNC were as follows:
August 2018 - ETG filed its annual WNC rate adjustment petition, requesting a revenue decrease of $0.8 million to an annual revenue of $6.3 million to recover a deficiency from warmer than normal weather. This was approved in October 2018.
OSMC - The OSMC rate is designed to flow back to ETG’s firm customers the margins received from on-system sales and transportation services. For the preceding year, inclusive of the period following the Acquisition of ETG by SJI, regulatory actions regarding the OSMC were as follows:
August 2018 - ETG filed its annual OSMC rate adjustment petition, requesting a revenue increase of $1.1 million. This was approved in October 2018.
SBC - Similar to SJG, the SBC allows ETG to recover costs related to several BPU-mandated programs, including the RAC, the NJCEP and the USF program. SBC adjustments affect revenue and cash flows but do not directly affect earnings as related costs are deferred and recovered through rates on an on-going basis.
RAC - The RAC is similar to that of SJG defined above. As of December 31, 2018, ETG reflected the unamortized remediation costs of $10.9 million on the consolidated balance sheet as a regulatory asset. For the preceding year, inclusive of the period following the Acquisition of ETG by SJI, regulatory actions regarding the RAC were as follows:
August 2018 - ETG filed its annual RAC filing with the BPU, requesting a $6.9 million increase in RAC recoveries.
October 2018 - The BPU issued an Order maintain the current rate with no change in RAC recoveries, effective November 2018.
CEP - The CEP recovers costs associated with State mandated NJCEP related to ETG’s energy efficiency and renewable energy programs. In June of 2018, the BPU approved a NJCEP funding level of $344.7 million through June 2019, of which ETG is responsible for $10.6 million. For the preceding year, inclusive of the period following the Acquisition of ETG by SJI, regulatory actions regarding the CEP were as follows:
August 2018 - ETG filed its annual CEP rate adjustment petition, requesting a revenue decrease of $1.6 million to an annual revenue of $10.0 million to recovery costs mandated by the Board. This was approved in October 2018.
USF - The USF is similar to that of SJG defined above. For the preceding year, inclusive of the period following the Acquisition of ETG by SJI, regulatory actions regarding the USF were as follows:
June 2018 - ETG made its annual USF filing, along with the State’s other gas utilities, proposing to increase statewide electric and gas revenues by $7.2 million. This proposal included an increase to ETG’s annual USF recoveries of $0.8 million.
September 2018 - The BPU approved the Statewide budget of $45.5 million for all the State's gas utilities. ETG’s portion of the total is approximately $4.8 million, resulting in a $0.8 million increase to its USF recoveries, effective October 1, 2018.
Aside from EEP and WNC and carrying cost income/expense on the BGSS (expense only), CEP, RAC and USF, the clauses discussed above do not impact ETG’s earnings. They represent changes in the cash requirements of ETG corresponding to cost changes and/or previously over/under recoveries from ratepayers associated with each respective mechanism.
ELK:
As part of the Acquisition approval by the MPSC, the Company was required to provide ELK customers with a one-time bill credit of $0.3 million. Consistent with this requirement, ELK issued one-time bill credits to all customers in September 2018.
In June 2018, ELK filed a base rate case application with the MPSC. In January 2019, the PULJ issued a proposed ruling approving a settlement in which the parties agreed to revenue increase of approximately 90,000, with a 9.8% return on equity and a 6.98% overall return. In February 2019, the Commission approved ELK's new rates effective February 20, 2019.
Currently effective rate mechanisms reflected in ELK's tariff include a Purchase Gas Adjustment Clause (PGA) and Revenue Normalization Adjustment Clause (RNA). The PGA is a cost pass through for cost incurred from purchasing gas supplies for customers. Over/under recoveries are reconciled annually. The Company earns no profits on the PGA. The RNA is applicable to residential and commercial heating customers having a stated monthly revenue per customer. The primary variance is due to weather. The RNA amounts are established in a rate case for each customer grouping based on normal weather and the resultant average revenues per customer. The revenue excess or deficiency is calculated monthly and trued-up on a rolling twelve-month basis.
| REGULATORY ASSETS |
The discussion under Note 3, Rates and Regulatory Actions,10 is integral to the following explanations of specific regulatory assets and liabilities.
The Utilities Regulatory Assets at December 31 consisted of the following items (in thousands):
| December 31, 2018 | December 31, 2017 | ||||||||||||||||||||||
| 2016 | 2015 | SJG | ETG | ELK | Total SJI | Total SJI and SJG | |||||||||||||||||
| Environmental Remediation Costs: | |||||||||||||||||||||||
| Expended - Net | $ | 71,997 | $ | 42,032 | $ | 136,227 | $ | 10,875 | $ | — | $ | 147,102 | $ | 100,327 | |||||||||
| Liability for Future Expenditures | 153,047 | 123,194 | 148,071 | 104,594 | — | 252,665 | 171,696 | ||||||||||||||||
| Deferred Asset Retirement Obligation Costs | 43,014 | 42,430 | 31,096 | — | — | 31,096 | 42,368 | ||||||||||||||||
| Deferred Pension Costs - Unrecognized Prior Service Cost | — | 40,612 | 14 | 40,626 | — | ||||||||||||||||||
| Deferred Pension and Other Postretirement Benefit Costs | 85,693 | 79,779 | 80,121 | 2,607 | 30 | 82,758 | 78,211 | ||||||||||||||||
| Deferred Gas Costs - Net | — | 2,701 | 57,889 | — | 289 | 58,178 | 16,838 | ||||||||||||||||
| Conservation Incentive Program - Receivable | 27,567 | 2,624 | |||||||||||||||||||||
| CIP Receivable | — | — | — | — | 26,652 | ||||||||||||||||||
| Societal Benefit Costs Receivable | 2,173 | — | — | 2,173 | 2,484 | ||||||||||||||||||
| Deferred Interest Rate Contracts | 7,365 | 7,631 | 5,867 | — | — | 5,867 | 7,028 | ||||||||||||||||
| Energy Efficiency Tracker | 219 | 496 | 2,319 | — | — | 2,319 | 2,094 | ||||||||||||||||
| Pipeline Supplier Service Charges | 2,122 | 3,776 | 617 | — | — | 617 | 708 | ||||||||||||||||
| Pipeline Integrity Cost | 4,810 | 4,596 | 5,140 | — | — | 5,140 | 5,280 | ||||||||||||||||
| AFUDC - Equity Related Deferrals | 12,434 | 11,423 | 13,914 | — | — | 13,914 | 12,785 | ||||||||||||||||
| Weather Normalization | — | 3,210 | 139 | 3,349 | — | ||||||||||||||||||
| Other Regulatory Assets | 2,478 | 2,752 | 8,931 | 8,023 | 211 | 17,165 | 2,753 | ||||||||||||||||
| Total Regulatory Assets | $ | 410,746 | $ | 323,434 | $ | 492,365 | $ | 169,921 | $ | 683 | $ | 662,969 | $ | 469,224 | |||||||||
Except where noted below, all regulatory assets are or will be recovered through utility rate charges, as detailed in the following discussion. WeThe Utilities are currently permitted to recover interest on our Environmental Remediation Costs, Societal Benefit Costs Receivable, Energy Efficiency Tracker and Pipeline Integrity Costs, while the other assets are being recovered without a return on investment.
Environmental Remediation Costs - WeSJG and ETG have two regulatory assets associated with environmental costs related to the cleanup of environmental sites. SJG has 12 sites where weSJG or ourits predecessors previously operated gas manufacturing plants.plants, while ETG is subject to environmental remediation liabilities associated with six former manufactured gas plant sites in New Jersey. The first asset, "Environmental Remediation Cost: Expended - Net," represents what was actually spent to clean up the sites, less recoveries through the RAC and insurance carriers. These costs meet the deferral requirements of GAAP, as the BPU allows usSJG and ETG to recover such expenditures through the RAC. The other asset, "Environmental Remediation Cost: Liability for Future Expenditures," relates to estimated future expenditures required to complete the remediation of these sites. WeSJG and ETG recorded this estimated amount as a regulatory asset with the corresponding current and noncurrent liabilities on the consolidated balance sheets under the captions "Current Liabilities" (SJI and SJG) and "Deferred Credits and Other Noncurrent Liabilities" (SJI) and "Regulatory and Other Noncurrent Liabilities."Liabilities" (SJG). The BPU allows usSJG to recover the deferred costs over seven-year periods after they are spent (See Notes 3incurred. Accrued environmental remediation costs at ETG are recoverable from customers through rate mechanisms approved by the BPU.
Deferred ARO Costs - SJG records AROs primarily related to the legal obligation to cut and 12)cap gas distribution pipelines when taking those pipelines out of service. Deferred ARO costs represent the period to period passage of time (accretion) and the revision to cash flows originally estimated to settle the retirement obligation (see Note 1). The increaseDeferred ARO Costs regulatory asset decreased $11.3 million from December 31, 2015 is a result of expenditures made during 20162017 to December 31, 2018, due to revisions to the settlement timing, retirement costs, and an increase inchanges to inflation and discount rates used to measure the expected future expenditures for remediation activities, primarily dueretirement costs. A corresponding decrease was made to an increase in the scope of the remediation at a site related to additional contamination being discovered.ARO liability (see Note 1), thus having no impact on earnings.
Deferred Asset Retirement ObligationPension Costs - Unrecognized Prior Service Cost - This regulatory asset resulted from the recording of asset retirement obligations (ARO) and additional utility plant, primarilyThe BPU approved ETG to recover costs related to a legal obligation we haveETG's unrecognized prior service cost and actuarial gains/losses for certain safety requirements upon the retirementpension and postretirement benefits. This ETG deferred asset of our gas distribution$40.6 million is being amortized over 13.5 years for pension and transmission system. We recover asset retirement costs through rates charged to customers. All related accumulated accretion and depreciation amountsover 7.7 years for these ARO represent timing differences in the recognition of retirement costs that we are currently recovering in rates and, as such, we are deferring such differences as regulatory assets.postretirement benefits.
Deferred Pension and Other Postretirement Benefit Costs - The BPU authorized usSJG and ETG and the MPSC authorized ELK to recover costs related to postretirement benefits under the accrual method of accounting consistent with GAAP. SJG'sSJI's regulatory asset represents the recognition of the underfunded positions of ourSJIU's pension and other postretirement benefit plans. Subsequent adjustments to this balance occur annually to reflect changes in the funded positions of these benefit plans caused by changes in actual plan experience as well as assumptions of future experience (See(see Note 11)12).
Deferred Gas Costs - Net - Over/under collections of gas costs are monitored through SJG's and ETG's BGSS mechanism.bill credit . Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability (see Note 3)10). Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval (see Note 14)16). The BGSS regulatory assets of SJI and SJG increased $41.3 million and $41.0 million, respectively, from December 31, 2017 to December 31, 2018, primarily due to the actual gas commodity costs exceeding recoveries from customers.
Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 13.16.
Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program (See Note 3).EEP
Pipeline Supplier Service Charges - This regulatory asset represents costs necessary to maintain adequate supply and system pressures, which are being recovered on a monthly basis through the BGSS over the term of the underlying supplier contracts (see Note 3)10).
Pipeline Integrity Cost - As part of our September 2014SJG's October 2017 base rate increase, we wereSJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2014.October 2017. In addition, we areSJG is authorized to defer future program costs, including related carrying costs, for recovery in ourSJG's next base rate proceeding, subject to review by the BPU (see Note 3)10).
AFUDC Equity Related Deferrals - This regulatory asset represents the future revenue to recover the future income taxes related to the deferred tax liability for the equity component of AFUDC. Included in the balance is $1.0 million which is being recovered over a period of three years, as approved by the BPU in SJG’s 2014 rate case settlement. The remaining balancedeferred amount is being amortized over the life of the associated utility plant.
Weather Normalization - The tariffs for ETG include a weather normalization clause that reduces customer bills when winter weather is colder than normal and increases customer bills when winter weather is warmer than normal.
Other Regulatory Assets - Some of the assets included in Other Regulatory Assets are currently being recovered from ratepayers as approved by the BPU. Management believes the remaining deferred costs are probable of recovery from ratepayers through future utility rates. Included in this number for SJG is the impact of the ERIP on SJG employees, see Note 1.
The Utilities Regulatory Liabilities at December 31 consisted of the following items (in thousands):
| December 31, 2018 | December 31, 2017 | ||||||||||||||||||||||
| 2016 | 2015 | SJG | ETG | ELK | Total SJI | Total SJI and SJG | |||||||||||||||||
| Excess Plant Removal Costs | $ | 28,226 | $ | 32,644 | 20,805 | 47,909 | 1,393 | $ | 70,107 | $ | 23,295 | ||||||||||||
| Deferred Revenue - Net | 17,800 | — | |||||||||||||||||||||
| Societal Benefit Costs Payable | 3,095 | 10,197 | |||||||||||||||||||||
| Excess Deferred Taxes | 259,863 | 118,757 | 1,231 | 379,851 | 263,810 | ||||||||||||||||||
| Deferred Revenues - Net | — | 3,188 | — | 3,188 | — | ||||||||||||||||||
| CIP Payable | 5,871 | — | — | 5,871 | — | ||||||||||||||||||
| Amounts to be Refunded to Customers | — | 17,039 | — | 17,039 | — | ||||||||||||||||||
| Other Regulatory Liabilities | — | 2,443 | — | 2,443 | — | ||||||||||||||||||
| Total Regulatory Liabilities | $ | 49,121 | $ | 42,841 | $ | 286,539 | $ | 189,336 | $ | 2,624 | $ | 478,499 | $ | 287,105 | |||||||||
Excess Plant Removal Costs – Represents amounts accrued- The Utilities accrue and collect for cost of removal of utility property. This regulatory liability represents customer collections in excess of actual utility plant removal costs incurredexpenditures, which will be returned to date. As part of our September 2014 base rate increase, we are required to amortize approximately $1.1 million of this balancecustomers as a reduction to depreciation expense each year.expense. The Excess Plant Removal Costs Liability increased from December 31, 2017 due to the addition of ETG/ELK.
Excess Deferred RevenueTaxes - This liability is recognized as a result of Tax Reform enacted into law on December 22, 2017 (See Notes 1 and 4). The increase in this regulatory liability at SJI of $116.0 million for the year ended December 31, 2018 includes those excess deferred income tax liabilities of ETG and ELK resulting from Tax Reform. The decrease in this regulatory liability at SJG of $3.9 million for the year ended December 31, 2018 is related to excess tax amounts returned to customers through customer billings. The Unprotected amount of excess deferred taxes of $26.1 million will be returned to customers over a five year period. The remaining balance will be deferred until SJG's next base rate case as approved by the BPU. (See Note 10).
Deferred Revenues - Net - Over/under collections of gas costs are monitored through the ETG's BGSS mechanism. Net under collected gas costs are classified as a regulatory asset and net over collected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval.
CIP Payable - The BGSS changedCIP tracking mechanism at SJG adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. Actual usage per customer was more than the established baseline during 2018, resulting in a $2.7 million regulatory asset at December 31, 2015 to a $17.8 million regulatory liability at December 31, 2016,liability. This is primarily due to the gas costs recovered from customers exceedingresult of cold weather experienced in the actual cost of the commodity. See previous discussion under "Deferred Gas Costs - Net" above.region.
| 2016 | 2015 | 2014 | |||||||||
| Operating Revenues/Affiliates: | |||||||||||
| SJRG | $ | 6,934 | $ | 5,342 | $ | 959 | |||||
| Marina | 386 | 602 | 1,083 | ||||||||
| Other | — | 5 | — | ||||||||
| Total Operating Revenues/Affiliates | $ | 7,320 | $ | 5,949 | $ | 2,042 | |||||
| 2016 | 2015 | 2014 | |||||||||
| Costs of Sales/Affiliates | |||||||||||
| (Excluding depreciation): | |||||||||||
| SJRG | $ | 16,306 | $ | 26,090 | $ | 15,265 | |||||
| Derivative Losses/ (Gains) (See Note 1): | |||||||||||
| SJRG | $ | — | $ | 64 | $ | (1,582 | ) | ||||
| Operations Expense/Affiliates: | |||||||||||
| SJI | $ | 20,296 | $ | 14,088 | $ | 14,110 | |||||
| Millennium | 2,803 | 2,746 | 2,668 | ||||||||
| Other | (198 | ) | (412 | ) | (434 | ) | |||||
| Total Operations Expense/Affiliates | $ | 22,901 | $ | 16,422 | $ | 16,344 | |||||
| 2016 | 2015 | 2014 | |||||||||
| Tax at Statutory Rate | $ | 37,944 | $ | 36,233 | $ | 35,482 | |||||
| Increase (Decrease) Resulting from: | |||||||||||
| State Income Taxes | 4,096 | 4,584 | 1,935 | ||||||||
| Amortization of Investment Tax Credits | — | (149 | ) | (211 | ) | ||||||
| ESOP Dividend | (1,170 | ) | (1,168 | ) | (1,109 | ) | |||||
| AFUDC | (900 | ) | (1,109 | ) | (1,481 | ) | |||||
| Research and Development Credits | (613 | ) | (1,400 | ) | — | ||||||
| Other - Net | 9 | (46 | ) | 279 | |||||||
| Total Income Tax Expense | $ | 39,366 | $ | 36,945 | $ | 34,895 | |||||
| 2016 | 2015 | 2014 | |||||||||
| Current: | |||||||||||
| Federal | $ | — | $ | — | $ | 60 | |||||
| State | (1,614 | ) | (2,203 | ) | 2,642 | ||||||
| Total Current | (1,614 | ) | (2,203 | ) | 2,702 | ||||||
| Deferred: | |||||||||||
| Federal | 33,064 | 30,042 | 32,069 | ||||||||
| State | 7,916 | 9,255 | 335 | ||||||||
| Total Deferred | 40,980 | 39,297 | 32,404 | ||||||||
| Investment Tax Credits | — | (149 | ) | (211 | ) | ||||||
| Total Income Tax Expense | $ | 39,366 | $ | 36,945 | $ | 34,895 | |||||
| 2016 | 2015 | ||||||
| Deferred Tax Assets: | |||||||
| Net Operating Loss and Tax Credits | $ | 102,290 | $ | 64,978 | |||
| Deferred State tax | 24,574 | 20,825 | |||||
| Provision for Uncollectibles | 5,170 | 4,030 | |||||
| Pension & Other Post Retirement Benefits | 17,264 | 28,464 | |||||
| Deferred Revenues | 7,696 | 4,844 | |||||
| Other | 3,573 | 3,985 | |||||
| Total Deferred Tax Assets | $ | 160,567 | $ | 127,126 | |||
| Deferred Tax Liabilities: | |||||||
| Book Versus Tax Basis of Property | $ | 532,330 | $ | 480,682 | |||
| Deferred Fuel Costs - Net | 2,052 | 3,998 | |||||
| Environmental Remediation | 33,573 | 20,408 | |||||
| Deferred Regulatory Costs | 1,554 | 566 | |||||
| Deferred Pension & Other Post Retirement Benefits | 34,432 | 42,216 | |||||
| Budget Billing - Customer Accounts | 3,347 | 830 | |||||
| Section 461 Prepayments | 1,147 | 1,017 | |||||
| Conservation Incentive Program | 11,846 | 1,132 | |||||
| Other | 9,694 | 8,951 | |||||
| Total Deferred Tax Liabilities | $ | 629,975 | $ | 559,800 | |||
| Deferred Tax Liability - Net | $ | 469,408 | $ | 432,674 | |||
| 2016 | 2015 | 2014 | |||||||||
| Balance at January 1, | $ | 559 | $ | 552 | $ | 547 | |||||
| Increase as a result of tax position taken in prior years | 802 | 7 | 5 | ||||||||
| Balance at December 31, | $ | 1,361 | $ | 559 | $ | 552 | |||||
| 2016 | 2015 | |||||||||
| Long-Term Debt (A): | ||||||||||
| First Mortgage Bonds: (B) | ||||||||||
| 5.437 | % | Series due 2016 (C) | — | 10,000 | ||||||
| 4.60 | % | Series due 2016 (C) | — | 17,000 | ||||||
| 4.657 | % | Series due 2017 | 15,000 | 15,000 | ||||||
| 7.97 | % | Series due 2018 | 10,000 | 10,000 | ||||||
| 7.125 | % | Series due 2018 | 20,000 | 20,000 | ||||||
| 5.587 | % | Series due 2019 | 10,000 | 10,000 | ||||||
| 3.00 | % | Series due 2024 (D) | 50,000 | 50,000 | ||||||
| 3.03 | % | Series due 2024 (E) | 35,000 | 35,000 | ||||||
| 3.63 | % | Series due 2025 (F) | 8,182 | 9,091 | ||||||
| 4.84 | % | Series due 2026 (G) | 15,000 | 15,000 | ||||||
| 4.93 | % | Series due 2026 (H) | 45,000 | 45,000 | ||||||
| 4.03 | % | Series due 2027 | 45,000 | 45,000 | ||||||
| 4.01 | % | Series due 2030 (I) | 50,000 | 50,000 | ||||||
| 4.23 | % | Series due 2030 | 30,000 | 30,000 | ||||||
| 3.74 | % | Series due 2032 | 35,000 | 35,000 | ||||||
| 5.55 | % | Series due 2033 | 32,000 | 32,000 | ||||||
| 6.213 | % | Series due 2034 | 10,000 | 10,000 | ||||||
| 5.45 | % | Series due 2035 | 10,000 | 10,000 | ||||||
| Series A 2006 Tax-Exempt First Mortgage Bonds | ||||||||||
| Variable Rate, due 2036 (J) | 24,900 | 24,900 | ||||||||
| Variable Rate Bank Term Facility, due 2017 (K) | 200,000 | 139,000 | ||||||||
| Total Long-Term Debt Outstanding (L) | 645,082 | 611,991 | ||||||||
| Less Current Maturities | (215,909 | ) | (27,909 | ) | ||||||
| Long-Term Debt (L) | $ | 429,173 | $ | 584,082 | ||||||
| Total Facility | Usage | Available Liquidity | Expiration Date | ||||||||||
| Commercial Paper Program/ Revolving Credit Facility | $ | 200,000 | $ | 105,100 | (A) | $ | 94,900 | May 2018 | |||||
| Uncommitted Bank Lines | 10,000 | — | 10,000 | August 2017 | |||||||||
| Total | $ | 210,000 | $ | 105,100 | $ | 104,900 | |||||||
Net periodic benefit cost related to the SJI employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | Pension Benefits | ||||||||||
| 2018 | 2017 | 2016 | |||||||||
| Service Cost | $ | 6,442 | $ | 4,989 | $ | 4,843 | |||||
| Interest Cost | 13,778 | 11,772 | 12,125 | ||||||||
| Expected Return on Plan Assets | (18,672 | ) | (14,105 | ) | (13,508 | ) | |||||
| Amortizations: | |||||||||||
| Prior Service Cost | 116 | 131 | 212 | ||||||||
| Actuarial Loss | 11,528 | 10,282 | 9,394 | ||||||||
| Net Periodic Benefit Cost | 13,192 | 13,069 | 13,066 | ||||||||
| Curtailment and Special Termination Costs | 7,324 | — | — | ||||||||
| Capitalized Benefit Costs | (2,243 | ) | (4,723 | ) | (4,645 | ) | |||||
| Deferred Benefit Costs | (1,987 | ) | (527 | ) | (645 | ) | |||||
| Total Net Periodic Benefit Expense | $ | 16,286 | $ | 7,819 | $ | 7,776 | |||||
| Pension Benefits | Other Postretirement Benefits | |||||||||||||||||||||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | Other Postretirement Benefits | |||||||||||||||||||||||||||||||||
| 2016 | 2015 | 2014 | 2016 | 2015 | 2014 | 2018 | 2017 | 2016 | ||||||||||||||||||||||||||
| Service Cost | $ | 4,144 | $ | 4,430 | $ | 3,697 | $ | 576 | $ | 726 | $ | 585 | $ | 945 | $ | 910 | $ | 851 | ||||||||||||||||
| Interest Cost | 10,292 | 9,357 | 8,952 | 2,120 | 2,406 | 2,297 | 2,430 | 2,418 | 2,615 | |||||||||||||||||||||||||
| Expected Return on Plan Assets | (11,029 | ) | (11,914 | ) | (10,818 | ) | (2,823 | ) | (2,708 | ) | (2,467 | ) | (4,286 | ) | (3,411 | ) | (3,104 | ) | ||||||||||||||||
| Amortization: | ||||||||||||||||||||||||||||||||||
| Prior Service Cost (Credits) | 203 | 203 | 177 | (257 | ) | 499 | 133 | |||||||||||||||||||||||||||
| Amortizations: | ||||||||||||||||||||||||||||||||||
| Prior Service Credits | (344 | ) | (344 | ) | (344 | ) | ||||||||||||||||||||||||||||
| Actuarial Loss | 7,975 | 8,969 | 4,864 | 945 | 1,107 | 770 | 903 | 1,238 | 1,109 | |||||||||||||||||||||||||
| Net Periodic Benefit Cost | 11,585 | 11,045 | 6,872 | 561 | 2,030 | 1,318 | (352 | ) | 811 | 1,127 | ||||||||||||||||||||||||
| Curtailment and Special Termination Costs | 1,286 | (106 | ) | — | ||||||||||||||||||||||||||||||
| Capitalized Benefit Costs | (4,645 | ) | (4,805 | ) | (3,047 | ) | (277 | ) | (1,043 | ) | (722 | ) | (290 | ) | (46 | ) | (277 | ) | ||||||||||||||||
| Affiliate SERP Allocations | (1,960 | ) | (1,688 | ) | (1,313 | ) | — | — | — | |||||||||||||||||||||||||
| Deferred Benefit Costs | (644 | ) | (1,007 | ) | — | — | (256 | ) | — | 580 | — | — | ||||||||||||||||||||||
| Total Net Periodic Benefit Expense | $ | 4,336 | $ | 3,545 | $ | 2,512 | $ | 284 | $ | 731 | $ | 596 | $ | 1,224 | $ | 659 | $ | 850 | ||||||||||||||||
Curtailment and Special Termination Costs reflected in the tables above relate to the ERIP offered in 2018 as discussed in Note 1.
Net periodic benefit cost related to the SJG employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):
| SJG: | Pension Benefits | ||||||||||
| 2018 | 2017 | 2016 | |||||||||
| Service Cost | $ | 5,073 | $ | 4,303 | $ | 4,144 | |||||
| Interest Cost | 10,010 | 9,925 | 10,292 | ||||||||
| Expected Return on Plan Assets | (12,513 | ) | (11,366 | ) | (11,029 | ) | |||||
| Amortization: | |||||||||||
| Prior Service Cost | 112 | 127 | 203 | ||||||||
| Actuarial Loss | 10,074 | 8,692 | 7,975 | ||||||||
| Net Periodic Benefit Cost | 12,756 | 11,681 | 11,585 | ||||||||
| Capitalized Benefit Costs | (1,943 | ) | (4,723 | ) | (4,645 | ) | |||||
| Affiliate SERP Allocations | (3,861 | ) | (2,235 | ) | (1,960 | ) | |||||
| Deferred Benefit Costs | (1,987 | ) | (527 | ) | (644 | ) | |||||
| Total Net Periodic Benefit Expense | $ | 4,965 | $ | 4,196 | $ | 4,336 | |||||
| SJG: | Other Postretirement Benefits | ||||||||||
| 2018 | 2017 | 2016 | |||||||||
| Service Cost | $ | 583 | $ | 582 | $ | 576 | |||||
| Interest Cost | 1,698 | 1,897 | 2,120 | ||||||||
| Expected Return on Plan Assets | (3,449 | ) | (3,101 | ) | (2,823 | ) | |||||
| Amortization: | |||||||||||
| Prior Service Credits | (257 | ) | (257 | ) | (257 | ) | |||||
| Actuarial Loss | 695 | 972 | 945 | ||||||||
| Net Periodic Benefit Cost | (730 | ) | 93 | 561 | |||||||
| Capitalized Benefit Costs | (257 | ) | (46 | ) | (277 | ) | |||||
| Deferred Benefit Costs | 580 | — | — | ||||||||
| Total Net Periodic Benefit (Income)/Expense | $ | (407 | ) | $ | 47 | $ | 284 | ||||
Capitalized benefit costs reflected in the tabletables above relate to ourThe Utilities construction program. DeferredEffective January 1, 2018, SJI and SJG adopted FASB ASU 2017-07 which stipulates that only the service cost component of net benefit costs relate tocost is eligible for capitalization. In SJG's rate case settlement in October 2017, the BPU allowed deferral until the next base rate case of incremental expensesexpense associated with the adoption of new mortality tables in 2015. Deferred benefit costs are expected to be recovered through rates as part of our next base rate case.adoption. See Note 10.
Companies with publicly traded equity securities that sponsor a postretirement benefit plan are required to fully recognize, as an asset or liability, the overfunded or underfunded status of its benefit plans and recognize changes in the funded status in the year in which the changes occur. Changes in funded status are generally reported in Other Comprehensive Loss; however, since wethe Utilities recover all prudently incurred pension and postretirement benefit costs from ourits ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this statementrequirement are reported as regulatory assets (see Note 4)11).
Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive LossAOCL associated with Pension and Other Postretirement Benefits are as follows (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | Regulatory Assets | Accumulated Other Comprehensive Loss (pre-tax) | ||||||||||||||||||||||||||||
| Regulatory Assets | Accumulated Other Comprehensive Loss (pre-tax) | Pension Benefits | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | |||||||||||||||||||||||||
| Balance at January 1, 2017 | $ | 68,450 | $ | 17,243 | $ | 39,590 | $ | 2,821 | ||||||||||||||||||||||
| Pension Benefits | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | |||||||||||||||||||||||||||
| Balance at January 1, 2015 | $ | 71,177 | $ | 27,863 | $ | 23,170 | $ | — | ||||||||||||||||||||||
| Amounts Arising during the Period: | ||||||||||||||||||||||||||||||
| Net Actuarial (Gains)/Losses | (463 | ) | (3,155 | ) | 184 | — | ||||||||||||||||||||||||
| Prior Service Cost | — | (499 | ) | — | — | |||||||||||||||||||||||||
| Amounts Amortized to Net Periodic Costs: | ||||||||||||||||||||||||||||||
| Net Actuarial Loss | (6,079 | ) | (1,107 | ) | (2,891 | ) | — | |||||||||||||||||||||||
| Prior Service Cost | (203 | ) | (7,755 | ) | — | — | ||||||||||||||||||||||||
| Balance at December 31, 2015 | 64,432 | 15,347 | 20,463 | — | ||||||||||||||||||||||||||
| Amounts Arising during the Period: | ||||||||||||||||||||||||||||||
| Net Actuarial Loss | 9,706 | 2,584 | 6,129 | — | ||||||||||||||||||||||||||
| Net Actuarial Gain | 2,711 | (3,286 | ) | 18,506 | 1,614 | |||||||||||||||||||||||||
| Prior Service Credit | — | 257 | — | — | — | 257 | — | 84 | ||||||||||||||||||||||
| Amounts Amortized to Net Periodic Costs: | ||||||||||||||||||||||||||||||
| Net Actuarial Loss | (5,485 | ) | (945 | ) | (2,490 | ) | — | (6,066 | ) | (972 | ) | (4,160 | ) | (1,013 | ) | |||||||||||||||
| Prior Service Cost | (203 | ) | — | — | — | (126 | ) | — | (4 | ) | — | |||||||||||||||||||
| Balance at December 31, 2016 | $ | 68,450 | $ | 17,243 | $ | 24,102 | $ | — | ||||||||||||||||||||||
| Balance at December 31, 2017 | 64,969 | 13,242 | 53,932 | 3,506 | ||||||||||||||||||||||||||
| Amounts Arising during the Period: | ||||||||||||||||||||||||||||||
| Net Actuarial Gain (Loss) | 8,637 | 5,662 | (5,953 | ) | (1,819 | ) | ||||||||||||||||||||||||
| Prior Service Credit | 70 | (3,247 | ) | — | (2,471 | ) | ||||||||||||||||||||||||
| Other (Curtailments, Settlements, Special Termination) | — | — | — | 1,586 | ||||||||||||||||||||||||||
| Amounts Amortized to Net Periodic Costs: | ||||||||||||||||||||||||||||||
| Net Actuarial Loss | (6,025 | ) | (695 | ) | (5,450 | ) | (199 | ) | ||||||||||||||||||||||
| Prior Service Cost | (112 | ) | 257 | (4 | ) | 84 | ||||||||||||||||||||||||
| Balance at December 31, 2018 | $ | 67,539 | $ | 15,219 | $ | 42,525 | $ | 687 | ||||||||||||||||||||||
| SJG: | Regulatory Assets | Accumulated Other Comprehensive Loss (pre-tax) | |||||||||||||
| Pension Benefits | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | ||||||||||||
| Balance at January 1, 2017 | $ | 68,450 | $ | 17,243 | $ | 24,102 | $ | — | |||||||
| Amounts Arising during the Period: | |||||||||||||||
| Net Actuarial Gain | 2,711 | (3,286 | ) | 17,881 | — | ||||||||||
| Prior Service Credit | — | 257 | — | — | |||||||||||
| Amounts Amortized to Net Periodic Costs: | |||||||||||||||
| Net Actuarial Loss | (6,066 | ) | (972 | ) | (2,627 | ) | — | ||||||||
| Prior Service Cost | (126 | ) | — | — | — | ||||||||||
| Balance at December 31, 2017 | 64,969 | 13,242 | 39,356 | — | |||||||||||
| Amounts Arising during the Period: | |||||||||||||||
| Net Actuarial Gain | 6,590 | 5,071 | (911 | ) | — | ||||||||||
| Prior Service Credit | 70 | (3,247 | ) | — | — | ||||||||||
| Other (Curtailments, Settlements, Special Termination) | — | — | |||||||||||||
| Amounts Amortized to Net Periodic Costs: | |||||||||||||||
| Net Actuarial Loss | (6,025 | ) | (695 | ) | (4,049 | ) | — | ||||||||
| Prior Service Cost | (111 | ) | 257 | — | — | ||||||||||
| Balance at December 31, 2018 | $ | 65,493 | $ | 14,628 | $ | 34,396 | $ | — | |||||||
The estimated costs that will be amortized from Regulatory Assets for SJI and SJG into net periodic benefit costs in 20172019 are as follows (in thousands):
| Pension Benefits | Other Postretirement Benefits | |||||||||||||
| SJI and SJG (costs are the same for both entities): | Pension Benefits | Other Postretirement Benefits | ||||||||||||
| Prior Service Cost/(Credit) | $ | 127 | $ | (257 | ) | $ | 101 | $ | (474 | ) | ||||
| Net Actuarial Loss | $ | 6,202 | $ | 1,040 | $ | 5,837 | $ | 965 | ||||||
The estimated costs that will be amortized from Accumulated Other Comprehensive Lossfor SJI and SJG AOCL into net periodic benefit costs in 20172019 are as follows (in thousands):
| Pension Benefits | Other Postretirement Benefits | ||||||
| Net Actuarial Loss | $ | 2,378 | $ | — | |||
| Pension Benefits | Other Postretirement Benefits | ||||||
| SJI (includes SJG and all other consolidated subsidiaries): | |||||||
| Prior Service Cost/(Credit) | $ | 4 | $ | (102 | ) | ||
| Net Actuarial Loss | $ | 3,801 | $ | 120 | |||
| SJG: | |||||||
| Prior Service Cost/(Credit) | $ | — | $ | — | |||
| Net Actuarial Loss | $ | 2,579 | $ | — | |||
A reconciliation of the plans’plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in ourSJI's consolidated balance sheets follows (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||||||||
| Other | ||||||||||||||||||||||||||||||
| Pension Benefits | Postretirement Benefits | 2018 | 2017 | 2018 | 2017 | |||||||||||||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||||||||||||||||
Change in Benefit Obligations: | ||||||||||||||||||||||||||||||
| Change in Benefit Obligations: | ||||||||||||||||||||||||||||||
| Benefit Obligation at Beginning of Year | $ | 213,660 | $ | 221,605 | $ | 46,518 | $ | 60,670 | $ | 316,289 | $ | 278,288 | $ | 62,283 | $ | 60,350 | ||||||||||||||
| Acquisition Opening Obligation | 100,362 | — | 13,195 | — | ||||||||||||||||||||||||||
| Service Cost | 4,144 | 4,430 | 576 | 726 | 6,442 | 4,989 | 945 | 910 | ||||||||||||||||||||||
| Interest Cost | 10,292 | 9,357 | 2,120 | 2,406 | 13,778 | 11,772 | 2,430 | 2,418 | ||||||||||||||||||||||
| Actuarial Loss (Gain) | 17,463 | (13,107 | ) | 2,292 | (6,257 | ) | (26,274 | ) | 32,893 | (3,534 | ) | 1,411 | ||||||||||||||||||
| Retiree Contributions | — | — | 70 | 608 | — | — | 265 | 19 | ||||||||||||||||||||||
| Plan Amendments | — | — | — | (7,755 | ) | 7,394 | — | (3,012 | ) | — | ||||||||||||||||||||
| Benefits Paid | (9,203 | ) | (8,625 | ) | (3,027 | ) | (3,880 | ) | (15,835 | ) | (11,653 | ) | (3,061 | ) | (2,825 | ) | ||||||||||||||
| Benefit Obligation at End of Year | $ | 236,356 | $ | 213,660 | $ | 48,549 | $ | 46,518 | $ | 402,156 | $ | 316,289 | $ | 69,511 | $ | 62,283 | ||||||||||||||
| Change in Plan Assets: | ||||||||||||||||||||||||||||||
| Fair Value of Plan Assets at Beginning of Year | $ | 149,032 | $ | 144,568 | $ | 43,428 | $ | 40,951 | $ | 216,065 | $ | 189,542 | $ | 57,922 | $ | 50,532 | ||||||||||||||
| Acquisition Beginning Fair Value | 94,685 | — | 15,659 | — | ||||||||||||||||||||||||||
| Actual Return on Plan Assets | 12,656 | (913 | ) | 2,531 | (395 | ) | (10,399 | ) | 25,807 | (3,050 | ) | 7,390 | ||||||||||||||||||
| Employer Contributions | 2,244 | 14,002 | 2,946 | 6,144 | 2,704 | 12,369 | 2,796 | 2,806 | ||||||||||||||||||||||
| Retiree Contributions | — | — | 70 | 608 | — | — | 265 | 19 | ||||||||||||||||||||||
| Benefits Paid | (9,203 | ) | (8,625 | ) | (3,027 | ) | (3,880 | ) | (15,835 | ) | (11,653 | ) | (3,061 | ) | (2,825 | ) | ||||||||||||||
| Fair Value of Plan Assets at End of Year | $ | 154,729 | $ | 149,032 | $ | 45,948 | $ | 43,428 | $ | 287,220 | $ | 216,065 | $ | 70,531 | $ | 57,922 | ||||||||||||||
| Funded Status at End of Year: | $ | (114,936 | ) | $ | (100,224 | ) | $ | 1,020 | $ | (4,361 | ) | |||||||||||||||||||
| Amounts Related to Unconsolidated Affiliate | (147 | ) | 135 | 320 | 518 | |||||||||||||||||||||||||
| Accrued Net Benefit Cost at End of Year | $ | (115,083 | ) | $ | (100,089 | ) | $ | 1,340 | $ | (3,843 | ) | |||||||||||||||||||
| Amounts Recognized in the Statement of Financial Position Consist of: | ||||||||||||||||||||||||||||||
| Current Liabilities | $ | (3,631 | ) | $ | (2,388 | ) | $ | — | $ | — | ||||||||||||||||||||
| Noncurrent Liabilities | (111,452 | ) | (97,701 | ) | 1,340 | (3,843 | ) | |||||||||||||||||||||||
| Net Amount Recognized at End of Year | $ | (115,083 | ) | $ | (100,089 | ) | $ | 1,340 | $ | (3,843 | ) | |||||||||||||||||||
| Amounts Recognized in Regulatory Assets Consist of: | ||||||||||||||||||||||||||||||
| Prior Service Costs | $ | 162 | $ | 428 | $ | (5,765 | ) | $ | (2,775 | ) | ||||||||||||||||||||
| Net Actuarial Loss | 67,377 | 64,541 | 20,984 | 16,017 | ||||||||||||||||||||||||||
| $ | 67,539 | $ | 64,969 | $ | 15,219 | $ | 13,242 | |||||||||||||||||||||||
| Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax): | ||||||||||||||||||||||||||||||
| Prior Service Costs | $ | 268 | $ | 47 | $ | (1,707 | ) | $ | (906 | ) | ||||||||||||||||||||
| Net Actuarial Loss | 42,257 | 53,885 | 2,394 | 4,412 | ||||||||||||||||||||||||||
| $ | 42,525 | $ | 53,932 | $ | 687 | $ | 3,506 | |||||||||||||||||||||||
| SJG: | Other | |||||||||||||||||||||||||||||
| Pension Benefits | Postretirement Benefits | |||||||||||||||||||||||||||||
| 2018 | 2017 | 2018 | 2017 | |||||||||||||||||||||||||||
Change in Benefit Obligations: | ||||||||||||||||||||||||||||||
| Benefit Obligation at Beginning of Year | $ | 269,066 | $ | 236,356 | $ | 49,098 | $ | 48,549 | ||||||||||||||||||||||
| Service Cost | 5,073 | 4,303 | 583 | 582 | ||||||||||||||||||||||||||
| Interest Cost | 10,010 | 9,925 | 1,698 | 1,897 | ||||||||||||||||||||||||||
| Actuarial Loss (Gain) | (13,009 | ) | 27,892 | (1,271 | ) | 328 | ||||||||||||||||||||||||
| Retiree Contributions | — | — | 143 | 15 | ||||||||||||||||||||||||||
| Plan Amendments | 4,169 | — | (3,247 | ) | — | |||||||||||||||||||||||||
| Benefits Paid | (10,486 | ) | (9,410 | ) | (2,122 | ) | (2,273 | ) | ||||||||||||||||||||||
| Benefit Obligation at End of Year | $ | 264,823 | $ | 269,066 | $ | 44,882 | $ | 49,098 | ||||||||||||||||||||||
| Change in Plan Assets: | ||||||||||||||||||||||||||||||
| Fair Value of Plan Assets at Beginning of Year | $ | 174,277 | $ | 154,729 | $ | 52,663 | $ | 45,948 | ||||||||||||||||||||||
| Actual Return on Plan Assets | (6,175 | ) | 18,666 | (2,893 | ) | 6,715 | ||||||||||||||||||||||||
| Employer Contributions | 2,669 | 10,292 | 1,979 | 2,259 | ||||||||||||||||||||||||||
| Retiree Contributions | — | — | 143 | 14 | ||||||||||||||||||||||||||
| Benefits Paid | (10,486 | ) | (9,410 | ) | (2,122 | ) | (2,273 | ) | ||||||||||||||||||||||
| Fair Value of Plan Assets at End of Year | $ | 160,285 | $ | 174,277 | $ | 49,770 | $ | 52,663 | ||||||||||||||||||||||
Funded Status at End of Year: | ||||||||||||||||||||||||||||||
| Accrued Net Benefit Cost at End of Year | $ | (81,627 | ) | $ | (64,628 | ) | $ | (2,601 | ) | $ | (3,090 | ) | $ | (104,538 | ) | $ | (94,789 | ) | $ | 4,888 | $ | 3,565 | ||||||||
| Amounts Recognized in the Statement of Financial Position Consist of: | ||||||||||||||||||||||||||||||
| Current Liabilities | $ | (2,428 | ) | $ | (2,227 | ) | $ | — | $ | — | $ | (3,597 | ) | $ | (2,353 | ) | $ | — | $ | — | ||||||||||
| Noncurrent Liabilities | (79,199 | ) | (62,401 | ) | (2,601 | ) | (3,090 | ) | (100,941 | ) | (92,436 | ) | 4,888 | 3,565 | ||||||||||||||||
| Net Amount Recognized at End of Year | $ | (81,627 | ) | $ | (64,628 | ) | $ | (2,601 | ) | $ | (3,090 | ) | $ | (104,538 | ) | $ | (94,789 | ) | $ | 4,888 | $ | 3,565 | ||||||||
| Amounts Recognized in Regulatory Assets Consist of: | ||||||||||||||||||||||||||||||
| Prior Service Costs | $ | 538 | $ | 741 | $ | (3,032 | ) | $ | (3,289 | ) | $ | 163 | $ | 428 | $ | (5,765 | ) | $ | (2,775 | ) | ||||||||||
| Net Actuarial Loss | 67,912 | 63,691 | 20,275 | 18,636 | 65,330 | 64,541 | 20,393 | 16,017 | ||||||||||||||||||||||
| Net Amount Recognized at End of Year | $ | 68,450 | $ | 64,432 | $ | 17,243 | $ | 15,347 | $ | 65,493 | $ | 64,969 | $ | 14,628 | $ | 13,242 | ||||||||||||||
| Amounts Recognized in Accumulated Other Comprehensive Loss Consist of: | ||||||||||||||||||||||||||||||
| Net Actuarial Loss | $ | 24,102 | $ | 20,463 | $ | — | $ | — | $ | 34,396 | $ | 39,356 | $ | — | $ | — | ||||||||||||||
The projected benefit obligation (PBO)PBO and accumulated benefit obligation (ABO)ABO of ourSJI's qualified employee pension plans were $183.2$329.2 million and $170.0$309.4 million, respectively, as of December 31, 2016;2018; and $167.6$243.9 million and $154.8$227.3 million, respectively, as of December 31, 2015.2017. The ABO of these plans exceeded the value of the plan assets as of December 31, 20162018 and 2015.2017. The value of these assets were $154.7$287.2 million and $149.0$216.1 million as of December 31, 20162018 and 2015,2017, respectively, and can be seen in the table above. The PBO and ABO for SJI's non-funded SERP were $73.0 million and $69.5 million, respectively, as of December 31, 2018; and $72.4 million and $63.9 million, respectively, as of December 31, 2017. SJI's SERP obligation is reflected in the tables above and has no assets.
The PBO and ABO of SJG's qualified employee pension plans were $188.1 million and $176.8 million, respectively, as of December 31, 2018; and $197.0 million and $183.5 million, respectively, as of December 31, 2017. The ABO of these plans exceeded the value of the plan assets as of December 31, 2018 and 2017. The value of these assets were $160.3 million and $174.3 million as of December 31, 2018 and 2017, respectively, and can be seen in the tables above. The PBO and ABO for ourSJG's non-funded SERP were $53.2$72.6 million and $51.2$69.1 million, respectively, as of December 31, 2016;2018; and $46.1$72.0 million and $44.6$63.6 million, respectively, as of December 31, 2015. The2017. SJG's SERP obligation is reflected in the tables above and has no assets.
The weighted-average assumptions used to determine benefit obligations for SJI and SJG at December 31 were:
| Pension Benefits | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | |||||||||||||||||||
| 2016 | 2015 | 2016 | 2015 | 2018 | 2017 | 2018 | 2017 | |||||||||||||||
| Discount Rate | 4.30 | % | 4.83 | % | 4.13 | % | 4.73 | % | 4.39 | % | 3.73 | % | 3.63 | % | 3.63 | % | ||||||
| Rate of Compensation Increase | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | ||||||
The weighted-average assumptions used to determine net periodic benefit cost for SJI and SJG for the years ended December 31 were:
| Pension Benefits | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | |||||||||||||||||||||||||||||||
| 2016 | 2015 | 2014 | 2016 | 2015 | 2014 | 2018 | 2017 | 2016 | 2018 | 2017 | 2016 | |||||||||||||||||||||||
| Discount Rate | 4.83 | % | 4.25 | % | 5.09 | % | 4.73 | % | 4.20 | % | 4.91 | % | 3.73 | % | 4.30 | % | 4.83 | % | 4.13 | % | 4.13 | % | 4.73 | % | ||||||||||
| Expected Long-Term Return on Plan Assets | 7.50 | % | 7.75 | % | 7.75 | % | 6.50 | % | 6.25 | % | 6.25 | % | 7.25 | % | 7.25 | % | 7.50 | % | 6.75 | % | 6.50 | % | 6.50 | % | ||||||||||
| Rate of Compensation Increase | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | ||||||||||
In 2014, the Society of Actuaries (SOA)SOA released new mortality tables (RP-2014 base table with MP-2014 generational projection scale)(RP-2014), which indicated that the average life expectancyCompany adopted as of both our active and retired plan participants had increased.December 31, 2014. Since then, the SOA has updated the mortality projection on an annual basis. The Company utilizes the most current projection tables available. The obligations as of December 31, 2014, disclosed herein reflect the use of those tables. In 2015, the SOA released an update to the RP-2014 tables (MP-2015 base tables), slightly reducing the average life expectancy previously released. The obligations as of December 31,2018, 2017 and 2016, and 2015, disclosed herein, reflect the use of the updated 2015 tables. While the adoption of the newprojection tables impacts liabilities significantly as of December 31 of the year of adoption, the impact on expense does not occur until the subsequent year.applicable to those years.
The discount rates used to determine the benefit obligations at December 31, 20162018 and 2015,2017, which are used to determine the net periodic benefit cost for the subsequent year, were based on a portfolio model of high-quality investments with maturities that match the expected benefit payments under our pension and other postretirement benefit plans.
The expected long-term return on plan assets (“return”) has been determined by applying long-term capital market projections provided by our pension plan Trustee to the asset allocation guidelines, as defined in the Company’sSJI's and SJG's investment policy, to arrive at a weighted average return. For certain other equity securities held by an investment manager outside of the control of the Trustee, the return has been determined based on historic performance in combination with long-term expectations. The return for the other postretirement benefits plan is determined in the same manner as discussed above; however, the expected return is reduced based on the taxable nature of the underlying trusts.
PLAN ASSETS — The Company’s- SJI's and SJG's overall investment strategy for pension plan assets is to achieve a diversification by asset class, style of manager, and sector and industry limits to achieve investment results that match the actuarially assumed rate of return, while preserving the inflation adjusted value of the plans. The Company hasSJI and SJG have implemented this diversification strategy primarily with commingled common/collective trust funds. The target allocations for pension plan assets are 28-48are40-70 percent U.S. equity securities, 13-2510-25 percent international equity securities, 32-4225-60 percent fixed income investments, and 0-70-20 percent to all other types of investments. Equity securities include investments in commingled common/collective trust funds as well as large-cap mid-cap and small-capmid-cap companies. Fixed income securities include commingled common/collective trust funds, group annuity contracts for pension payments, and hedge funds. Other types of investments include investments in private equity funds and real estate funds that follow several different strategies.
The strategy recognizes that risk and volatility are present to some degree with all types of investments. WeSJI and SJG seek to avoid high levels of risk at the total fund level through diversification by asset class, style of manager, and sector and industry limits. Specifically prohibited investments include, but are not limited to, venture capital, margin trading, commodities and securities of companies with less than $250.0 million capitalization (except in the small-cap portion of the fund where capitalization levels as low as $50.0 million are permissible). These restrictions are only applicable to individual investment managers with separately managed portfolios and do not apply to mutual funds or commingled trusts.
GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. This hierarchy groups assets into three distinct levels, as fully described in Note 13,17, which will serve as the basis for presentation throughout the remainder of this Note.
The fair values of SJG’sSJI's and SJG's pension plan assets at December 31, 20162018 and 20152017 by asset category are as follows (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | |||||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2018 | |||||||||||||||
| Cash / Cash Equivalents: | |||||||||||||||
| Cash | $ | 92,224 | $ | 92,224 | $ | — | $ | — | |||||||
| STIF-Type Instrument (a) | 1,653 | — | 1,653 | — | |||||||||||
| Equity securities: | |||||||||||||||
| U.S. Large-Cap (b) | 13,684 | 13,684 | — | — | |||||||||||
| U.S. Mid-Cap (b) | 1,502 | 1,502 | — | — | |||||||||||
| International (b) | 2,327 | 2,327 | — | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Guaranteed Insurance Contract (c) | 8,453 | — | — | 8,453 | |||||||||||
| Subtotal Fair Value | $ | 119,843 | $ | 109,737 | $ | 1,653 | $ | 8,453 | |||||||
| Measured at net asset value practical expedient (g): | |||||||||||||||
| Private Equity Fund (d) | $ | 8,867 | |||||||||||||
| Common/Collective Trust Funds - Real Estate (e) | 9,737 | ||||||||||||||
| 18,604 | |||||||||||||||
| Other Common/Collective Trust Funds (f): | |||||||||||||||
| Cash/Cash Equivalents | 696 | ||||||||||||||
| Equity Securities - U.S. | 63,418 | ||||||||||||||
| Equity Securities - International | 33,391 | ||||||||||||||
| Fixed Income | 51,268 | ||||||||||||||
| 148,773 | |||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 167,377 | |||||||||||||
| Total Fair Value | $ | 287,220 | |||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2016 | |||||||||||||||
| Cash / Cash Equivalents: | |||||||||||||||
| Cash | $ | 52 | $ | 52 | $ | — | $ | — | |||||||
| Common/Collective Trust Funds (a) | 376 | — | 376 | — | |||||||||||
| STIF-Type Instrument (b) | 1,168 | — | 1,168 | — | |||||||||||
| Equity securities: | |||||||||||||||
| Common/Collective Trust Funds – U.S. (a) | 42,369 | — | 42,369 | — | |||||||||||
| Common/Collective Trust Funds – International (a) | 27,017 | — | 27,017 | — | |||||||||||
| U.S. Large-Cap (c) | 14,523 | 14,523 | — | — | |||||||||||
| U.S. Mid-Cap (c) | 2,024 | 2,024 | — | — | |||||||||||
| U.S. Small-Cap (c) | — | — | — | ||||||||||||
| International (c) | 2,727 | 2,727 | — | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Common/Collective Trust Funds (a) | 44,873 | — | 44,873 | — | |||||||||||
| Guaranteed Insurance Contract (d) | 7,930 | — | — | 7,930 | |||||||||||
| Hedge Funds (e) | — | — | — | — | |||||||||||
| Other types of investments: | |||||||||||||||
| Private Equity Fund (f) | 4,164 | — | — | 4,164 | |||||||||||
| Common/Collective Trust Fund – Real Estate (g) | 7,506 | — | — | 7,506 | |||||||||||
| Total | $ | 154,729 | $ | 19,326 | $ | 115,803 | $ | 19,600 | |||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2017 | |||||||||||||||
| Cash / Cash Equivalents: | |||||||||||||||
| Cash | $ | 72 | $ | 72 | $ | — | $ | — | |||||||
| STIF-Type Instrument (a) | 1,522 | — | 1,522 | — | |||||||||||
| Equity securities: | |||||||||||||||
| U.S. Large-Cap (b) | 13,526 | 13,526 | — | — | |||||||||||
| U.S. Mid-Cap (b) | 1,701 | 1,701 | — | — | |||||||||||
| U.S. Small-Cap (b) | 490 | 490 | — | — | |||||||||||
| International (b) | 3,260 | 3,260 | — | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Guaranteed Insurance Contract (c) | 9,211 | — | — | 9,211 | |||||||||||
| Subtotal Fair Value | $ | 29,782 | $ | 19,049 | $ | 1,522 | $ | 9,211 | |||||||
| Measured at net asset value practical expedient (g): | |||||||||||||||
| Private Equity Fund (d) | $ | 7,111 | |||||||||||||
| Common/Collective Trust Funds - Real Estate (e) | 9,813 | ||||||||||||||
| 16,924 | |||||||||||||||
| Other Common/Collective Trust Funds (f): | |||||||||||||||
| Cash/Cash Equivalents | 477 | ||||||||||||||
| Equity Securities - U.S. | 75,699 | ||||||||||||||
| Equity Securities - International | 39,077 | ||||||||||||||
| Fixed Income | 54,106 | ||||||||||||||
| 169,359 | |||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 186,283 | |||||||||||||
| Total Fair Value | $ | 216,065 | |||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2015 | |||||||||||||||
| Cash / Cash Equivalents: | |||||||||||||||
| Cash | $ | 28 | $ | 28 | — | $ | — | ||||||||
| Common/Collective Trust Funds (a) | 692 | — | 692 | — | |||||||||||
| STIF-Type Instrument (b) | 1,096 | — | 1,096 | — | |||||||||||
| Equity securities: | |||||||||||||||
| Common/Collective Trust Funds – U.S. (a) | 41,976 | — | 41,976 | — | |||||||||||
| Common/Collective Trust Funds – International (a) | 26,800 | — | 26,800 | — | |||||||||||
| U.S. Large-Cap (c) | 11,535 | 11,535 | — | — | |||||||||||
| U.S. Mid-Cap (c) | 2,748 | 2,748 | — | — | |||||||||||
| U.S. Small-Cap (c) | 210 | 210 | |||||||||||||
| International (c) | 1,367 | 1,367 | — | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Common/Collective Trust Funds (a) | 40,853 | — | 40,853 | — | |||||||||||
| Guaranteed Insurance Contract (d) | 8,031 | — | — | 8,031 | |||||||||||
| Hedge Funds (e) | 3,353 | — | — | 3,353 | |||||||||||
| Other types of investments: | |||||||||||||||
| Private Equity Fund (f) | 3,477 | — | — | 3,477 | |||||||||||
| Common/Collective Trust Fund – Real Estate (g) | 6,866 | — | — | 6,866 | |||||||||||
| Total | $ | 149,032 | $ | 15,888 | $ | 111,417 | $ | 21,727 | |||||||
| SJG: | |||||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2018: | |||||||||||||||
| Cash / Cash Equivalents: | |||||||||||||||
| Cash | $ | 19 | $ | 19 | $ | — | $ | — | |||||||
| STIF-Type Instrument (a) | 1,359 | — | 1,359 | — | |||||||||||
| Equity securities: | |||||||||||||||
| U.S. Large-Cap (b) | 11,247 | 11,247 | — | — | |||||||||||
| U.S. Mid-Cap (b) | 1,234 | 1,234 | — | — | |||||||||||
| International (b) | 1,912 | 1,912 | — | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Guaranteed Insurance Contract (c) | 6,947 | — | — | 6,947 | |||||||||||
| Subtotal Fair Value | $ | 22,718 | $ | 14,412 | $ | 1,359 | $ | 6,947 | |||||||
| Measured at net asset value practical expedient (g): | |||||||||||||||
| Private Equity Fund (d) | $ | 7,288 | |||||||||||||
| Common/Collective Trust Funds - Real Estate (e) | 8,003 | ||||||||||||||
| 15,291 | |||||||||||||||
| Other Common/Collective Trust Funds (f): | |||||||||||||||
| Cash/Cash Equivalents | 572 | ||||||||||||||
| Equity Securities - U.S. | 52,123 | ||||||||||||||
| Equity Securities - International | 27,444 | ||||||||||||||
| Fixed Income | 42,137 | ||||||||||||||
| 122,276 | |||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 137,567 | |||||||||||||
| Total Fair Value | $ | 160,285 | |||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2017: | |||||||||||||||
| Cash / Cash Equivalents: | |||||||||||||||
| Cash | $ | 58 | $ | 58 | $ | — | $ | — | |||||||
| STIF-Type Instrument (a) | 1,228 | — | 1,228 | — | |||||||||||
| Equity securities: | |||||||||||||||
| U.S. Large-Cap (b) | 10,910 | 10,910 | — | — | |||||||||||
| U.S. Mid-Cap (b) | 1,372 | 1,372 | — | — | |||||||||||
| U.S. Small-Cap (b) | 395 | 395 | — | — | |||||||||||
| International (b) | 2,629 | 2,629 | — | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Guaranteed Insurance Contract (c) | 7,429 | — | — | 7,429 | |||||||||||
| Subtotal Fair Value | $ | 24,021 | $ | 15,364 | $ | 1,228 | $ | 7,429 | |||||||
| Measured at net asset value practical expedient (g): | |||||||||||||||
| Private Equity Fund (d) | $ | 5,735 | |||||||||||||
| Common/Collective Trust Funds - Real Estate (e) | 7,920 | ||||||||||||||
| 13,655 | |||||||||||||||
| Other Common/Collective Trust Funds (f): | |||||||||||||||
| Cash/Cash Equivalents | 385 | ||||||||||||||
| Equity Securities - U.S. | 61,057 | ||||||||||||||
| Equity Securities - International | 31,519 | ||||||||||||||
| Fixed Income | 43,640 | ||||||||||||||
| 136,601 | |||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 150,256 | |||||||||||||
| Total Fair Value | $ | 174,277 | |||||||||||||
| (a) |
| This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements. Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information. Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments. |
| This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy. These common stocks are actively traded on exchanges and price quotes for these shares are readily available. These common stocks are classified as Level 1 investments. |
| This category represents SJI’s Group Annuity contracts with a nationally recognized life insurance company. The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder. Valuation is based on a formula and calculation specified within the contract. Since the valuation is based on the reporting entity’s own assumptions, these contracts are classified as Level 3 investments. |
| This category represents a limited partnership which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June or September 30, |
| This category represents real estate common/collective trust fund investments through a commingled employee benefit trust. These commingled funds are part of a direct investment in a pool of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals from sources with professional qualifications. |
| (f) | This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not |
| (g) | Subsequent to the |
Fair Value Measurement Using Significant
Unobservable Inputs (Level 3)
(In thousands)
| SJI (includes SJG and all other consolidated subsidiaries): | Guaranteed | Private | ||||||||||||||||||||||||||||||||
| Insurance | Equity | Real | ||||||||||||||||||||||||||||||||
| Contract | Funds (A) | Estate (A) | Total | |||||||||||||||||||||||||||||||
Guaranteed Insurance Contract | Hedge Funds | Private Equity Funds | Real Estate | Total | ||||||||||||||||||||||||||||||
| Balance at January 1, 2015 | $ | 8,738 | $ | 3,469 | $ | 2,895 | $ | 5,987 | $ | 21,089 | ||||||||||||||||||||||||
| Balance at January 1, 2017 | $ | 9,714 | $ | — | $ | — | $ | 9,714 | ||||||||||||||||||||||||||
| Actual return on plan assets: | ||||||||||||||||||||||||||||||||||
| Relating to assets still held at the reporting date | (26 | ) | (116 | ) | (223 | ) | 879 | 514 | 245 | — | — | 245 | ||||||||||||||||||||||
| Relating to assets sold during the period | 21 | — | 346 | — | 367 | 12 | — | — | 12 | |||||||||||||||||||||||||
| Purchases, Sales and Settlements | (702 | ) | — | 459 | — | (243 | ) | (760 | ) | — | — | (760 | ) | |||||||||||||||||||||
| Balance at December 31, 2015 | $ | 8,031 | $ | 3,353 | $ | 3,477 | $ | 6,866 | $ | 21,727 | ||||||||||||||||||||||||
| Balance at December 31, 2017 | 9,211 | — | — | 9,211 | ||||||||||||||||||||||||||||||
| Actual return on plan assets: | — | — | — | |||||||||||||||||||||||||||||||
| Relating to assets still held at the reporting date | 541 | (13 | ) | (71 | ) | 640 | 1,097 | (53 | ) | — | — | (53 | ) | |||||||||||||||||||||
| Relating to assets sold during the period | 12 | — | 200 | — | 212 | 13 | — | — | 13 | |||||||||||||||||||||||||
| Purchases, Sales and Settlements | (654 | ) | (3,340 | ) | 558 | — | (3,436 | ) | (718 | ) | — | — | (718 | ) | ||||||||||||||||||||
| Balance at December 31, 2016 | $ | 7,930 | $ | — | $ | 4,164 | $ | 7,506 | $ | 19,600 | ||||||||||||||||||||||||
| Balance at December 31, 2018 | $ | 8,453 | $ | — | $ | — | $ | 8,453 | ||||||||||||||||||||||||||
| SJG: | Guaranteed Insurance Contract | Private Equity Funds (A) | Real Estate (A) | Total | |||||||||||
| Balance at January 1, 2017 | $ | 7,930 | $ | — | $ | — | $ | 7,930 | |||||||
| Actual return on plan assets: | |||||||||||||||
| Relating to assets still held at the reporting date | 103 | — | — | 103 | |||||||||||
| Relating to assets sold during the period | 9 | — | — | 9 | |||||||||||
| Purchases, Sales and Settlements | (613 | ) | — | — | (613 | ) | |||||||||
| Balance at December 31, 2017 | $ | 7,429 | $ | — | $ | — | $ | 7,429 | |||||||
| Actual return on plan assets: | |||||||||||||||
| Relating to assets still held at the reporting date | 98 | — | — | 98 | |||||||||||
| Relating to assets sold during the period | 11 | — | — | 11 | |||||||||||
| Purchases, Sales and Settlements | (591 | ) | — | — | (591 | ) | |||||||||
| Balance at December 31, 2018 | $ | 6,947 | $ | — | $ | — | $ | 6,947 | |||||||
(A) The 2017 amounts have been reclassified to NAV as per (g) above.
As with the pension plan assets, the Company’sSJI's and SJG's overall investment strategy for post-retirement benefit plan assets is to achieve a diversification by asset class, style of manager, and sector and industry limits to achieve investment results that match the actuarially assumed rate of return, while preserving the inflation adjusted value of the plans. The Company hasSJI and SJG have implemented this diversification strategy with a mix of common/collective trust funds, mutual funds and Company-owned life insurance policies. The target allocations for post-retirement benefit plan assets are 30-4355-75 percent U.S. equity securities, 20-3010-20 percent international equity securities, and 32-4225-45 percent fixed income investments and 0-7 percent to all other types of investments. Equity securities include investments in large-cap, mid-cap and small-cap companies within mutual funds or common/collective trust funds. Fixed income securities within the common/collective trust fund include primarily investment grade, U.S. Government and mortgage-backed financial instruments. The insurance policies are backed by a series of commingled trust investments held by the insurance carrier.
The fair values of SJG’sSJI's and SJG's other postretirement benefit plan assets at December 31, 20162018 and 20152017 by asset category are as follows (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | |||||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2018: | |||||||||||||||
| Cash | $ | 16,720 | $ | 16,720 | $ | — | $ | — | |||||||
| Other Types of Investments: | |||||||||||||||
| Mutual Funds - REITS (a) | 822 | 822 | — | — | |||||||||||
| Subtotal Fair Value | $ | 17,542 | $ | 17,542 | $ | — | $ | — | |||||||
| Measured at net asset value practical expedient (c): | |||||||||||||||
| Common/Collective Trust Funds (b): | |||||||||||||||
| Equity Securities - U.S. | $ | 14,069 | |||||||||||||
| Equity Securities - International | 9,720 | ||||||||||||||
| Fixed Income | 15,315 | ||||||||||||||
| Company Owned Life Insurance (b) | 13,885 | ||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 52,989 | |||||||||||||
| Total Fair Value | $ | 70,531 | |||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2017: | |||||||||||||||
| Other Types of Investments: | |||||||||||||||
| Mutual Funds - REITS (a) | $ | 864 | $ | 864 | $ | — | $ | — | |||||||
| Subtotal Fair Value | $ | 864 | $ | 864 | $ | — | $ | — | |||||||
| Measured at net asset value practical expedient (c): | |||||||||||||||
| Common/Collective Trust Funds (b): | |||||||||||||||
| Equity Securities - U.S. | $ | 15,101 | |||||||||||||
| Equity Securities - International | 11,378 | ||||||||||||||
| Fixed Income | 15,272 | ||||||||||||||
| Company Owned Life Insurance (b) | 15,307 | ||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 57,058 | |||||||||||||
| Total Fair Value | $ | 57,922 | |||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2016 | |||||||||||||||
| Cash | $ | — | $ | — | $ | — | $ | — | |||||||
| Equity Securities: | |||||||||||||||
| Common/Collective Trust Funds - U.S. (a) | 13,372 | — | 13,372 | $ | — | ||||||||||
| Common/Collective Trust Funds - International (a) | 7,796 | — | 7,796 | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Common/Collective Trust Funds - Bonds (a) | 12,167 | — | 12,167 | — | |||||||||||
| Other Types of Investments: | |||||||||||||||
| Company Owned Life Insurance (c) | 12,613 | — | 12,613 | — | |||||||||||
| Total | $ | 45,948 | $ | — | $ | 45,948 | $ | — | |||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2015 | |||||||||||||||
| Cash | $ | 26 | $ | 26 | $ | — | $ | — | |||||||
| Equity Securities: | |||||||||||||||
| Common/Collective Trust Funds - U.S. (a) | 12,154 | — | 12,154 | $ | — | ||||||||||
| Common/Collective Trust Funds - International (a) | 7,471 | — | 7,471 | — | |||||||||||
| Mutual Fund - U.S. (b) | 1,228 | 1,228 | — | — | |||||||||||
| Mutual Funds - International (b) | 922 | 922 | — | — | |||||||||||
| Fixed Income: | |||||||||||||||
| Common/Collective Trust Funds - Bonds (a) | 11,852 | — | 11,852 | — | |||||||||||
| Mutual Funds - Bonds (b) | 1,352 | 1,352 | — | — | |||||||||||
| Other Types of Investments: | |||||||||||||||
| Mutual Funds - REITS (b) | 142 | 142 | — | — | |||||||||||
| Company Owned Life Insurance (c) | 8,281 | — | 8,281 | — | |||||||||||
| Total | $ | 43,428 | $ | 3,670 | $ | 39,758 | $ | — | |||||||
| SJG: | |||||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2018 | |||||||||||||||
| Cash | $ | 859 | $ | 859 | $ | — | $ | — | |||||||
| Other Types of Investments: | |||||||||||||||
| Mutual Funds - REITS (a) | 740 | 740 | — | — | |||||||||||
| Subtotal Fair Value | $ | 1,599 | $ | 1,599 | $ | — | $ | — | |||||||
| Measured at net asset value practical expedient (c): | |||||||||||||||
| Common/Collective Trust Funds (b): | |||||||||||||||
| Equity Securities - U.S. | $ | 12,645 | |||||||||||||
| Equity Securities - International | 8,735 | ||||||||||||||
| Fixed Income | 13,764 | ||||||||||||||
| Company Owned Life Insurance (b) | 13,027 | ||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 48,171 | |||||||||||||
| Total Fair Value | $ | 49,770 | |||||||||||||
| Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
| As of December 31, 2017 | |||||||||||||||
| Other Types of Investments: | |||||||||||||||
| Mutual Funds - REITS (a) | $ | 777 | $ | 777 | $ | — | $ | — | |||||||
| Subtotal Fair Value | $ | 777 | $ | 777 | $ | — | $ | — | |||||||
| Measured at net asset value practical expedient (c): | |||||||||||||||
| Common/Collective Trust Funds (b): | |||||||||||||||
| Equity Securities - U.S. | $ | 13,572 | |||||||||||||
| Equity Securities - International | 10,226 | ||||||||||||||
| Fixed Income | 13,726 | ||||||||||||||
| Company Owned Life Insurance (b) | 14,362 | ||||||||||||||
| Subtotal measured at net asset value practical expedient | $ | 51,886 | |||||||||||||
| Total Fair Value | $ | 52,663 | |||||||||||||
| (a) | This category represents mutual fund investments. The mutual funds are actively traded on exchanges and price quotes for the shares are readily available. These mutual funds are classified as Level 1 investments. |
| (b) | This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active |
| This category |
| (c) | Subsequent to |
| Pension Benefits | Other Postretirement Benefits | |||||||||||||
| 2017 | $ | 10,339 | $ | 3,600 | ||||||||||
| 2018 | $ | 10,619 | $ | 3,577 | ||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | Pension Benefits | Other Postretirement Benefits | ||||||||||||
| 2019 | $ | 11,472 | $ | 3,677 | $ | 21,690 | $ | 5,873 | ||||||
| 2020 | $ | 11,921 | $ | 3,790 | $ | 22,382 | $ | 5,853 | ||||||
| 2021 | $ | 12,481 | $ | 3,811 | $ | 22,517 | $ | 5,811 | ||||||
| 2022 - 2026 | $ | 73,847 | $ | 18,131 | ||||||||||
| 2022 | $ | 23,108 | $ | 5,728 | ||||||||||
| 2023 | $ | 23,883 | $ | 5,561 | ||||||||||
| 2024 - 2028 | $ | 122,192 | $ | 24,069 | ||||||||||
| SJG: | Pension Benefits | Other Postretirement Benefits | |||||
| 2019 | $ | 12,777 | $ | 3,879 | |||
| 2020 | $ | 13,265 | $ | 3,888 | |||
| 2021 | $ | 13,674 | $ | 3,817 | |||
| 2022 | $ | 14,207 | $ | 3,739 | |||
| 2023 | $ | 14,788 | $ | 3,639 | |||
| 2024 - 2028 | $ | 79,003 | $ | 15,444 | |||
As part of the Acquisition, SJI acquired the existing pension and other post-employment benefit plans. The plans include a qualified defined benefit, trusteed, pension plan covering most eligible employees. The qualified pension plan is funded in accordance with requirements of the ERISA. The Company also provides certain non-qualified defined benefit and defined contribution pension plans for a selected group of the Company's management and highly compensated employees. Benefits under these non-qualified pension plans are funded on a cash basis. In addition, the entities also have a postretirement benefit plan, which provides certain medical care and life insurance benefits for eligible retired employees through a postretirement benefit plan. In 2018, SJI's Pension and Other Postretirement Benefits Liabilities balance was increased by us.$3.2 million, which is the fair value value of the acquired ETG and ELK Pension and Other Postretirement Benefits Liabilities at the time of the acquisition. The value of ETG and ELK's Pension and Other Postretirement Benefits Liabilities as of December 31, 2018 is $5.1 million.
| 13. | LINES OF CREDIT: |
Credit facilities and available liquidity as of December 31, 2018 were as follows (in thousands):
| Company | Total Facility | Usage | Available Liquidity | Expiration Date | ||||||||||
| SJI: | ||||||||||||||
| SJI Syndicated Revolving Credit Facility | $ | 400,000 | $ | 33,100 | (A) | $ | 366,900 | August 2022 | ||||||
| Revolving Credit Facility | 50,000 | 50,000 | — | September 2019 | ||||||||||
| Total SJI | 450,000 | 83,100 | 366,900 | |||||||||||
| SJG: | ||||||||||||||
Commercial Paper Program/Revolving Credit Facility | 200,000 | 108,300 | (B) | 91,700 | August 2022 | |||||||||
| Uncommitted Bank Line | 10,000 | 10,000 | August 2019 | |||||||||||
| Total SJG | 210,000 | 108,300 | 101,700 | |||||||||||
| ETG/ELK: | ||||||||||||||
| ETG/ELK Revolving Credit Facility | 200,000 | 86,000 | 114,000 | June 2020 | ||||||||||
| Total | $ | 860,000 | $ | 277,400 | $ | 582,600 | ||||||||
(A) Includes letters of credit outstanding in the amount of $6.1 million.
(B) Includes letters of credit outstanding in the amount of $0.8 million.
On June 26, 2018, SJI (as a guarantor to ELK's obligation under this revolving credit agreement) and ETG and ELK (as Borrowers) entered into a $200.0 million, two-year revolving credit agreement with several lenders. The revolving credit agreement provides for the extension of credit to the Borrowers in a total aggregate amount of $200.0 million ($175.0 million for ETG; $25.0 million for ELK), in the form of revolving loans up to a full amount of $200.0 million, swingline loans in an amount not to exceed an aggregate of $20.0 million and letters of credit in an amount not to exceed an aggregate of $50.0 million, each at the applicable interest rates specified in the revolving credit agreement. Subject to certain conditions set forth in the revolving credit agreement, ETG may increase the revolving credit facility up to a maximum aggregate amount of $50.0 million (for a total revolving facility of up to $250.0 million). This facility contains one financial covenant, limiting the ratio of indebtedness to total capitalization (as defined in the credit agreement) of each Borrower to not more than 0.70 to 1, measured at the end of each fiscal quarter. ETG and ELK were in compliance with this covenant at December 31, 2018. As of December 31, 2018, outstanding loans from this credit facility amount to $86.0 million.
The SJG and ETG/ELK facilities are restricted as to use and availability specifically to SJG and ETG/ELK, respectively; however, if necessary, the SJI facilities can also be used to support the liquidity needs of SJG, ETG or ELK. All committed facilities contain one financial covenant limiting the ratio of indebtedness to total capitalization of the applicable borrowers (as defined in the respective credit agreements), measured on a quarterly basis. SJI, SJG, ETG and ELK were in compliance with these covenants as of December 31, 2018. Borrowings under these credit facilities are at market rates.
SJI's weighted average interest rate on these borrowings (which includes SJG and ETG), which changes daily, was 3.32%, 2.46% and 1.47% at December 31, 2018, 2017 and 2016, respectively. SJG's weighted average interest rate on these borrowings, which changes daily, was 2.96%, 1.88% and 0.97% at December 31, 2018, 2017 and 2016, respectively.
SJI's average borrowings outstanding under these credit facilities (which includes SJG and ETG/ELK), not including letters of credit, during the years ended December 31, 2018 and 2017 were $265.5 million and $276.7 million, respectively. The maximum amounts outstanding under these credit facilities (which includes SJG and ETG/ELK), not including letters of credit, during the years ended December 31, 2018 and 2017 were $497.0 million and $373.8 million, respectively.
SJG's average borrowings outstanding under its credit facilities, not including letters of credit, during the years ended December 31, 2018 and 2017 were $86.0 million and $17.6 million, respectively. The maximum amount outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2018 and 2017 were $177.0 million and $110.1 million, respectively.
The SJI and SJG principal credit facilities are provided by a syndicate of banks. In January 2018, the NPA for Senior Unsecured Notes issued by SJI, as well as the credit agreements with its syndicate of banks, were amended to reflect a financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective NPA or credit agreement) to not more than 0.70 to 1, measured at the end of each fiscal quarter. For SJI, the equity units are treated as equity (as opposed to how they are classified on the consolidated balance sheet, as long-term debt) for purposes of the covenant calculation. Further, in the event that SJI receives less than $500.0 million of net cash proceeds from the issuance of equity or equity-linked securities, that financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective NPA or credit agreement) increases to not more than 0.75 to 1, measured at the end of each fiscal quarter, for a period of one year following the closing of the acquisition of ETG and ELK. SJI and SJG were in compliance with this covenant as of December 31, 2018. However, one SJG bank facility still contains a financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreement) to not more than 0.65 to 1 measured at the end of each fiscal quarter. As a result, SJG must ensure that the ratio of indebtedness to total capitalization (as defined in the respective credit agreement) does not exceed 0.65 to 1, as measured at the end of each fiscal quarter. SJG is was in compliance with this covenant as of December 31, 2018.
SJG has a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million. The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes. SJG uses the commercial paper program in tandem with the new $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.
| 14. | LONG-TERM DEBT: |
Outstanding Long-Term Debt at December 31 consisted of the following:
| 2018 | 2017 | ||||||||
| Long-Term Debt (A): | |||||||||
| SJG: | |||||||||
| First Mortgage Bonds: (B) | |||||||||
| 7.97% | Series due 2018 (C) | — | 10,000 | ||||||
| 7.125% | Series due 2018 (C) | — | 20,000 | ||||||
| 5.587% | Series due 2019 | 10,000 | 10,000 | ||||||
| 3.00% | Series due 2024 (D) | 50,000 | 50,000 | ||||||
| 3.03% | Series due 2024 (E) | 35,000 | 35,000 | ||||||
| 3.63% | Series due 2025 (F) | 6,364 | 7,273 | ||||||
| 4.84% | Series due 2026 (G) | 15,000 | 15,000 | ||||||
| 4.93% | Series due 2026 (H) | 45,000 | 45,000 | ||||||
| 4.03% | Series due 2027 (H) | 45,000 | 45,000 | ||||||
| 4.01% | Series due 2030 (I) | 42,000 | 50,000 | ||||||
| 4.23% | Series due 2030 | 30,000 | 30,000 | ||||||
| 3.74% | Series due 2032 (J) | 35,000 | 35,000 | ||||||
| 5.55% | Series due 2033 | 32,000 | 32,000 | ||||||
| 6.213% | Series due 2034 | 10,000 | 10,000 | ||||||
| 5.45% | Series due 2035 | 10,000 | 10,000 | ||||||
| 3.00% | Series due 2047 | 200,000 | 200,000 | ||||||
| Series A 2006 Bonds at variable rates due 2036 (K) | 24,900 | 24,900 | |||||||
| SJG Term Facility (L) | — | 200,000 | |||||||
| SJG Term Loan (L) | 310,000 | — | |||||||
| Total SJG Long-Term Debt Outstanding (S) | $ | 900,264 | $ | 829,173 | |||||
| Less SJG Current Maturities | (18,909 | ) | (63,809 | ) | |||||
| Total SJG Long-Term Debt (S) | $ | 881,355 | $ | 765,364 | |||||
| SJI: | |||||||||
| 3.30% | Series due 2019 (T) | 60,000 | 60,000 | ||||||
| 3.30% | Series due 2019 (T) | 30,000 | 30,000 | ||||||
| 3.30% | Series due 2019 (T) | 50,000 | 50,000 | ||||||
| 3.71% | Series C 2012 Notes due 2022 (T) | 35,000 | 35,000 | ||||||
| 3.47% | Series due 2024 (T) | 25,000 | 25,000 | ||||||
| 3.71% | Series due 2027 (T) | 25,000 | 25,000 | ||||||
| 3.57% | Series 2017A-2 due 2025 (T) | 25,000 | — | ||||||
| 3.81% | Series 2017B-2 due 2028 (T) | 25,000 | — | ||||||
| 3.43% | Series 2018A due 2021 (M) (T) | 90,000 | — | ||||||
| 4.07% | Series 2018B due 2028 (M) (T) | 80,000 | — | ||||||
| 4.17% | Series 2018C due 2030 (M) (T) | 80,000 | — | ||||||
| Series Notes at variable rates due 2019 (N) | 40,000 | 40,000 | |||||||
| Series Notes at variable rates due 2019 (N) | 60,000 | 60,000 | |||||||
| South Jersey Industries Term Loan at variable rates due 2020 (O) | 50,000 | 50,000 | |||||||
| Convertible Equity Units (M, P) | 287,500 | — | |||||||
| Series 2018D Notes at variable rates due 2019 (M, Q) | 475,000 | — | |||||||
| ETG: | |||||||||
| First Mortgage Bonds, Series 2018A: (R) | |||||||||
| 4.02% | Series 2018A-1 due 2028 | 50,000 | — | ||||||
| 4.22% | Series 2018A-2 due 2033 | 55,000 | — | ||||||
| 4.29% | Series 2018A-3 due 2038 | 150,000 | — | ||||||
| 4.37% | Series 2018A-4 due 2048 | 200,000 | — | ||||||
| 4.52% | Series 2018A-5 due 2058 | 75,000 | — | ||||||
| Total SJI Consolidated Long-Term Debt Outstanding (S) | $ | 2,867,764 | $ | 1,204,173 | |||||
| Less SJI Consolidated Current Maturities | (733,909 | ) | (63,809 | ) | |||||
| Total SJI Consolidated Long-Term Debt (S) | $ | 2,133,855 | $ | 1,140,364 | |||||
| (B) | In January 2017, SJG entered into a First Mortgage Indenture, which provides for the issuance by SJG of bonds, notes or other securities that are secured by a lien on substantially all of the operating properties and franchises of SJG. |
| (C) | In 2018, SJG retired $10.0 million of 7.97% MTN's, along with $20.0 million of 7.125% MTN's. |
| (D) | SJG has $50.0 million of 3.00% MTN's, with $10.0 million due annually beginning September 2020 with the final payment due September 2024. |
| (E) | SJG has $35.0 million of 3.03% MTN's, with $7.0 million due annually beginning November 2020 with the final payment due November 2024. |
| (F) | SJG pays $0.9 million annually toward the principal amount of 3.63% MTN's, with the final payment to be made December 2025. As such, $0.9 million of the total outstanding amount on this debt is classified in current portion of long-term debt on the consolidated balance sheets as it is due within one year. |
| (G) | SJG has $15.0 million of 4.84% MTN's, with $2.5 million due annually beginning March 2021 with the final payment due March 2026. |
| (H) | SJG has $45.0 million of 4.93% MTN's, with $7.5 million due annually beginning June 2021 with the final payment due June 2026. SJG also has $45.0 million of 4.03% MTN's, with $9.0 million due annually beginning in December 2023 with the final payment due in December 2027. |
| (I) | SJG has $42.0 million of 4.01% MTN's with several due dates, as follows: $8.0 million due November 2019; $2.0 million due November 2025; $3.0 million due November 2026; $8.0 million due November 2027; and $7.0 million each due November 2028, 2029 and 2030. |
| (J) | SJG has $35.0 million of 3.74% MTN's, with $3.175 million due annually beginning April 2022 with final payment due April 2032. |
| (K) | These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2018 was 1.78%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August 2021; as such, these bonds are recorded in current portion of long-term debt on the consolidated balance sheets. These bonds contain no financial covenants. |
| (L) | In January 2017, SJG entered into an unsecured, $200.0 million multiple-draw term loan credit agreement, on which SJG had borrowed the full $200.0 million as of December 31, 2017. In 2018, this was paid down, and in October 2018, SJG entered into an unsecured, $400.0 million term loan credit agreement (the “Credit Agreement”), which is syndicated among eight banks. Under the Credit Agreement, the Company can borrow up to an aggregate of $400.0 million from time to time until October 26, 2019. All loans under the Credit Agreement become due and payable on April 26, 2020. As of December 31, 2018, SJG borrowed $310.0 million. |
| (M) | Proceeds from these debt issuances, which occurred in the second quarter of 2018, were used to fund the Acquisition (see Notes 1 and 20). |
| (N) | At December 31, 2018, the floating rate on these Senior Notes was 4.38%. |
(O) At December 31, 2018, the floating rate on this Term Loan was 3.67%.
| (P) | In April 2018, SJI completed a public offering of Equity Units for gross proceeds of $287.5 million (see Note 6). As of December 31, 2018, these Equity Units were not converted into equity. |
| (Q) | At December 31, 2018, the floating rate on these Senior Notes was 3.76%. |
| (R) | In December 2018, ETG issued $530.0 million aggregate principal amount of its First Mortgage Bonds, Series 2018A, which were issued in five Tranches as shown in the table above. These bonds were issued under that First Mortgage Indenture dated as of July 2, 2018 between ETG and a Trustee, as supplemented by that First Supplement dated as of December 20, 2018, pursuant to a BPA dated as of December 20, 2018 between ETG and the purchasers named therein. The proceeds from the sale of these bonds were used to repay short-term indebtedness under a previous $530.0 million, 364-day term loan credit agreement dated as of June 26, 2018 among ETG (Borrower), SJI (Guarantor), the lenders party thereto and Bank of America, N.A., as Administrative Agent. Prior to repayment, the term loans bore interest at a variable base rate or a variable LIBOR at the election of the Company. |
| (S) | Total SJI consolidated Long-Term Debt in the table above does not include unamortized debt issuance costs of $27.0 million and $17.4 million for the years ended December 31, 2018 and 2017, respectively. Total SJG Long-Term Debt in the table above does not include unamortized debt issuance costs of $6.8 million and $7.3 million for the years ended December 31, 2018 and 2017, respectively. |
| (T) | In July 2018, the interest rates on these senior notes increased 25 basis points per annum due to a rating fee provision included in the respective note purchase agreements. This rating fee provision was triggered upon the S&P downgrading SJI from BBB+ to BBB. |
In 2019, SJI provided two separate Notices of CreditOptional Prepayment to the holders of its Floating Rate Senior Notes, Series 2018D, due June 20, 2019 of the Company’s intent to prepay a portion of the $475.0 million aggregate principal amount outstanding. See Note 22.
| 15. | COMMITMENTS AND CONTINGENCIES: |
GAS SUPPLY CONTRACTS - In the normal course of business, SJG, SJRG and ETG have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The transportation and storage service agreements with interstate pipeline suppliers were made under FERC approved tariffs. SJG's and ETG's cumulative obligation for gas supply-related demand charges and reservation fees paid to suppliers for these services averages approximately $5.7 million and $4.1 million per month, respectively. and is recovered on a current basis through the BGSS. SJRG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services averages approximately $1.3 million per month. SJRG has also committed to purchase 832,500 dts/d of natural gas, from various suppliers, for terms ranging from four to ten years at index based prices.
ETG has an AMA with SJRG for transportation and storage capacity to meet natural gas demands. The AMA is valid through March 31, 2022. It also requires SJRG to pay minimum annual fees of $4.25 million to ETG and includes tiered margin sharing levels between ETG and SJRG (see Note 1).
SJI has entered into a TSA with Southern Company Gas whereby the latter will provide certain administrative and operational services through no later than January 31, 2020.
PENDING LITIGATION - SJI and SJG are subject to claims arising in the ordinary course of business and other legal proceedings. SJI has been named in, among other actions, certain gas supply contract disputes and certain product liability claims related to our former sand mining subsidiary.
SJI is currently involved in a pricing dispute related to two long-term gas supply contracts. On May 8, 2017, a jury from the United States District Court for the District of Colorado returned a verdict in favor of the plaintiff supplier. On July 21, 2017, the court entered final judgment against SJG and SJRG. As a result of this ruling, SJG and SJRG have accrued, including interest, $22.1 million and $57.7 million, respectively, from the first quarter of 2017 through December 31, 2018. We believe that the amount to be paid by SJG reflects a gas cost that ultimately will be recovered from SJG’s customers through adjusted rates. As such, the $22.1 million associated with SJG above was recorded as both an Accounts Payable and an increase in Regulatory Assets on the consolidated balance sheets of both SJI and SJG as of December 31, 2018. Similarly, $57.7 million associated with SJRG was also recorded as an Accounts Payable on the consolidated balance sheets of SJI as of December 31, 2018, with charges of $4.1 million to Cost of Sales - Nonutility on the consolidated statements of income of SJI for the year ended December 31, 2018. SJI also recorded $1.0 million to Interest Charges on the consolidated statements of income for the year ended December 31, 2018. In April 2018, SJI filed an appeal of this judgment which was heard by the Tenth Circuit on January 22, 2019; however, no decision on the appeal has been made at the time of filing this Report. SJI continues to dispute the supplier invoices received and has created a reserve to reflect the differences between the invoices and paid amounts. The plaintiff supplier filed a second related lawsuit against SJG and SJRG in the United States District Court for the District of Colorado on December 21, 2017, alleging that SJG and SJRG have continued to breach the gas supply contracts notwithstanding the judgmentin the prior lawsuit. The plaintiff supplier is seeking recovery of the amounts disputed by SJI since the earlier judgment, and a declaration regarding the price under the disputed contracts going forward until the contracts terminate in October 2019. The outcome of this lawsuit will be determined by the outcome in the pending appeal of the first lawsuit. All reserves related to this second lawsuit are recorded as part of the accrued amounts disclosed above.
In August 2018, the State of New Jersey filed a civil enforcement action against SJG and several other current and former owners of certain property in Atlantic City, NJ where SJG and its predecessors previously operated a manufactured gas plant. The State of New Jersey is alleging damage to the State's natural resources and seeking payment for damages to those natural resources. SJG is working with a licensed state remediation professional to remediate the site. SJG is currently evaluating the merits of the State of New Jersey's allegations and, at this time, can provide no assessment of the claim or assurance regarding its outcome.
Liabilities related to claims are accrued when the amount or range of amounts of probable settlement costs or other charges for these claims can be reasonably estimated. For matters other than the disputes that are noted above, SJI has accrued approximately $3.2 million and $3.0 million related to all claims in the aggregate as of December 31, 2018 and 2017, respectively, of which SJG has accrued approximately $0.9 million and $0.7 million as of December 31, 2018 and 2017, respectively. Although SJI and SJG do not presently believe that these matters will have a material adverse effect on their businesses, given the inherent uncertainties in such situations, SJI and SJG can provide no assurance regarding the outcome of litigation.
COLLECTIVE BARGAINING AGREEMENTS— Unionized personnel represent approximately 45% and 58% of SJI's and SJG's workforce at December 31, 2018, respectively. SJI has collective bargaining agreements with unions that represent these employees: IBEW Local 1293; IAM Local 76; and UWUA Local 424. SJG employees represented by the IBEW operate under a collective bargaining agreement that runs through February 2022. SJG's remaining unionized employees are represented by the IAM and operate under a collective bargaining agreement that runs through August 2021. ETG employees represented by the UWUA operate under a collective bargaining agreement that runs through November 2019.
GUARANTEES - As of -December 31, 2018, SJI, the parent company, has issued guarantees to third parties on behalf of its consolidated subsidiaries. These guarantees were issued to guarantee payment to third parties with whom SJI's consolidated subsidiaries have commodity supply contracts. As of December 31, 2018, these guarantees support future firm commitments of SJI's consolidated subsidiaries and$134.6 million of the Accounts Payable already recorded on SJI's consolidated balance sheet.
As of December 31, 2018, SJI had issued $8.6 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable the subsidiary to market retail natural gas.
STANDBY LETTERS OF CREDIT — As of December 31, 2018, SJI provided $6.1 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. SJG provided a $25.2$0.8 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. SJG has provided $25.1 million of additional letters of credit under a separate facility outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA)NJEDA to finance the expansion of SJG’s natural gas distribution system.
Since the early 1980s, weSJI accrued environmental remediation costs of $420.2$627.1 million,, of which $267.2$373.5 million has been was spent as of December 31, 20162018. The accrued amount includes the addition of ETG environmental remediation beginning with the date of the Acquisition (see Note 20 and ETG discussion below). SJG accrued environmental remediation costs of $499.4 million, of which $351.4 million was spent as of December 31, 2018.
The following table details the amounts expended and accrued for SJI's and expended forSJG's environmental remediation at December 31during the last two years (in thousands):
| 2016 | 2015 | |||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | 2018 | 2017 | ||||||||||||
| Beginning of Year | $ | 123,194 | $ | 124,308 | $ | 172,855 | $ | 155,013 | ||||||
| Accruals | 61,933 | 18,747 | 58,706 | 56,405 | ||||||||||
| Expenditures | (32,080 | ) | (19,861 | ) | (51,176 | ) | (38,563 | ) | ||||||
| Opening Balance Sheet Adjustment (See Note 20) | 73,265 | — | ||||||||||||
| End of Year | $ | 153,047 | $ | 123,194 | $ | 253,650 | $ | 172,855 | ||||||
| SJG: | 2018 | 2017 | |||||
| Beginning of Year | $ | 171,696 | $ | 153,047 | |||
| Accruals | 21,695 | 55,814 | |||||
| Expenditures | (45,320 | ) | (37,165 | ) | |||
| End of Year | $ | 148,071 | $ | 171,696 | |||
The balances are segregated between current and noncurrent on the consolidated balance sheets under the captions Current Liabilities and RegulatoryDeferred Credits and Other Noncurrent Liabilities.
Management estimates that undiscounted future costs to clean up ourSJG's sites will range from $153.0$148.1 million to $257.1$253.7 million. Six of SJG's sites comprise the majority of these estimates, the sum of the six sites range from a low of $140.0 million. We to a high of $246.3 million. SJG recorded the lower end of this range$153.0 million, as a liability because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue.Six of our sites comprise the majority of these estimates, the sum of the six sites range from a low of $141.2 million to a high of $246.7 million. Recorded amounts include estimated costs based on projected investigation and remediation work plans using existing technologies. Actual costs could differ from the estimates due to the long-term nature of the projects, changing technology, government regulations and site-specific requirements. Significant risks surrounding these estimates include unforeseen market price increases for remedial services, property owner acceptance of remedy selection, regulatory approval of selected remedy and remedial investigative findings.
The remediation efforts at ourSJG's six most significant sites include the following:
Site 1 - Several interim remedial actions have been completed at the site. Steps remaining to remediate the balance of the site include selection of the remedial action, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy, long-term groundwater monitoring, and issuance of a Response Action Outcome.
Site 2 - Various remedial investigation activities have been completed at this site and a final site remedy has been approved by the regulatory authority. The first phase of remedial action is underway and preparation for the next step is ongoing. Remaining steps to remediate the site include continuedcompletion of the remedial action, long-term groundwater monitoring, and issuance of a Response Action Outcome.
Site 3 - Various remedial investigation activities have been completed at this site and a final site remedy has been approved by the regulatory authority. Steps remaining to remediate the site include implementation of the approved remedy, long term groundwater monitoring, and issuance of a Response Action Outcome.
Site 34 - VariousThe remedial action approved by the regulatory authority is currently being implemented. Remaining steps to remediate the site include post remediation groundwater monitoring, ongoing operation of the product recovery system, and issuance of a Response Action Outcome.
Site 5 - Remedial investigation activities have been completed at this site and a final site remedy is being developed for proposalhas been proposed to the regulatory authority. Steps remaining to remediate the site include selectionapproval of the final remedy, implementation of the approved remedy, and issuance of a final remedy,Response Action Outcome.
Site 6 - The remedial action to address impacted soil was completed in 2017. Steps remaining include long-term groundwater monitoring and issuance of a Response Action Outcome.
Management estimates that undiscounted future costs to clean up ETG's sites will range from $104.6 million to $189.8 million.
The remediation efforts at ETG's six sites include the following:
Site 1 - Remediation of soil and sediment has been completed and a Response Action Outcome has been received. No further efforts are needed at this time.
Site 2 - Several interim remedial actions have been completed at the site. Steps remaining to remediate the balance of the site include selection of the remedial action for the remaining areas, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy, long-term groundwater monitoring, and issuance of a Response Action Outcome.
Site 43 - Remedial investigation activities are completeInterim remedial actions have been completed at this site and a final remedy has been approved by the regulatory authority.site. Steps remaining to remediate the balance of the site include installationincluded selection of a sub-surface containment unit, post remediationthe remedial action for the remaining areas, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy, long-term groundwater monitoring, and issuance of a Response Action Outcome.
Site 4 - Soil remediation for the on-site portion of the work has been completed and unrestricted use closure documentation is expected in 2019. Steps remaining include investigation within a City owned park, remediation of any impacts found, and issuance of the appropriate closure documentation.
Site 5 -The remedial action to address impacted soil- Soil remediation at the site is ongoing.has been completed. Steps remaining include long-term groundwater monitoring and issuance of a Response Action Outcome.
Site 6 - RemedialVarious remedial investigation activities have been completed at thisthe site and a final site remedy is being developed for proposalhas been proposed to the regulatory authority. Steps remainingRemediation of offsite impacts to remediatebegin in 2019 and continue into 2020.
With Morie's sale in 1996, EMI assumed responsibility for environmental liabilities currently estimated between $0.5 million and $0.9 million. The information available on these sites is sufficient only to establish a range of probable liability and no point within the site include selection of a final remedy, confirmation of regulatory compliancerange is more likely than any other. Therefore, EMI has accrued the lower end of the selected remedy, implementationrange. Changes in the accrual are included in the statements of consolidated income under Loss from Discontinued Operations.
SJI and SJF estimate their potential exposure for the approved remedyfuture remediation of five sites where fuel oil operations existed years ago to range from $0.5 million to $0.9 million. The lower end of this range has been recorded under Current Liabilities and issuanceDeferred Credits and Other Noncurrent Liabilities as of a Response Action Outcome.December 31, 2018.
| DERIVATIVE INSTRUMENTS: |
Certain SJI subsidiaries, including SJG, are involved in buying, selling, transporting and storing natural gas and buying and selling retail electricity for their own accounts as well as managing these activities for third parties. These subsidiaries are subject to market risk on expected future purchases and sales due to commodity price fluctuations. SJI and SJG use a variety of derivative instruments to limit this exposure to market risk in accordance with strict corporate guidelines. These derivative instruments include forward contracts, swap agreements, options contracts and futures contracts.
As of December 31, 2018, SJI and SJG had outstanding derivative contracts as follows:
| SJI Consolidated | SJG | |||
| Derivative contracts intended to limit exposure to market risk to: | ||||
| Expected future purchases of natural gas (in MMdts) | 88.6 | 8.6 | ||
| Expected future sales of natural gas (in MMdts) | 71.6 | 0.7 | ||
| Expected future purchases of electricity (in MMmWh) | 1.7 | — | ||
| Expected future sales of electricity (in MMmWh) | 1.3 | — | ||
| Basis and Index related net purchase/(sale) contracts (in MMdts) | 54.9 | (1.1 | ) | |
These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Energy Related Assets or Derivatives - Energy Related Liabilities on the consolidated balance sheets of SJI and SJG. For SJE and SJRG contracts, the net unrealized pre-tax gains (losses) for these energy-related commodity contracts are included with realized gains (losses) in Operating Revenues – Nonutility on the consolidated statements of income for SJI. These pre-tax gains (losses) were $34.5 million, $(13.7) million and $26.9 million for the years ended December 31, 2018, 2017 and 2016, respectively. For ETG's and SJG's contracts, the costs or benefits are recoverable through the BGSS clause, subject to BPU approval. As a result, the net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the consolidated balance sheets of both SJI (ETG and SJG) and SJG. As of December 31, 2018 and 2017, SJI had $4.1 million and $(2.1) million, respectively, and SJG had $3.3 million and $(2.1) million, respectively, of unrealized gains (losses) included in its BGSS related to energy-related commodity contracts.
As part of its gas purchasing strategy, SJG uses financial contracts through SJRG to limit exposure to forward price risk. The costs or benefits of these short-term contracts are recoverable through SJG's BGSS clause, subject to BPU approval.
The retail electric operations of SJE use forward physical and financial contracts to mitigate commodity price risk on fixed price electric contracts.
Management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in identifying, assessing and controlling various risks. Management reviews any open positions in accordance with strict policies to limit exposure to market risk.
SJI, including SJG, has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, some of which had been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the consolidated balance sheets. Hedge accounting has been discontinued prospectively for these derivatives. As a result, any unrealized gains and losses on these derivatives, that were previously included in AOCL on the consolidated balance sheets, are being recorded in earnings over the remaining life of the derivative.
In March 2017, SJI entered into a new interest rate derivative and amended the existing interest rate derivative linked to unrealized losses previously recorded in AOCL. SJI reclassified $2.4 million of pre-tax unrealized loss in AOCL to Interest Charges on the consolidated statements of income as a result of the prior hedged transactions being deemed probable of not occurring.
For SJG interest rate derivatives, the fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates.
As of December 31, 2018, SJI's active interest rate swaps were as follows:
| Notional Amount | Fixed Interest Rate | Start Date | Maturity | Obligor | |||||
| $ | 20,000,000 | 3.049% | 3/15/2017 | 3/15/2027 | SJI | ||||
| $ | 20,000,000 | 3.049% | 3/15/2017 | 3/15/2027 | SJI | ||||
| $ | 10,000,000 | 3.049% | 3/15/2017 | 3/15/2027 | SJI | ||||
| $ | 12,500,000 | 3.530% | 12/1/2006 | 2/1/2036 | SJG | ||||
| $ | 12,500,000 | 3.430% | 12/1/2006 | 2/1/2036 | SJG | ||||
The unrealized gains and losses on interest rate derivatives that are not designated as cash flow hedges are included in Interest Charges on the consolidated statements of income. However, for selected interest rate derivatives at SJG, management believes that, subject to BPU approval, the market value upon termination can be recovered in rates and, therefore, these unrealized losses have been included in Other Regulatory Assets in the consolidated balance sheets.
The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands):
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||||||
| Derivatives not designated as hedging instruments under GAAP | December 31, 2018 | December 31, 2017 | ||||||||||||||
| Assets | Liabilities | Assets | Liabilities | |||||||||||||
| Energy-related commodity contracts: | ||||||||||||||||
| Derivatives - Energy Related - Current | $ | 54,021 | $ | 24,134 | $ | 42,139 | $ | 46,938 | ||||||||
| Derivatives - Energy Related - Non-Current | 7,169 | 7,256 | 5,988 | 6,025 | ||||||||||||
| Interest rate contracts: | ||||||||||||||||
| Derivatives - Other - Current | — | 588 | — | 748 | ||||||||||||
| Derivatives - Other - Noncurrent | — | 7,285 | — | 9,622 | ||||||||||||
| Total derivatives not designated as hedging instruments under GAAP | $ | 61,190 | $ | 39,263 | $ | 48,127 | $ | 63,333 | ||||||||
| Total Derivatives | $ | 61,190 | $ | 39,263 | $ | 48,127 | $ | 63,333 | ||||||||
| SJG: | ||||||||||||||||
| Derivatives not designated as hedging instruments under GAAP | December 31, 2018 | December 31, 2017 | ||||||||||||||
| Assets | Liabilities | Assets | Liabilities | |||||||||||||
| Energy-related commodity contracts: | ||||||||||||||||
| Derivatives – Energy Related – Current | $ | 5,464 | $ | 2,146 | $ | 7,327 | $ | 9,270 | ||||||||
| Derivatives – Energy Related – Non-Current | 15 | 43 | 5 | 170 | ||||||||||||
| Interest rate contracts: | ||||||||||||||||
| Derivatives - Other - Current | — | 343 | — | 389 | ||||||||||||
| Derivatives - Other - Non-Current | — | 5,524 | — | 6,639 | ||||||||||||
| Total derivatives not designated as hedging instruments under GAAP | 5,479 | 8,056 | 7,332 | 16,468 | ||||||||||||
| Total Derivatives | $ | 5,479 | $ | 8,056 | $ | 7,332 | $ | 16,468 | ||||||||
SJI and SJG enter into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. These derivatives are presented at gross fair values on the consolidated balance sheets.
As of December 31, 2018 and2017, information related to these offsetting arrangements were as follows (in thousands):
| As of December 31, 2018 | ||||||||||||||||||||||||
| Description | Gross amounts of recognized assets/liabilities | Gross amount offset in the balance sheet | Net amounts of assets/liabilities in balance sheet | Gross amounts not offset in the balance sheet | Net amount | |||||||||||||||||||
| Financial Instruments | Cash Collateral Posted | |||||||||||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||||||||||||||
| Derivatives - Energy Related Assets | $ | 61,190 | $ | — | $ | 61,190 | $ | (21,045 | ) | (A) | $ | (7,252 | ) | $ | 32,893 | |||||||||
| Derivatives - Energy Related Liabilities | $ | (31,390 | ) | $ | — | $ | (31,390 | ) | $ | 21,045 | (B) | $ | — | $ | (10,345 | ) | ||||||||
| Derivatives - Other | $ | (7,873 | ) | $ | — | $ | (7,873 | ) | $ | — | $ | — | $ | (7,873 | ) | |||||||||
| SJG: | ||||||||||||||||||||||||
| Derivatives - Energy Related Assets | $ | 5,479 | $ | — | $ | 5,479 | $ | (347 | ) | (A) | $ | 688 | $ | 5,820 | ||||||||||
| Derivatives - Energy Related Liabilities | $ | (2,189 | ) | $ | — | $ | (2,189 | ) | $ | 347 | (B) | $ | — | $ | (1,842 | ) | ||||||||
| Derivatives - Other | $ | (5,867 | ) | $ | — | $ | (5,867 | ) | $ | — | $ | — | $ | (5,867 | ) | |||||||||
| As of December 31, 2017 | ||||||||||||||||||||||||
| Description | Gross amounts of recognized assets/liabilities | Gross amount offset in the balance sheet | Net amounts of assets/liabilities in balance sheet | Gross amounts not offset in the balance sheet | Net amount | |||||||||||||||||||
| Financial Instruments | Cash Collateral Posted | |||||||||||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||||||||||||||
| Derivatives - Energy Related Assets | $ | 48,127 | $ | — | $ | 48,127 | $ | (24,849 | ) | (A) | $ | — | $ | 23,278 | ||||||||||
| Derivatives - Energy Related Liabilities | $ | (52,963 | ) | $ | — | $ | (52,963 | ) | $ | 24,849 | (B) | $ | 8,832 | $ | (19,282 | ) | ||||||||
| Derivatives - Other | $ | (10,370 | ) | $ | — | $ | (10,370 | ) | $ | — | $ | — | $ | (10,370 | ) | |||||||||
| SJG: | ||||||||||||||||||||||||
| Derivatives - Energy Related Assets | $ | 7,332 | $ | — | $ | 7,332 | $ | (208 | ) | (A) | $ | — | $ | 7,124 | ||||||||||
| Derivatives - Energy Related Liabilities | $ | (9,440 | ) | $ | — | $ | (9,440 | ) | $ | 208 | (B) | $ | 1,543 | $ | (7,689 | ) | ||||||||
| Derivatives - Other | $ | (7,028 | ) | $ | — | $ | (7,028 | ) | $ | — | $ | — | $ | (7,028 | ) | |||||||||
(A) The balances at December 31, 2018 and 2017 were related to derivative liabilities which can be net settled against derivative assets.
(B) The balances at December 31, 2018 and 2017 were related to derivative assets which can be net settled against derivative liabilities.
The effect of derivative instruments on the consolidated statements of income for the year ended December 31 is as follows (in thousands):
| Derivatives in Cash Flow Hedging Relationships under GAAP | 2018 | 2017 | 2016 | ||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | |||||||||||||
| Interest Rate Contracts: | |||||||||||||
| Losses reclassified from AOCL into income (a) | $ | (46 | ) | $ | (2,524 | ) | $ | (333 | ) | ||||
| SJG: | |||||||||||||
| Interest Rate Contracts: | |||||||||||||
| Losses reclassified from AOCL into income (a) | $ | (46 | ) | $ | (46 | ) | (46 | ) | |||||
(a) Included in Interest Charges
| Derivatives Not Designated as Hedging Instruments under GAAP | 2018 | 2017 | 2016 | |||||||||
| SJI (no balances for SJG; includes all other consolidated subsidiaries): | ||||||||||||
| Gains (losses) on energy-related commodity contracts (a) | $ | 34,509 | $ | (13,667 | ) | $ | 26,935 | |||||
| Gains (losses) on interest rate contracts (b) | 1,337 | (677 | ) | 647 | ||||||||
| Total | $ | 35,846 | $ | (14,344 | ) | $ | 27,582 | |||||
(a) Included in Operating Revenues - Nonutility
(b) Included in Interest Charges
Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on December 31, 2018, was $1.0 million. If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2018, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $0.2 million after offsetting asset positions with the same counterparties under master netting arrangements.
| 17. | FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL |
GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. The levels of the hierarchy are described below:
Level 1: Observable inputs, such as quoted prices in active markets for identical assets or liabilities.
Level 2: Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly; these include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.
Level 3: Unobservable inputs that reflect the reporting entity’s own assumptions.
Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of financial assets and financial liabilities and their placement within the fair value hierarchy.
For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands):
| As of December 31, 2016 | ||||||||||||||||||||||||||||||
| As of December 31, 2018 | Total | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||||
| Assets | ||||||||||||||||||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||||||||||||||||||||
| Available-for-Sale Securities (A) | $ | 41 | $ | 41 | $ | — | $ | — | ||||||||||||||||||||||
| Derivatives – Energy Related Assets (B) | 61,190 | 9,955 | 23,429 | 27,806 | ||||||||||||||||||||||||||
| Total | Level 1 | Level 2 | Level 3 | $ | 61,231 | $ | 9,996 | $ | 23,429 | $ | 27,806 | |||||||||||||||||||
| SJG: | ||||||||||||||||||||||||||||||
| Assets | ||||||||||||||||||||||||||||||
| Derivatives – Energy Related Assets (B) | 5,807 | 4,767 | — | 1,040 | $ | 5,479 | $ | 348 | $ | 126 | $ | 5,005 | ||||||||||||||||||
| $ | 5,807 | $ | 4,767 | $ | — | $ | 1,040 | $ | 5,479 | $ | 348 | $ | 126 | $ | 5,005 | |||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||||||||||||||||||||
| Liabilities | ||||||||||||||||||||||||||||||
| Derivatives – Energy Related Liabilities (B) | $ | 1,372 | $ | 6 | $ | 1,252 | $ | 114 | $ | 31,390 | $ | 7,291 | $ | 12,354 | $ | 11,745 | ||||||||||||||
| Derivatives – Other (C) | 7,365 | — | 7,365 | — | 7,873 | — | 7,873 | — | ||||||||||||||||||||||
| $ | 8,737 | $ | 6 | $ | 8,617 | $ | 114 | $ | 39,263 | $ | 7,291 | $ | 20,227 | $ | 11,745 | |||||||||||||||
| SJG: | ||||||||||||||||||||||||||||||
| Liabilities | ||||||||||||||||||||||||||||||
| Derivatives – Energy Related Liabilities (B) | $ | 2,189 | $ | 1,035 | $ | 1,077 | $ | 77 | ||||||||||||||||||||||
| Derivatives – Other (C) | 5,867 | — | 5,867 | — | ||||||||||||||||||||||||||
| $ | 8,056 | $ | 1,035 | $ | 6,944 | $ | 77 | |||||||||||||||||||||||
| As of December 31, 2015 | ||||||||||||||||||||||||||||||
| Total | Level 1 | Level 2 | Level 3 | |||||||||||||||||||||||||||
| As of December 31, 2017 | Total | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||||
| Assets | ||||||||||||||||||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||||||||||||||||||||
| Available-for-Sale Securities (A) | $ | 8,788 | $ | 1,722 | $ | 7,066 | $ | — | $ | 36 | $ | 36 | $ | — | $ | — | ||||||||||||||
| Derivatives – Energy Related Assets (B) | 1,141 | 398 | 144 | 599 | 48,127 | 5,155 | 21,869 | 21,103 | ||||||||||||||||||||||
| $ | 9,929 | $ | 2,120 | $ | 7,210 | $ | 599 | $ | 48,163 | $ | 5,191 | $ | 21,869 | $ | 21,103 | |||||||||||||||
| SJG: | ||||||||||||||||||||||||||||||
| Assets | ||||||||||||||||||||||||||||||
| Derivatives – Energy Related Assets (B) | $ | 7,332 | $ | 208 | $ | 230 | $ | 6,894 | ||||||||||||||||||||||
| $ | 7,332 | $ | 208 | $ | 230 | $ | 6,894 | |||||||||||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | ||||||||||||||||||||||||||||||
| Liabilities | ||||||||||||||||||||||||||||||
| Derivatives – Energy Related Liabilities (B) | $ | 5,840 | $ | 5,424 | $ | — | $ | 416 | $ | 52,963 | $ | 10,687 | $ | 24,283 | $ | 17,993 | ||||||||||||||
| Derivatives – Other (C) | 7,631 | — | 7,631 | — | 10,370 | — | 10,370 | — | ||||||||||||||||||||||
| $ | 13,471 | $ | 5,424 | $ | 7,631 | $ | 416 | $ | 63,333 | $ | 10,687 | $ | 34,653 | $ | 17,993 | |||||||||||||||
| SJG: | ||||||||||||||||||||||||||||||
Liabilities | ||||||||||||||||||||||||||||||
| Derivatives – Energy Related Liabilities (B) | $ | 9,440 | $ | 1,750 | $ | 2,848 | $ | 4,842 | ||||||||||||||||||||||
| Derivatives – Other (C) | 7,028 | — | 7,028 | — | ||||||||||||||||||||||||||
| $ | 16,468 | $ | 1,750 | $ | 9,876 | $ | 4,842 | |||||||||||||||||||||||
(A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy.
(B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable.
Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forward contracts, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
(C) Derivatives – Other include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.
The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands)thousands, except for ranges):
SJI (includes SJG and all other consolidated subsidiaries):
| Type | Fair Value at December 31, 2018 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | ||||||
| Assets | Liabilities | |||||||||
| Forward Contract - Natural Gas | $ | 20,706 | $ | 8,976 | Discounted Cash Flow | Forward price (per dt) | $1.56 - $9.00 [$3.12] | (A) | ||
| Forward Contract - Electric | $ | 7,100 | $ | 2,769 | Discounted Cash Flow | Fixed electric load profile (on-peak) | 0.00% - 100.00% [54.55%] | (B) | ||
| Fixed electric load profile (off-peak) | 0.00% - 100.00% [45.45%] | (B) | ||||||||
| Type | Fair Value at December 31, 2016 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | Fair Value at December 31, 2017 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | |||||||
| Assets | Liabilities | Assets | Liabilities | ||||||||||||
| Forward Contract - Natural Gas | $1,040 | $114 | Discounted Cash Flow | Forward price (per dt) | $3.25 - $6.33 [$5.09] | $ | 13,519 | $ | 15,686 | Discounted Cash Flow | Forward price (per dt) | $1.79 - $12.09 [$3.01] | (A) | ||
| Forward Contract - Electric | $ | 7,584 | $ | 2,307 | Discounted Cash Flow | Fixed electric load profile (on-peak) | 36.36% - 100.00% [53.39%] | (B) | |||||||
| Fixed electric load profile (off-peak) | 0.00% - 63.64% [46.61%] | (B) | |||||||||||||
SJG:
| Type | Fair Value at December 31, 2018 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | ||||||
| Assets | Liabilities | |||||||||
| Forward Contract - Natural Gas | $ | 5,005 | $ | 77 | Discounted Cash Flow | Forward price (per dt) | $3.13 - $6.00 [$4.53] | (A) | ||
| Type | Fair Value at December 31, 2015 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | Fair Value at December 31, 2017 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | |||||||
| Assets | Liabilities | Assets | Liabilities | ||||||||||||
| Forward Contract - Natural Gas | $599 | $416 | Discounted Cash Flow | Forward price (per dt) | $1.18 - $5.21 [$2.90] | $ | 6,894 | $ | 4,842 | Discounted Cash Flow | Forward price (per dt) | $2.42 - $6.67 [$5.25] | (A) | ||
(A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas.
(B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak.
The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 20162018 and 2015,2017, using significant unobservable inputs (Level 3), are as follows (in thousands):
SJI (includes SJG and all other consolidated subsidiaries):
| Year Ended December 31, 2018 | ||||
| Balance at January 1, 2018 | $ | 3,110 | ||
| Other changes in fair value from continuing and new contracts, net | 14,418 | |||
| Settlements | (1,467 | ) | ||
| Balance at December 31, 2018 | $ | 16,061 | ||
| Year Ended December 31, 2017 | ||||
| Balance at January 1, 2017 | $ | 9,035 | ||
| Other changes in fair value from continuing and new contracts, net | 1,857 | |||
| Transfers in to/(out of) of Level 3 (A) | (954 | ) | ||
| Settlements | (6,828 | ) | ||
| Balance at December 31, 2017 | $ | 3,110 | ||
SJG:
| Year Ended December 31, 2018 | ||||
| Balance at January 1, 2018 | $ | 2,052 | ||
| Other changes in fair value from continuing and new contracts, net | 4,928 | |||
| Settlements | (2,052 | ) | ||
| Balance at December 31, 2018 | $ | 4,928 | ||
| Year Ended December 31, 2016 | ||||
| Balance at January 1, 2016 | $ | 183 | ||
| Other Changes in Fair Value from Continuing and New Contracts, Net | 926 | |||
| Settlements | (183 | ) | ||
| Balance at December 31, 2016 | $ | 926 | ||
| Year Ended December 31, 2017 | ||||
| Balance at January 1, 2017 | $ | 926 | ||
| Other changes in fair value from continuing and new contracts, net | 2,258 | |||
| Transfers in to/(out of) of Level 3 (A) | (206 | ) | ||
| Settlements | (926 | ) | ||
| Balance at December 31, 2017 | $ | 2,052 | ||
(A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period, and are assessed quarterly by management. No transfers in or out of Level 3 occurred in 2018. During the year ended December 31, 2017, $1.0 million and $0.2 million of SJI's and SJG's net derivative assets, respectively, were transferred from Level 3 to Level 2, due to increased observability of market data.
Total gains for 2018 included in earnings for SJI for the year ended December 31, 2018 that are attributable to the change in unrealized gains relating to those assets and liabilities included in Level 3 still held as of December 31, 2018, are $14.4 million. These gains are included in Operating Revenues-Nonutility on the consolidated statements of income.
18. ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL):
The following table summarizes the changes in SJI's AOCL for the year ended December 31, 2018 (in thousands):
| Year Ended December 31, 2015 | ||||
| Balance at January 1, 2015 | $ | — | ||
| Other Changes in Fair Value from Continuing and New Contracts, Net | 183 | |||
| Settlements | — | |||
| Balance at December 31, 2015 | $ | 183 | ||
| Postretirement Liability Adjustment (A) | Unrealized Gain (Loss) on Derivatives-Other (A) | Unrealized Gain (Loss) on Available-for-Sale Securities (A) | Other Comprehensive Income (Loss) of Affiliated Companies (A) | Total | |||||||||||||||
| Balance at January 1, 2018 | $ | (36,262 | ) | $ | (396 | ) | $ | (10 | ) | $ | (97 | ) | $ | (36,765 | ) | ||||
| Other comprehensive income before reclassifications | 10,636 | — | — | — | 10,636 | ||||||||||||||
| Amounts reclassified from AOCL (B) | — | 34 | — | — | 34 | ||||||||||||||
| Net current period other comprehensive income | 10,636 | 34 | — | — | 10,670 | ||||||||||||||
| Balance at December 31, 2018 | $ | (25,626 | ) | $ | (362 | ) | $ | (10 | ) | $ | (97 | ) | $ | (26,095 | ) | ||||
| Notional Amount | Fixed Interest Rate | Start Date | Maturity | Type of Debt | Obligor | ||||||||
| $ | 12,500,000 | 3.53 | % | 12/1/2006 | 2/1/2036 | Tax-exempt | SJG | ||||||
| $ | 12,500,000 | 3.43 | % | 12/1/2006 | 2/1/2036 | Tax-exempt | SJG | ||||||
| Derivatives not designated as hedging instruments under GAAP | 2016 | 2015 | ||||||||||||||
| Assets | Liabilities | Assets | Liabilities | |||||||||||||
| Energy related commodity contracts: | ||||||||||||||||
| Derivatives – Energy Related – Current | $ | 5,434 | $ | 1,372 | $ | 1,077 | $ | 5,489 | ||||||||
| Derivatives – Energy Related – Non-Current | 373 | — | 64 | 351 | ||||||||||||
| Interest rate contracts: | ||||||||||||||||
| Derivatives – Other Current | 386 | — | ||||||||||||||
| Derivatives – Other Noncurrent | — | 6,979 | — | 7,631 | ||||||||||||
| Total derivatives not designated as hedging instruments under GAAP | $ | 5,807 | $ | 8,737 | $ | 1,141 | $ | 13,471 | ||||||||
| Amounts Reclassified from AOCL | Affected Line Item in the Statements of Consolidated Income | ||||||
| For the Year Ended December 31, 2018 | |||||||
| Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges | $ | 46 | Interest Charges | ||||
| Income Taxes | (12 | ) | Income Taxes (a) | ||||
| $ | 34 | ||||||
The following table summarizes the changes in SJG's AOCL for the year ended December 31, 2016, and 2015, information related to these offsetting arrangements were as follows2018 (in thousands):
| As of December 31, 2016 | ||||||||||||||||||||||||
| Description | Gross amounts of recognized assets/liabilities | Gross amount offset in the balance sheet | Net amounts of assets/liabilities in balance sheet | Gross amounts not offset in the balance sheet | Net amount | |||||||||||||||||||
| Financial Instruments | Cash Collateral Posted | |||||||||||||||||||||||
| Derivatives - Energy Related Assets | $ | 5,807 | $ | — | $ | 5,807 | $ | (6 | ) | (A) | $ | (3,587 | ) | $ | 2,214 | |||||||||
| Derivatives - Energy Related Liabilities | $ | (1,372 | ) | $ | — | $ | (1,372 | ) | $ | 6 | (B) | $ | — | $ | (1,366 | ) | ||||||||
| Derivatives - Other | $ | (7,365 | ) | $ | — | $ | (7,365 | ) | $ | — | $ | — | $ | (7,365 | ) | |||||||||
| Postretirement Liability Adjustment (A) | Unrealized Gain (Loss) on Derivatives-Other (A) | Total | |||||||||
| Balance at January 1, 2018 | (25,507 | ) | (490 | ) | $ | (25,997 | ) | ||||
Other comprehensive loss before reclassifications | 3,606 | — | 3,606 | ||||||||
| Amounts reclassified from AOCL (B) | — | 34 | 34 | ||||||||
| Net current period other comprehensive loss | 3,606 | 34 | 3,640 | ||||||||
| Balance at December 31, 2018 | $ | (21,901 | ) | $ | (456 | ) | $ | (22,357 | ) | ||
(A) Determined using a combined average statutory tax rate of 25% for 2018.
(B) See table below.
The following table provides details about reclassifications out of SJG's AOCL for the year ended December 31, 2018 (in thousands):
| Components of AOCL | Amounts Reclassified from AOCL | Affected Line Item in the Statements of Income | |||
| For the Year Ended December 31, 2018 | |||||
| Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges | $ | 46 | Interest Charges | ||
| Income Taxes | (12 | ) | Income Taxes (a) | ||
| $ | 34 | ||||
(a) Determined using a combined average statutory tax rate of 25%.
19. REVENUES:
At contract inception, SJI and SJG assess the goods and services promised in all of its contracts with customers, and identifies a performance obligation for each promise to transfer to a customer a distinct good or service.
As applicable for each revenue stream and customer contract type, SJI and SJG follow two approaches:
SJI and SJG have elected the Practical Expedient in ASC 606 for recognizing revenue on contracts with customers on a portfolio of performance obligations with similar characteristics, as we reasonably expect the effects of applying the guidance to the portfolio would not differ materially from applying it to individual contracts.
SJI and SJG apply the accounting guidance for recognizing revenue on contracts with customers on a series of distinct goods and services as one performance obligation, as long as the distinct goods and services are part of a series that are substantially the same and satisfied over time, and the same method would be used to measure progress towards satisfaction of the performance obligation. All performance obligations noted below under "Revenue Recognized Over Time" apply this guidance.
Below is a listing of all performance obligations that arise from contracts with customers, along with details on the satisfaction of each performance obligation, the significant payment terms, and the nature of the goods and services being transferred:
| Revenue Recognized Over Time: | ||
| Reportable Segment | Performance Obligation | Description |
SJG Utility Operations; ETG Gas Utility Operations; ELK Gas Utility Operations; Wholesale Energy Operations; Retail Gas and Other Operations | Natural Gas | SJG, ETG and ELK sell natural gas to residential, commercial and industrial customers, and price is based on regulated tariff rates which are established by the BPU or the MPSC, as applicable. There is an implied contract with a customer for the purchase, delivery, and sale of gas, and the customer is billed monthly, with payment due within 30 days. SJRG sells natural gas to commercial customers at either a fixed quantity or at variable quantities based on a customer's needs. Payment is due on the 25th of each month for the previous month's deliveries. SJE previously sold natural gas to commercial, industrial and residential customers at fixed prices throughout the life of the contract, with the customer billed monthly and payment due within 30 days (SJE sold its Retail Gas Operations in November 2018; see Note 1). For all listed segments, revenue is currently being recognized over time based upon volumes delivered (i.e., unit of output) or through the passage of time ratablyas the customer uses natural gas, which represents satisfaction of the performance obligation. |
| SJG Utility Operations; Wholesale Energy Operations | Pipeline transportation capacity | SJG and SJRG sell pipeline transportation capacity on a wholesale basis to various customers on the interstate pipeline system and transport natural gas purchased directly from producers or suppliers to their customers. These contracts to sell this capacity are at a price, quantity and time period agreed to by both parties determined on a contract by contract basis. Payment is due on the 25th of each month for the previous month's deliveries. Revenue is currently being recognized over time based upon volumes delivered (i.e., unit of output) or through the passage of time ratably coinciding with the delivery of gas and the customer obtaining control, which represents satisfaction of the performance obligation. |
| Wholesale Energy Operations | Fuel Management Services | SJRG currently has eleven fuel supply management contracts where SJRG has acquired pipeline transportation capacity that allows SJRG to match end users, many of which are merchant generators, with producers looking to find a long-term solution for their supply. Natural gas is sold to the merchant generator daily based on its needs, with payment made either weekly or biweekly depending on the contract. Revenue is currently being recognized over time based upon volumes delivered (i.e., unit of output) coinciding with the delivery of gas and the customer obtaining control, which represents satisfaction of the performance obligation. |
| Retail Electric Operations | Electricity | SJE sells electricity to commercial, industrial and residential customers at fixed prices throughout the life of the contract, with the customer billed monthly and payment due within 30 days. Revenue is currently being recognized over time based upon volumes delivered (i.e., unit of output) or through the passage of time ratably coinciding with the delivery of electricity and the customer obtaining control, which represents satisfaction of the performance obligation. |
| On-Site Energy Production | Solar | Marina has several wholly-owned solar projects that earn revenue based on electricity generated. The customer pays monthly as electricity is being generated, with payment due within 30 days. The performance obligation is satisfied as kwh's of energy are generated (i.e., unit of output), which is when revenue is recognized. As disclosed in Note 1, the majority of Marina's solar assets were sold as of December 31, 2018. |
| On-Site Energy Production | Marina Thermal Facility | Marina has a contract with a casino and resort in Atlantic City, NJ to provide cooling, heating and emergency power. There are multiple performance obligations with this contract, including electric, chilled water and hot water, and each of these are considered distinct and separately identifiable, and they are all priced separately. These performance obligations are satisfied over time ratably as they are used by the customer, who is billed monthly. Payment is due within 30 days. |
Table of Contents
| As of December 31, 2015 | ||||||||||||||||||||||||
| Description | Gross amounts of recognized assets/liabilities | Gross amount offset in the balance sheet | Net amounts of assets/liabilities in balance sheet | Gross amounts not offset in the balance sheet | Net amount | |||||||||||||||||||
| Financial Instruments | Cash Collateral Posted | |||||||||||||||||||||||
| Derivatives - Energy Related Assets | $ | 1,141 | $ | — | $ | 1,141 | $ | (399 | ) | (A) | $ | — | $ | 742 | ||||||||||
| Derivatives - Energy Related Liabilities | $ | (5,840 | ) | $ | — | $ | (5,840 | ) | $ | 399 | (B) | $ | 5,025 | $ | (416 | ) | ||||||||
| Derivatives - Other | $ | (7,631 | ) | $ | — | $ | (7,631 | ) | $ | — | $ | — | $ | (7,631 | ) | |||||||||
| Revenue Recognized at a Point in Time: | ||
| Reportable Segment | Performance Obligation | Description |
| On-Site Energy Production | SREC's | The customer is billed based on a contracted amount of SREC's to be sold, with the price based on the market price of the SRECs at the time of generation. This does not represent variable consideration as the price is known and established at the time of generation and delivery to the customer. The performance obligation is satisfied at the point in time the SREC is delivered to the customer, which is when revenue is recognized. Payment terms are approximately 10 days subsequent to delivery. As disclosed in Note 1, SJI has entered into an agreement to sell SREC's generated to a third party; as a result, no revenue with customers from SREC agreements was recorded since this agreement was signed. |
SJI and SJG have determined that the above methods provide a faithful depiction of the transfer of goods or services to the customer. For all above performance obligations, SJI's and SJG's efforts are expended throughout the contract based on seasonality and customer needs. Further, for various contracts among each performance obligation, SJI and SJG may have a stand ready obligation to provide goods or services on an as needed basis to the customer.
Because the Invoiced Practical Expedient is used for recognizing revenue, SJI and SJG further adopted the Practical Expedient in ASC 606 that allows both company's to not disclose additional information regarding remaining performance obligations.
SJI revenues from contracts with customers totaled $1.51 billion for the year ended December 31, 20162018, respectively. SJG revenues from contracts with customers totaled $475.5 million for the year ended December 31, 2018, respectively. The SJG balance is a part of the SJG utility operations segment, and 2015is before intercompany eliminations with other SJI entities. Revenues on the consolidated statements of income that are not with contracts with customers consist of (a) revenues from alternative revenue programs at the SJG, ETG and ELK utility operating segments (including CIP, AIRP, SHARP and WNC), and (b) both utility and nonutility revenue from derivative contracts at the SJG and ETG gas utility, wholesale energy, retail gas and retail electric operating segments.
SJI and SJG disaggregate revenue from contracts with customers into customer type and product line. SJI and SJG have determined that disaggregating revenue into these categories achieves the disclosure objective in ASC 606 to depict how the nature, timing and uncertainty of revenue and cash flows are affected by economic factors. Further, disaggregating revenue into these categories is consistent with information regularly reviewed by the CODM in evaluating the financial performance of SJI's operating segments. SJG only operates in the SJG Utility Operations segment. See Note 6 for further information regarding SJI's operating segments.
Disaggregated revenues from contracts with customers, by both customer type and product line, are disclosed below, by operating segment, for the year ended December 31, 2018 (in thousands):
| Year Ended December 31, 2018 | ||||||||||||||||||||||||||||||
| SJG Utility Operations | ETG Utility Operations | ELK Utility Operations | Wholesale Energy Operations | Retail Gas Operations | Retail Electric Operations | On-site Energy Production | Appliance Service Operations | Corporate Services and Intersegment | Total | |||||||||||||||||||||
| Customer Type: | ||||||||||||||||||||||||||||||
| Residential | $ | 329,207 | $ | 82,763 | $ | 1,482 | $ | 29,762 | — | $ | 1,957 | — | $ | 445,171 | ||||||||||||||||
| Commercial & Industrial | 132,055 | 42,935 | 1,815 | 652,833 | 75,651 | 94,483 | 72,374 | — | (24,392 | ) | 1,047,754 | |||||||||||||||||||
| OSS & Capacity Release | 11,536 | — | — | — | — | 11,536 | ||||||||||||||||||||||||
| Other | 2,699 | 2,949 | 65 | — | — | — | 5,713 | |||||||||||||||||||||||
| $ | 475,497 | $ | 128,647 | $ | 3,362 | $ | 652,833 | $ | 75,651 | $ | 124,245 | $ | 72,374 | $ | 1,957 | $ | (24,392 | ) | $ | 1,510,174 | ||||||||||
| Product Line: | ||||||||||||||||||||||||||||||
| Gas | $ | 475,497 | $ | 128,647 | $ | 3,362 | $ | 652,833 | $ | 75,651 | — | $ | (10,181 | ) | $ | 1,325,809 | ||||||||||||||
| Electric | 124,245 | — | (7,904 | ) | 116,341 | |||||||||||||||||||||||||
| Solar | 35,444 | — | (6,307 | ) | 29,137 | |||||||||||||||||||||||||
| CHP | 30,473 | — | — | 30,473 | ||||||||||||||||||||||||||
| Landfills | 6,457 | — | — | 6,457 | ||||||||||||||||||||||||||
| Other | 1,957 | — | 1,957 | |||||||||||||||||||||||||||
| $ | 475,497 | $ | 128,647 | $ | 3,362 | $ | 652,833 | $ | 75,651 | $ | 124,245 | $ | 72,374 | $ | 1,957 | $ | (24,392 | ) | $ | 1,510,174 | ||||||||||
The following table provides information about SJI's and SJG's receivables and unbilled revenue from contracts with customers (in thousands):
| Accounts Receivable (1) | Unbilled Revenue (2) | |||
| SJI (including SJG and all other consolidated subsidiaries): | ||||
| Beginning balance as of 1/1/18 | 202,379 | 73,377 | ||
| Ending balance as of 12/31/2018 | 337,502 | 79,538 | ||
| Increase (Decrease) | 135,123 | 6,161 | ||
| SJG: | ||||
| Beginning balance as of 1/1/18 | 78,571 | 54,980 | ||
| Ending balance as of 12/31/2018 | 101,572 | 43,271 | ||
| Increase (Decrease) | 23,001 | (11,709 | ) | |
(1) Included in Accounts Receivable in the consolidated balance sheets. A receivable is SJI's and SJG's right to consideration that is unconditional, as only the passage of time is required before payment is expected from the customer. All of SJI's and SJG's Accounts Receivable arise from contracts with customers. The large increase in SJI's Accounts Receivable is due to the Acquisition.
(2) Included in Unbilled Revenues in the consolidated balance sheets. All unbilled revenue for SJI and SJG arises from contracts with customers. Unbilled revenue relates to SJI's and SJG's right to receive payment for commodity delivered but not yet billed. This represents contract assets that arise from contracts with customers, which is defined in ASC 606 as the right to payment in exchange for goods already transferred to a customer, excluding any amounts presented as a receivable. The unbilled revenue is transferred to accounts receivable when billing occurs and the rights to collection become unconditional. The change in unbilled revenues for the year ended December 31, 2018 is due primarily to the timing difference between SJI and SJG delivering the commodity to the customer and the customer actually receiving the bill for payment.
20. BUSINESS COMBINATION
On July 1, 2018, the Company completed the Acquisition of ETG and ELK. The Company completed the Acquisition for total consideration of $1.74 billion in cash, inclusive of $40.3 million of certain net working capital adjustments. Of the total, $1.73 billion relates to the acquisition of ETG, while $10.9 million relates to the acquisition of the ELK. In the second quarter of 2018, the Company completed public equity offerings and issued long-term debt to help fund the Acquisition (see Notes 6 and 14, respectively). The Acquisition supports the Company’s strategy of earnings growth derived from high-quality, regulated utilities. Further, the Acquisition expands the Company’s customer base in the natural gas industry, which drives efficiencies by providing a greater operating scale.
Preliminary purchase price allocations
The Acquisition was accounted for as a business combination using the acquisition method of accounting in accordance with GAAP, which includes GAAP for regulated operations. Under the acquisition method of accounting, the total estimated purchase price of an acquisition is allocated to the net assets based on their estimated fair values. ETG's and ELK's regulated natural gas distribution operations are subject to rate-setting authorities of the BPU and the MPSC, respectively, which includes provisions in place that provide revenues to recover costs of service, including a carrying charge on most net assets and liabilities. Given the regulatory environment under which ETG and ELK operate, the historical book value of the assets acquired and liabilities assumed approximate fair value.
The Company has not finalized its valuation of certain assets and liabilities in connection with the Acquisition. As such, the estimated measurements recorded to date are subject to change and these changes, if any, could be material. Any changes will be recorded as adjustments to the fair value of those assets and liabilities and residual amounts will be allocated to goodwill. The final valuation adjustments may also require adjustment to the consolidated statements of operations and cash flows. The final determination of these fair values will be completed as soon as possible but no later than one year from the Acquisition date.
The preliminary purchase price for the Acquisition has been allocated to the assets acquired and liabilities assumed as of the acquisition date and is as follows:
| (in thousands) | ETG and ELK | ||
| Property, Plant and Equipment | $ | 1,089,342 | |
| Accounts Receivable | 45,875 | ||
| Provision for Uncollectibles | (6,579 | ) | |
| Natural Gas in Storage | 12,204 | ||
| Materials and Supplies | 345 | ||
| Other Prepayments and Current Assets | 200 | ||
| Deferred Income Taxes | 21,024 | ||
| Regulatory Assets | 136,213 | ||
| Goodwill | 731,029 | ||
| Total assets acquired | 2,029,653 | ||
| Accounts Payable | 13,089 | ||
| Other Current Liabilities | 9,185 | ||
| Environmental Remediation Costs - Current | 7,100 | ||
| Pension and Other Postretirement Benefits | 3,213 | ||
| Environmental Remediation Costs - Non Current | 66,165 | ||
| Regulatory Liabilities | 189,509 | ||
| Other | 1,107 | ||
| Total liabilities assumed | 289,368 | ||
| Total net assets acquired | $ | 1,740,285 | |
Goodwill of $731.0 million arising from the Acquisition includes the potential synergies between ETG, ELK and the Company. The goodwill, of which $677.6 million is expected to be deductible for income tax purposes, was assigned to the ETG and ELK Utility Operations segments.
Conditions of approval
The Acquisition was subject to regulatory approval from the BPU and the MPSC. Approvals were obtained from both commissions, subject to various conditions. As a requirement for approval of the acquisition of ETG, the BPU mandated that the Company pay $15.0 million to existing ETG customers in the form of a one-time credit. As a requirement for approval of the acquisition of ELK, the MPSC mandated that the Company pay $0.3 million to existing ELK customers in the form of a one-time payout. See Note 10. Other key conditions of approval related to derivative liabilitiesthe acquisition include but are not limited to ETG filing a base rate case no later than June 2020. Prior to its next base rate case, ETG will be required to maintain a capital structure that consists of no less than 46% common equity which can be net settled against derivative assets.excludes goodwill. In December 2018, the Company successfully completed a refinancing related to ETG's $530.0 million 364-day term loan credit agreement to a long term permanent financing plan which was in accordance with the BPU stipulation, see Note 14 for further detail.
Financial information of the acquirees
The amount of ETG and ELK revenues included in the Company's consolidated statement of income for the year ended December 31, 20162018 was $128.9 million. The amount of ETG and 2015 were related to derivative assets which can be net settled against derivative liabilities.
| Year ended December 31, | |||||||||||
| Derivatives in Cash Flow Hedging Relationships | 2016 | 2015 | 2014 | ||||||||
| Interest Rate Contracts: | |||||||||||
| Losses reclassified from accumulated OCI into income (a) | $ | (46 | ) | $ | (46 | ) | $ | (46 | ) | ||
The following tables summarizessupplemental unaudited pro forma information presents the combined results of SJI, ETG, and ELK as if the Acquisition occurred on January 1, 2017. This supplemental unaudited pro forma information has been prepared for comparative purposes and does not purport to be indicative of what would have occurred had the Acquisition occurred on January 1, 2017, nor is it indicative of any future results.
The pro forma results include adjustments for the financing impact of the Acquisition, along with the tax-related impacts. Other material non-recurring adjustments are reflected in the pro forma and described below:
| (In thousands, except per share data) | Year Ended December 31 | |||||||
| 2018 | 2017 | |||||||
| Revenues | $ | 1,829,823 | $ | 1,555,124 | ||||
| Net (loss) income | $ | 74,770 | $ | (9,824 | ) | |||
| Earnings (loss) per share | $ | 0.89 | $ | (0.11 | ) | |||
The supplemental unaudited pro forma net income for the year ended December 31, 2018 was adjusted to exclude $34.1 million of acquisition-related costs, which includes one-time regulatory approval costs, but excludes financing adjustments and recurring charges.
The supplemental unaudited pro forma net income for the year ended December 31, 2017 was adjusted to include $34.1 million of acquisition-related costs, which excludes financing adjustments and recurring charges.
21. GOODWILL AND IDENTIFIABLE INTANGIBLE ASSETS:
GOODWILL - Goodwill represents future economic benefits arising from other assets acquired in a business combination that are not individually identified and separately recognized. Goodwill is initially measured at cost, being the excess of the aggregate of the consideration paid or transferred over the fair value of identifiable net assets acquired. Goodwill is not amortized, but instead is subject to impairment testing on an annual basis, and between annual tests whenever events or changes in accumulatedcircumstances indicate that the fair value of a reporting unit may be below its carrying amount.
The Company performs its annual goodwill impairment test in the fourth quarter of each fiscal year beginning with a qualitative assessment at the reporting unit level. The reporting unit level is identified by assessing whether the components of our operating segments constitute businesses for which discrete financial information is available, whether segment management regularly reviews the operating results of those components and whether the economic and regulatory characteristics are similar. Factors utilized in the qualitative analysis performed on goodwill in our reporting units include, among other comprehensive loss (AOCL)things, macroeconomic conditions, industry and market considerations, cost factors, overall financial performance, company specific operating results and other relevant entity-specific events affecting individual reporting units.
In the absence of sufficient qualitative factors, goodwill impairment is determined using a two-step process. Step one identifies potential impairment by comparing the fair value of a reporting unit to the book value, including goodwill. The Company estimates the fair value of a reporting unit using a discounted cash flow analysis. Management also considers other methods, which includes a market multiples analysis. Determining the fair value of a reporting unit requires judgment and the use of significant estimates and assumptions. Such estimates and assumptions include, but are not limited to, forecasts of future operating results, discount and growth rates, capital expenditures, tax rates, and projected terminal values. Changes in estimates or the application of alternative assumptions could produce significantly different results. If the fair value exceeds book value, goodwill of the reporting unit is not considered impaired. If the book value exceeds fair value, proceed to step two, which compares the implied fair value of the reporting unit's goodwill to the book value of the reporting unit goodwill. If the book value of goodwill exceeds the implied fair value, an impairment charge is recognized for the excess.
Total goodwill of $734.6 million and $3.6 million is recorded on the consolidated balance sheets as of December 31, 2018 and 2017, respectively. The increase was due to consideration transferred in excess of the fair value of the identifiable net assets acquired as a result of the Acquisition (see Note 20). Of the total $734.6 million balance as of December 31, 2018, $730.9 million is included in the ETG Utility Operations segment, $3.6 million is included in the On-Site Energy Production segment, and $0.1 million is included in the ELK Utility Operations segment. The $3.6 million balance as of December 31, 2017 was included in the On-Site Energy Production segment. SJG does not have any goodwill.
The Company performed its 2018 annual goodwill impairment assessment and concluded that the fair value of all reporting units containing goodwill exceeded their respective carrying values.
In connection with the 2017 annual goodwill impairment assessment, the Company performed a qualitative assessment over its business units and noted that as a result of the continuing cash flow losses incurred at the LFGTE's business unit, the two-step impairment test was necessary during 2017. Based on the results of the goodwill impairment test, the Company determined that the carrying value of the LFGTE's reporting unit was higher than the fair value, and accordingly, the Company recognized a pre-tax impairment charge of $1.3 million during the year ended December 31, 2017, recorded in Impairment Charges on the consolidated statements of income and included in the Company's On-Site Energy Production segment.
The Company concluded based on the results of the annual testing performed that, other than the impairment charges noted above, there were no other impairments identified for the years ended December 31, 20162018 and 2015,2017.
The following table summarizes the changes in goodwill for the years ended December 31, 2018 and 2017, respectively (in thousands):
| Postretirement Liability Adjustment | Unrealized Gain (Loss) on Derivatives-Other | Unrealized Gain (Loss) on Available-for-Sale Securities | Total | ||||||||||||
| Balance at January 1, 2016 (a) | $ | (12,220 | ) | $ | (544 | ) | $ | (98 | ) | $ | (12,862 | ) | |||
Other comprehensive income before reclassifications | (3,687 | ) | — | 323 | (3,364 | ) | |||||||||
| Amounts reclassified from AOCL (b) | 1,490 | 27 | (225 | ) | 1,292 | ||||||||||
| Net current period other comprehensive income | (2,197 | ) | 27 | 98 | (2,072 | ) | |||||||||
| Balance at December 31, 2016 (a) | $ | (14,417 | ) | $ | (517 | ) | $ | — | $ | (14,934 | ) | ||||
| 2018 | 2017 | |||||
| Beginning Balance, January 1 | $ | 3,578 | $ | 4,838 | ||
| Impairment of Goodwill | — | (1,260 | ) | |||
| Goodwill from Acquisition | 756,247 | — | ||||
| Fair Value Adjustments During Measurement Period | (25,218 | ) | — | |||
| Ending Balance, December 31 | $ | 734,607 | $ | 3,578 | ||
| Postretirement Liability Adjustment | Unrealized Gain (Loss) on Derivatives-Other | Unrealized Gain (Loss) on Available-for-Sale Securities | Total | ||||||||||||
| Balance at January 1, 2015 (a) | $ | (13,837 | ) | $ | (567 | ) | $ | (75 | ) | $ | (14,479 | ) | |||
Other comprehensive income before reclassifications | (110 | ) | — | (76 | ) | (186 | ) | ||||||||
| Amounts reclassified from AOCL (b) | 1,727 | 23 | 53 | 1,803 | |||||||||||
| Net current period other comprehensive income | 1,617 | 23 | (23 | ) | 1,617 | ||||||||||
| Balance at December 31, 2015 (a) | $ | (12,220 | ) | $ | (544 | ) | $ | (98 | ) | $ | (12,862 | ) | |||
straight-line basis, over their useful lives, generally ranging from 2 to 20 years.
The reclassifications outcost of AOCL foridentifiable intangible assets of $28.1 million and $12.5 million are included in Other Noncurrent Assets on the years endedconsolidated balance sheets as of December 31, 20162018 and 20152017, respectively. The increase is as follows (in thousands):
| Components of AOCL | Amounts Reclassified from AOCL | Affected Line Item in the Statements of Income | ||||||||
| For the Year Ended December 31, 2016 | For the Year Ended December 31, 2015 | |||||||||
| Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges | $ | 46 | $ | 46 | Interest Charges | |||||
| Income Taxes | (19 | ) | (23 | ) | Income Taxes (a) | |||||
| $ | 27 | $ | 23 | |||||||
| Unrealized Loss(Gain) on Available-for-Sale Securities | (377 | ) | 90 | Other Income & Expense | ||||||
| Income Taxes | 152 | (37 | ) | Income Taxes (a) | ||||||
| $ | (225 | ) | $ | 53 | ||||||
| Actuarial Loss on Postretirement Benefits | 2,490 | 2,891 | Operating Expenses: Operations | |||||||
| Income Taxes | (1,000 | ) | (1,164 | ) | Income Taxes (a) | |||||
| $ | 1,490 | $ | 1,727 | |||||||
Losses from reclassifications for the period net of tax | $ | 1,292 | $ | 1,803 | ||||||
| 2016 Quarter Ended | 2015 Quarter Ended | ||||||||||||||||||||||||||||||
| March 31 | June 30 | Sept. 30 | Dec. 31 | March 31 | June 30 | Sept. 30 | Dec. 31 | ||||||||||||||||||||||||
| Operating Revenues | $ | 187,766 | $ | 68,762 | $ | 62,025 | $ | 142,502 | $ | 267,658 | $ | 75,812 | $ | 58,634 | $ | 132,186 | |||||||||||||||
| Expenses: | |||||||||||||||||||||||||||||||
| Cost of Sales (excluding depreciation) | 69,303 | 19,997 | 26,395 | 58,695 | 146,102 | 25,419 | 22,934 | 50,835 | |||||||||||||||||||||||
| Operations and Maintenance | |||||||||||||||||||||||||||||||
| Including Fixed Charges | 46,450 | 42,826 | 41,303 | 47,886 | 52,137 | 42,691 | 42,204 | 48,258 | |||||||||||||||||||||||
| Income Taxes | 27,404 | 1,415 | (2,007 | ) | 12,554 | 26,172 | 3,292 | (2,871 | ) | 10,352 | |||||||||||||||||||||
| Energy and Other Taxes | 1,027 | 560 | 838 | 1,195 | 1,420 | 854 | 806 | 951 | |||||||||||||||||||||||
| Total Expenses | 144,184 | 64,798 | 66,529 | 120,330 | 225,831 | 72,256 | 63,073 | 110,396 | |||||||||||||||||||||||
| Other Income and Expense | 836 | 1,079 | 1,189 | 727 | 760 | 1,670 | 1,010 | 404 | |||||||||||||||||||||||
| Net Income | $ | 44,418 | $ | 5,043 | $ | (3,315 | ) | $ | 22,899 | $ | 42,587 | $ | 5,226 | $ | (3,429 | ) | $ | 22,194 | |||||||||||||
| SUBSEQUENT EVENTS: |
On January 17, 2019, SJI provided Notice of bonds, notes or other securities that are secured by a lien on substantially allOptional Prepayment to the holders of its Floating Rate Senior Notes, Series 2018D, due June 20, 2019 of the operating properties and franchisesCompany’s intent to prepay a portion of SJG.
In JanuaryFebruary 2019, the Company entered into an extension of the agreement to sell solar assets (see Note 1). This extension is to sell the majority of the remaining solar projects that did not previously satisfy conditions precedent to closing.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Stockholders and the Board of Directors of South Jersey Industries, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of South Jersey Industries, Inc. and subsidiaries (the "Company") as of December 31, 2018 and 2017, SJG filed a base rate casethe related consolidated statements of income, comprehensive income, cash flows and changes in equity and comprehensive income for each of the three years in the period ended December 31, 2018, and the related notes and the schedules listed in the Index at Item 15(a)2 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2018 and 2017, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2018, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the BPUstandards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2018, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2019, expressed an unqualified opinion on the Company's internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to increase its base ratesexpress 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 orderaccordance 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 return on new capital investmentstest 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 SJGmanagement, 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
Philadelphia, Pennsylvania
February 27, 2019
We have served as the Company's auditor since 1948.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the settlementstockholder and the Board of Directors of South Jersey Gas Company
Opinion on the Financial Statements
We have audited the accompanying balance sheets of South Jersey Gas Company (the "Company") as of December 31, 2018 and 2017, the related statements of income, comprehensive income, cash flows and changes in common equity and comprehensive income for each of the three years in the period ended December 31, 2018, and the related notes and the schedule listed in the Index at Item 15(a)2 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2018 and 2017, and the results of its last base rate caseoperations and its cash flows for each of the three years in 2014. SJG expects the base rate caseperiod ended December 31, 2018, in conformity with accounting principles generally accepted in the United States of America.
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 Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be concluded during 2017.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. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
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
Philadelphia, Pennsylvania
February 27, 2019
We have served as the Company's auditor since 1948.
Quarterly Financial Data (Unaudited)
(Summarized quarterly results of SJI's and SJG's operations, in thousands except for per share amounts)
| 2018 Quarter Ended | 2017 Quarter Ended | |||||||||||||||||||||||||||||||
| SJI (includes SJG and all other consolidated subsidiaries): | March 31 | June 30 | Sept. 30 | Dec. 31 | March 31 | June 30 | Sept. 30 | Dec. 31 | ||||||||||||||||||||||||
| Operating Revenues | $ | 521,945 | $ | 227,330 | $ | 302,480 | $ | 589,583 | $ | 425,829 | $ | 244,374 | $ | 227,127 | $ | 345,738 | ||||||||||||||||
| Expenses: | ||||||||||||||||||||||||||||||||
| Cost of Sales - (Excluding depreciation) | 283,068 | 145,796 | 233,112 | 393,432 | 287,143 | 179,684 | 168,815 | 210,585 | ||||||||||||||||||||||||
| Operations, Impairment Charges, Net Gains on Sale of Assets, Depreciation and Maintenance Including Fixed Charges (See Note 1) | 92,540 | 208,384 | 131,899 | 133,121 | 84,496 | 77,504 | 121,439 | 152,091 | ||||||||||||||||||||||||
| Income Taxes | 36,415 | (31,972 | ) | (16,649 | ) | 12,767 | 21,870 | (5,544 | ) | (24,765 | ) | (16,498 | ) | |||||||||||||||||||
| Energy and Other Taxes | 2,439 | 1,243 | 2,595 | 3,260 | 2,071 | 1,551 | 1,517 | 1,348 | ||||||||||||||||||||||||
| Total Expenses | 414,462 | 323,451 | 350,957 | 542,580 | 395,580 | 253,195 | 267,006 | 347,526 | ||||||||||||||||||||||||
| Other Income and Expense (See Note 1) | 3,823 | 2,328 | 2,835 | (971 | ) | 7,498 | 1,209 | 2,331 | 5,797 | |||||||||||||||||||||||
| Income (Loss) from Continuing Operations | 111,306 | (93,793 | ) | (45,642 | ) | 46,032 | 37,747 | (7,612 | ) | (37,548 | ) | 4,009 | ||||||||||||||||||||
| Loss from Discontinued Operations - (Net of tax benefit) | (66 | ) | (26 | ) | (43 | ) | (105 | ) | (30 | ) | (47 | ) | (45 | ) | 36 | |||||||||||||||||
| Net Income (Loss) | $ | 111,240 | $ | (93,819 | ) | $ | (45,685 | ) | $ | 45,927 | $ | 37,717 | $ | (7,659 | ) | $ | (37,593 | ) | $ | 4,045 | ||||||||||||
| Basic Earnings Per Common Share: | ||||||||||||||||||||||||||||||||
| Continuing Operations | $ | 1.40 | $ | (1.12 | ) | $ | (0.53 | ) | $ | 0.54 | $ | 0.47 | $ | (0.10 | ) | $ | (0.47 | ) | $ | 0.05 | ||||||||||||
| Discontinued Operations | — | — | — | — | — | — | — | — | ||||||||||||||||||||||||
| Basic Earnings Per Common Share | $ | 1.40 | $ | (1.12 | ) | $ | (0.53 | ) | $ | 0.54 | $ | 0.47 | $ | (0.10 | ) | $ | (0.47 | ) | $ | 0.05 | ||||||||||||
| Average Shares of Common Stock Outstanding - Basic | 79,595 | 84,080 | 85,506 | 85,506 | 79,519 | 79,549 | 79,549 | 79,549 | ||||||||||||||||||||||||
| Diluted Earnings Per Common Share: | ||||||||||||||||||||||||||||||||
| Continuing Operations | $ | 1.40 | $ | (1.12 | ) | $ | (0.53 | ) | $ | 0.53 | $ | 0.47 | $ | (0.10 | ) | $ | (0.47 | ) | $ | 0.05 | ||||||||||||
| Discontinued Operations | — | — | — | — | — | — | — | — | ||||||||||||||||||||||||
| Diluted Earnings Per Common Share | $ | 1.40 | $ | (1.12 | ) | $ | (0.53 | ) | $ | 0.53 | $ | 0.47 | $ | (0.10 | ) | $ | (0.47 | ) | $ | 0.05 | ||||||||||||
| Average Shares of Common Stock Outstanding - Diluted | 79,724 | 84,080 | 85,506 | 86,389 | 79,641 | 79,549 | 79,549 | 79,705 | ||||||||||||||||||||||||
| 2018 Quarter Ended | 2017 Quarter Ended | |||||||||||||||||||||||||||||||
| SJG: | March 31 | June 30 | Sept. 30 | Dec. 31 | March 31 | June 30 | Sept. 30 | Dec. 31 | ||||||||||||||||||||||||
| Operating Revenues | $ | 234,459 | $ | 76,801 | $ | 56,371 | $ | 180,369 | $ | 196,814 | $ | 83,251 | $ | 66,755 | $ | 170,434 | ||||||||||||||||
| Expenses: | ||||||||||||||||||||||||||||||||
| Cost of Sales (excluding depreciation) | 89,808 | 19,379 | 16,079 | 84,383 | 72,424 | 33,644 | 29,499 | 68,865 | ||||||||||||||||||||||||
| Operations, Depreciation and Maintenance Including Fixed Charges (See Note 1) | 57,323 | 55,480 | 53,239 | 63,386 | 47,748 | 46,077 | 46,877 | 54,221 | ||||||||||||||||||||||||
| Income Taxes | 21,836 | 482 | (2,818 | ) | 6,913 | 29,911 | 1,431 | (3,688 | ) | 18,046 | ||||||||||||||||||||||
| Energy and Other Taxes | 1,255 | 498 | 988 | 1,505 | 1,295 | 872 | 865 | 697 | ||||||||||||||||||||||||
| Total Expenses | 170,222 | 75,839 | 67,488 | 156,187 | 151,378 | 82,024 | 73,553 | 141,829 | ||||||||||||||||||||||||
| Other Income and Expense (See Note 1) | 2,510 | 607 | 2,141 | (573 | ) | 1,042 | 1,039 | 1,027 | 979 | |||||||||||||||||||||||
| Net Income (Loss) | $ | 66,747 | $ | 1,569 | $ | (8,976 | ) | $ | 23,609 | $ | 46,478 | $ | 2,266 | $ | (5,771 | ) | $ | 29,584 | ||||||||||||||
The sum of the quarters for basic and diluted earnings per common share for 2018 does not equal the year's total due to the impact of the equity offering on the average shares of common stock outstanding (see Note 6). The sum of the quarters for basic and diluted earnings per common share for 2017 may not equal the year's total due to rounding.
| NOTE: | Because of the seasonal nature of the business and the volatility from energy-related derivatives, statements for the 3-month periods are not indicative of the results for a full year. |
Item 9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure
None
Item 9A. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
The Company’s management of each of SJI and SJG, with the participation of its chieftheir respective principal executive officerofficers and chiefprincipal financial officer,officers, evaluated the effectiveness of the design and operation of the Company’sSJI''s and SJG's disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) as of December 31, 20162018. Based on that evaluation, the Company’s chiefprincipal executive officer and chiefprincipal financial officer of each of SJI and SJG concluded that the disclosure controls and procedures employed at the CompanySJI and SJG, respectively, are effective.
Changes in Internal Control over Financial Reporting
On July 1, 2018, SJI completed the acquisition of ETG and ELK. See Note 20 - Business Combinations in the Notes to the Consolidated Financial Statements for additional information. Under the guidelines established by the SEC, companies are permitted to exclude acquisitions from their assessment of internal control over financial reporting for a period of up to one year following an acquisition while integrating the acquired company. SJI is in the process of integrating ETG and ELK into its
internal control over financial reporting structure. As a result of these integration activities, certain controls will be evaluated and may be changed. The operations of ETG and ELK represented 36% of SJI's consolidated assets and 8% of SJI's consolidated revenues as of and for the year ended December 31, 2018. There hashave not been any changechanges in the Company'sSJI’s internal control over financial reporting as defined in Rule 13a-15(f) under the Exchange Act, during the fiscal quarter ended December 31, 20162018, that has materially affected, or is reasonably likely to materially affect, the Company’sSJI’s internal control over financial reporting.
Item 9B. Other Information
On February 27, 2019, Marina and Buyer entered into an amendment to the purchase agreement (the “Amendment”). The Amendment extends the purchase and sale commitment period for the majority of the remaining solar projects that did not satisfy conditions precedent to closing prior to the original end date and adjusts the purchase prices for those projects to account for the extension of the commitment period..
A copy of the Amendment is filed as Exhibit (2)(b)(iii) to this Annual Report on Form 10-K and is incorporated by reference into this Item 9B. The foregoing summary of the Amendment is qualified in its entirety by reference to the text of such document filed herewith.
To the Stockholders and the Board of Directors of South Jersey Industries, Inc.
Opinion on Internal Control over Financial Reporting
We have audited the internal control over financial reporting of South Jersey Industries, Inc. and subsidiaries (the “Company”) as of December 31, 2018, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 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 schedules as of and for the year ended December 31, 2018, of the Company and our report dated February 27, 2019, expressed an unqualified opinion on those consolidated financial statements and financial statement schedules.
As described in Management's Report on Internal Controls over Financial Reporting, management excluded from its assessment the internal control over financial reporting the acquired Elizabethtown Gas Company and Elkton Gas Company businesses which were acquired on July 1, 2018 and whose financial statements constitute 36% of total assets, 8% of operating revenues of the consolidated financial statements amounts at and for the year ended December 31, 2018. Accordingly, our audit did not include the internal control over financial reporting at Elizabethtown Gas Company and Elkton Gas Company businesses.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Controls over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ Deloitte & Touche LLP
Philadelphia, Pennsylvania
February 27, 2019
165
South Jersey Industries, Inc.
Part III
PART III
Item 10. Directors, Executive Officers and Corporate Governance
Information concerning Directors may be found under the captions “Director Elections”, “Director Nominees”, “Directors and Management”, “Security Ownership”, "Meetings of the Board of Directors and its Committees", and “The Board of Directors” in our definitive proxy statement for our 2019 Annual Meeting of Shareholders (the “2019 Proxy Statement”), which will be filed with the Securities and Exchange Commission within 120 days after the close of our fiscal year. Information concerning the members of the Company's Audit Committee and the Company's Audit Committee Financial Expert is also incorporated by reference to the 2019 Proxy Statement under the captions "Meetings of the Board of Directors and its Committees," “Audit Committee,” and “Audit Committee Report.” Such information is incorporated herein by reference. Information required by this item relating to the executive officers of SJI is set forth in Item 4-A of this Report.
The Company has adopted a Code of Ethics for its Principal Executive, Financial and (b)Accounting Officers. It is available on SJI's website, www.sjindustries.com, by clicking “Investors” and then “Corporate Governance.” We will post any amendment to or waiver of Form 10-K.the Code to our website.
Item 11. Executive Compensation
Item 12. Security Ownership of Certain Beneficial Owners and Management
and Related Stockholder Matters
Item 13. Certain Relationships and Related Transactions,
and Director Independence
Item 14. Principal Accountant Fees and Services
166
South Jersey Industries, Inc.
Part IV
Item 15. Exhibits and Financial Statement ScheduleSchedules
| (a) | Listed below are all financial statements and schedules filed as part of this |
1 - The consolidated financial statements and notes to consolidated financial statements together with the reportreports thereon of Deloitte & Touche LLP, dated February 27, 20172019, are filefiled as part of this reportReport under Item 8 - Financial Statements and Supplementary Data.
2 - Supplementary Financial Information
Information regarding selected quarterly financial data can be found on page 161 of this Report.
Schedule I - Supplemental Schedules as of December 31, 2018 and 2017 and for the three years ended December 31, 2018, 2017, and 2016 (page 177).
Reports of Independent Registered Public Accounting Firm of Deloitte & Touche LLP (page 176).
Schedule II - Valuation and Qualifying Accounts. See page 81.Accounts (page 181).
All schedules, other than that listed above, are omitted because the information called for is included in the financial statements filed or because they are not applicable or are not required.
| (b) | List of Exhibits (Exhibit Number is in Accordance with the Exhibit Table in Item 601 of Regulation S-K). |
167
South Jersey Industries, Inc.
Part IV
| Exhibit Number | Description | Reference | ||
| Common Stock Underwriting Agreement, dated as of April 18, 2018, for SJI. | Incorporated by reference from Exhibit 1.1 of Form 8-K of SJI as filed April 23, 2018. | |||
| Equity Units Underwriting Agreement, dated as of April 18, 2018, for SJI. | Incorporated by reference from Exhibit 1.2 of Form 8-K of SJI as filed April 23, 2018. | |||
| Asset Purchase Agreement, dated as of October 15, 2017, by and between Pivotal Utility Holdings, Inc. and South Jersey Industries, Inc. | Incorporated by reference from Exhibit 2.1 of Form 8-K of SJI as filed October 16, 2017. | |||
| Asset Purchase Agreement, dated as of June 27, 2018, by and between Marina and GSRP Project Holdings I, LLC. | Incorporated by reference from Exhibit 2.1 of Form 8-K of SJI as filed July 3, 2018. | |||
| Solar Renewable Energy Certificate Purchase and Sale Agreement, dated as of June 27, 2018, by and between Marina and GSRP Project Holdings I, LLC. | Incorporated by reference from Exhibit 2.2 of Form 8-K of SJI as filed July 3, 2018. | |||
| Fifth Amendment Asset Purchase Agreement dated as of February 27, 2019 by and between Marina and GSRP Project Holdings I, LLC (filed herewith). | ||||
| Certificate of Incorporation of South Jersey Industries, Inc., dated November 10, 1969. | Incorporated by reference from Exhibit 3.1 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated April 21, 1983. | Incorporated by reference from Exhibit 3.2 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated April 19, 1984. | Incorporated by reference from Exhibit 3.3 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated April 23, 1987. | Incorporated by reference from Exhibit 3.4 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated October 7, 1996. | Incorporated by reference from Exhibit 3.6 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated May 5, 2005. | Incorporated by reference from Exhibit 3.7 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated April 28, 2009. | Incorporated by reference from Exhibit 3.8 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated June 2014. | Incorporated by reference from Exhibit 3.9 of Form 8-K of SJI as filed May 10, 2016. | |||
| Certificate of Amendment of the Certificate of Incorporation of SJI, dated February 27, 2015. | Incorporated by reference from Exhibit 3.10 of Form 8-K of SJI as filed May 10, 2016. | |||
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| Certificate of Incorporation of South Jersey Gas Company. | Incorporated by reference from Exhibit | |||
| Bylaws of South Jersey Industries, Inc. as amended and restated through April 21, 2017. | Incorporated by reference from Exhibit 3.2(ii) of Form 8-K of SJI as filed April 24, 2017. | |||
| Bylaws of South Jersey Gas Company as amended and restated through April | Incorporated by reference from Exhibit 3.2(ii) of Form 8-K of SJG as filed | |||
| Form of Stock Certificate for common stock. | Incorporated by reference from Exhibit 4.9 of Form 8-K of SJI as filed April 23, 2018. | |||
| Junior Subordinated Indenture, dated as of April 23, 2018, for SJI. | Incorporated by reference from Exhibit 4.1 of Form 8-K of SJI as filed April 23, 2018. | |||
| First Supplemental Indenture, dated as of April 23, 2018, for SJI. | Incorporated by reference from Exhibit 4.2 of Form 8-K of SJI as filed April 23, 2018. | |||
| Form of 2018 Series A 3.70% Remarketable Junior Subordinated Notes due 2031, dated as of April 23, 2018, for SJI. | Incorporated by reference from Exhibit 4.3 of Form 8-K of SJI as filed April 23, 2018. | |||
| Purchase Contract and Pledge Agreement, dated as of April 23, 2018, for SJI. | Incorporated by reference from Exhibit 4.4 of Form 8-K of SJI as filed April 23, 2018. | |||
| Form of Remarketing Agreement, dated as of April 23, 2018, for SJI. | Incorporated by reference from Exhibit 4.5 of Form 8-K of SJI as filed April 23, 2018. | |||
| Form of Corporate Units, dated as of April 23, 2018, for SJI. | Incorporated by reference from Exhibit 4.6 of Form 8-K of SJI as filed April 23, 2018. | |||
| Form of Treasury Units, dated as of April 23, 2018, for SJI. | Incorporated by reference from Exhibit 4.7 of Form 8-K of SJI as filed April 23, 2018. | |||
| Forward Sale Agreement, dated, April 18, 2018, for SJI. | Incorporated by reference from Exhibit 4.8 of Form 8-K of SJI as filed April 23, 2018. | |||
| First Mortgage Indenture, dated as of July 2, 2018, for ETG. | Incorporated by reference from Exhibit 4.1 of Form 8-K of SJI as filed December 26, 2018. | |||
| First Supplemental Indenture, dated as of December 20, 2018, for ETG. | Incorporated by reference from Exhibit 4.2 of Form 8-K of SJI as filed December 26, 2018. | |||
| Supplemental Indenture Amending and Restating First Mortgage Indenture, dated as of January 23, | Incorporated by reference from Exhibit 4.1 of Form 8-K of SJG dated January 30, 2017. | |||
| First Supplemental Indenture, dated as of January 23, | Incorporated by reference from Exhibit 4.2 of Form 8-K of SJG dated January 30, 2017. | |||
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| First Supplement to Indenture of Trust dated as of June 29, 2000. | Incorporated by reference from Exhibit 4.1 of Form 8-K of SJG dated July 12, 2001. | |||
| Second Supplement to Indenture of Trust dated as of July 5, 2000. | Incorporated by reference from Exhibit 4.2 of Form 8-K of SJG dated July 12, 2001. | |||
| Third Supplement to Indenture of Trust dated as of July 9, 2001. | Incorporated by reference from Exhibit 4.3 of Form 8-K of SJG dated July 12, 2001. | |||
| Fourth Supplement to Indenture of Trust dated as of February 26, 2010. | Incorporated by reference from Exhibit 4.1 of Form | |||
| Fifth Supplement, dated as of January 25, | Incorporated by reference from Exhibit 4.3 of Form 8-K of SJG dated January 30, 2017. | |||
| Exhibit Number | ||||
| Description | Reference | |||
| Deferred Payment Plan for Directors of South Jersey Industries, Inc., South Jersey Gas Company, Energy & Minerals, Inc., R&T Group, Inc. and South Jersey Energy Company as amended and restated October 21, 1994. | Incorporated by reference from Exhibit (10)(l) of Form 10-K | |||
| Schedule of Deferred Compensation Agreements. | Incorporated by reference from Exhibit (10)(l)(b) of Form 10-K | |||
| Form of Officer Change in Control Agreements, effective January 1, 2013, between certain officers and either South Jersey Industries, Inc. or its subsidiaries. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI as filed January 25, 2013. | |||
| Schedule of Officer | ||||
| Officer Severance Plan. | Incorporated by reference from Exhibit | |||
| Supplemental Executive Retirement Program, as amended and restated effective January 1, 2009 and Form of Agreement between certain SJI | Incorporated by reference from Exhibit (10)(f)(ii) of Form 10-K for 2009. | |||
| South Jersey Industries, Inc. 1997 Stock-Based Compensation Plan (As Amended and Restated Effective January 1, 2012). | Incorporated by reference from Exhibit 10.3 of Form 8-K of SJI as filed January 6, 2012. | |||
| Note Purchase Agreement dated as of March 1, 2010. | Incorporated by reference from Exhibit 10 of Form 8-K of SJG dated March 5, 2010. | |||
| Note Purchase Agreement dated as of December 30, 2010. | Incorporated by reference from Exhibit 10 of Form 8-K of SJG dated January 5, 2011. | |||
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| Commercial Paper Dealer Agreement, dated as of July 1, | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated July 1, 2011. | |||
| Commercial Paper Dealer Agreement, dated as of January 5, | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated January 9, 2012. | |||
| Letter of Credit Reimbursement Agreements dated as of March 15, 2012. | Incorporated by reference from Exhibit 10.1-10.3 of Form 8-K of SJI dated March 21, 2012. | |||
| Note Purchase Agreement dated as of April 2, 2012. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated April 3, 2012. | |||
| Note Purchase Agreement, dated as of June 28, 2012, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated June 29, 2012. | |||
| Note Purchase Agreement, dated as of September 20, | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated September 25, 2012. | |||
| Note Purchase Agreement, dated as of | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG | |||
| Note Purchase Agreement, dated as of | Incorporated by reference from Exhibit 10.1 of Form 8-K of | |||
| Term Loan Credit Agreement, dated as of | Incorporated by reference from Exhibit 10.1 of Form 8-K of | |||
| First Amendment to Letter of Credit Reimbursement Agreements dated as of March 10, 2016. | Incorporated by reference from Exhibit 10.1-10.3 of Form 8-K of SJI dated March 11, 2016. | |||
| 364-Day Revolving Credit Agreement, dated as of September 7, 2016, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated September 9, 2016. | |||
| Note Purchase Agreement, dated as of January 25, | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated January 30, 2017. | |||
| Term Loan Credit Agreement, dated as of January 26, | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated January 30, 2017. | |||
| Loan Agreement by and between New Jersey Economic Development Authority and SJG dated April 1, 2006. | Incorporated by reference from Exhibit 10 of Form 8-K of SJG as filed April 26, 2006. | |||
| Five-Year Revolving Credit Agreement, dated as of August 7, 2017, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated August 10, 2017. | |||
| Five-Year Revolving Credit Agreement, dated as of August 14, 2017, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated August 15, 2017. | |||
| Note Purchase Agreement, dated as of August 16, 2017, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated January 19, 2018. | |||
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| First Amendment to 364-Day Revolving Credit Agreement, dated as of | Incorporated by reference from Exhibit 10.1 of | |||
| Note Purchase Agreement, dated as of April 25, 2018, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated April 27, 2018. | |||
| Floating Rate Note Purchase Agreement, dated as of June 20, 2018, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated June 26, 2018. | |||
| Term Loan Credit Agreement, dated as of June 26, 2018, for ETG (Borrower) and SJI (Guarantor). | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated July 2, 2018. | |||
| Revolving Credit Agreement, dated as of June 26, 2018, for ETG and ELK (Borrowers) and SJI (Guarantor). | Incorporated by reference from Exhibit 10.2 of Form 8-K of SJI dated July 2, 2018. | |||
| Second Amendment to | Incorporated by reference from Exhibit 99.1 of Form 8-K of SJI dated July 10, 2018. | |||
| Second Amendment to the Note Purchase Agreement (dated as of June 26, 2014) for SJI, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.2 of Form 8-K of SJI dated July 10, 2018. | |||
| Second Amendment to the Note Purchase Agreement (dated as of August 16, 2017) for SJI, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.3 of Form 8-K of SJI dated July 10, 2018. | |||
| First Amendment to the Note Purchase Agreement (dated as of April 25, 2018) for SJI, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.4 of Form 8-K of SJI dated July 10, 2018. | |||
| First Amendment to the Note Purchase Agreement (dated as of March 1, 2010) for SJG, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.5 of Form 8-K of SJI dated July 10, 2018. | |||
| First Amendment to the Note Purchase Agreement (dated as of December 30, 2010) for SJG, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.6 of Form 8-K of SJI dated July 10, 2018. | |||
| First Amendment to the Note Purchase Agreement (dated as of April 2, 2012) for SJG, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.7 of Form 8-K of SJI dated July 10, 2018. | |||
| Second Amendment to the Note Purchase Agreement (dated as of September 20, 2012) for SJG, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.8 of Form 8-K of SJI dated July 10, 2018. | |||
| First Amendment to the Note Purchase Agreement (dated as of November 21, 2013) for SJG, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.9 of Form 8-K of SJI dated July 10, 2018. | |||
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| First Amendment to the Note Purchase Agreement (dated as of January 25, 2017) for SJG, dated as of July 3, 2018. | Incorporated by reference from Exhibit 99.10 of Form 8-K of SJI dated July 10, 2018. | ||||
| First Amendment to the Five-Year Revolving Credit Agreement (dated as of August 14, 2017) for SJG, dated as of June 14, 2018. | Incorporated by reference from Exhibit 99.11 of Form 8-K of SJI dated July 10, 2018. | ||||
| First Amendment to the Term Loan Credit Agreement (dated as of January 26, 2017) for SJG, dated as of June 15, 2018. | Incorporated by reference from Exhibit 99.12 of Form 8-K of SJI dated July 10, 2018. | ||||
| Third Amendment to the 364-Day Revolving Credit Agreement (dated as of September 6, 2016) for SJI, dated as of June 13, 2018. | Incorporated by reference from Exhibit 99.13 of Form 8-K of SJI dated July 10, 2018. | ||||
| Second Amendment to the Five-Year Revolving Credit Agreement (dated as of August 7, 2017) for SJI, dated as of June 14, 2018. | Incorporated by reference from Exhibit 99.14 of Form 8-K of SJI dated July 10, 2018. | ||||
| Second Amendment to the Term Loan Credit Agreement (dated as of October 28, 2015) for SJI, dated as of June 26, 2018. | Incorporated by reference from Exhibit 99.15 of Form 8-K of SJI dated July 10, 2018. | ||||
| Term Loan Credit Agreement, dated as of October 26, 2018, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated October 31, 2018. | ||||
| Bond Purchase Agreement, dated as of December 20, 2018, for ETG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated December 26, 2018. | ||||
| Equity Distribution and Purchase Agreement, dated as of December 31, 2015, by and among Energenic, Marina and DCO Energy, LLC. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated January 7, 2016. | ||||
| Equity Distribution and Purchase Agreement, dated as of December 31, 2015, by and among Energenic, DCO Energy, LLC and Marina. | Incorporated by reference from Exhibit 10.2 of Form 8-K of SJI dated January 7, 2016. | ||||
| Code of Ethics. | Incorporated by reference from Exhibit 14 of Form 10-K for 2007. | ||||
| SJI - Subsidiaries of the Registrant (filed herewith). | |||||
| SJI - Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith). | |||||
| SJG - Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith). | |||||
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| SJI - Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith). | ||||
| SJG - Certification of Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith). | ||||
| SJI - Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith). | ||||
| SJG - Certification of Principal Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith). | ||||
| SJI - Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith). | ||||
| SJG - Certification of Principal Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith). | ||||
| (101.INS) | eXtensible Business Reporting Language (XBRL) Instance Document (filed herewith). | |||
| (101.SCH) | XBRL Taxonomy Extension Schema (filed herewith). | |||
| (101.CAL) | XBRL Taxonomy Extension Calculation Linkbase (filed herewith). | |||
| (101.DEF) | XBRL Taxonomy Extension Definition Linkbase (filed herewith). | |||
| (101.LAB) | XBRL Taxonomy Extension Label Linkbase (filed herewith). | |||
| (101.PRE) | XBRL Taxonomy Extension Presentation Linkbase (filed herewith). | |||
* Constitutes a management contract or a compensatory plan or arrangement.
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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.
| SOUTH JERSEY INDUSTRIES, INC. | |||
| BY: | /s/ Cielo Hernandez | ||
| Cielo Hernandez | |||
| Senior Vice President & Chief Financial Officer | |||
| Date: | February 27, 2019 | ||
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 and in the capacities and on the dates indicated.
| Signature | Title | Date | |
| /s/ Walter M. Higgins, III | Director, Chairman of the Board | February 27, 2019 | |
| (Walter M. Higgins, III) | |||
| /s/ Michael J. Renna | Director, President & Chief Executive Officer | February 27, 2019 | |
| (Michael J. Renna) | (Principal Executive Officer) | ||
| /s/ Cielo Hernandez | Senior Vice President & Chief Financial Officer | February 27, 2019 | |
| (Cielo Hernandez) | (Principal Financial & Accounting Officer) | ||
| /s/ Sarah M. Barpoulis | Director | February 27, 2019 | |
| (Sarah M. Barpoulis) | |||
| /s/ Thomas A. Bracken | Director | February 27, 2019 | |
| (Thomas A. Bracken) | |||
| /s/ Keith S. Campbell | Director | February 27, 2019 | |
| (Keith S. Campbell) | |||
| /s/ Victor A. Fortkiewicz | Director | February 27, 2019 | |
| (Victor A. Fortkiewicz) | |||
| /s/ Sheila Hartnett-Devlin | Director | February 27, 2019 | |
| (Sheila Hartnett-Devlin) | |||
| /s/ Sunita Holzer | Director | February 27, 2019 | |
| (Sunita Holzer) | |||
| /s/ Joseph M. Rigby | Director | February 27, 2019 | |
| (Joseph M. Rigby) | |||
| /s/ Frank L. Sims | Director | February 27, 2019 | |
| (Frank L. Sims) | |||
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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.
| SOUTH JERSEY GAS COMPANY | |||
| BY: | /s/ | ||
| Treasurer - SJG | |||
| Date: | February 27, 2019 | ||
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 and in the capacities and on the dates indicated.
| Signature | Title | Date | ||
| /s/ David Robbins, Jr. | President | February 27, | ||
| (David Robbins, Jr.) | (Principal Executive Officer) | |||
| /s/ | February 27, | |||
| ( | (Principal Financial and Accounting Officer) | |||
| /s/ Walter M. Higgins III | Director, Chairman of the Board | February 27, | ||
| (Walter M. Higgins III) | ||||
| /s/ Thomas A. Bracken | Director | February 27, | ||
| (Thomas A. Bracken) | ||||
| /s/ Victor A. Fortkiewicz | Director | February 27, | ||
| (Victor A. Fortkiewicz) | ||||
| /s/ Sunita Holzer | Director | February 27, | ||
| (Sunita Holzer) | ||||
| /s/ Joseph M. Rigby | Director | February 27, | ||
| (Joseph M. Rigby) | ||||
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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Stockholders and the Board of Directors of
South Jersey Industries, Inc.
Folsom, New Jersey
Opinion on the Financial Statement Schedules
We have audited the consolidated financial statements of South Jersey Industries, Inc. and subsidiaries (the "Company") as of December 31, 2018 and 2017, and for each of the three years in the period ended December 31, 2018, and the Company's internal control over financial reporting as of December 31, 2018, and have issued our reports thereon dated February 27, 2019; such consolidated financial statements and reports are included in your 2018 Annual Report to Shareholders and are included in this Form 10-K. Our audits also included the financial statement schedules of the Company listed in the Index at Item 15(a) 2. These financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company’s financial statement schedules based on our audits. In our opinion, such financial statement schedules, when considered in relation to the financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.
/s/ Deloitte & Touche LLP
Philadelphia, Pennsylvania
February 27, 2019
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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF INCOME
(In Thousands)
| 2018 | 2017 | 2016 | ||||||||||
| Management Service Fee Revenues | $ | 42,934 | $ | 34,321 | $ | 25,463 | ||||||
| Operating Expenses: | ||||||||||||
| Operations | 67,869 | 43,513 | 22,194 | |||||||||
| Depreciation | 600 | 311 | 377 | |||||||||
| Energy and Other Taxes | 1,517 | 1,324 | 1,033 | |||||||||
| Total Operating Expenses | 69,986 | 45,148 | 23,604 | |||||||||
| Operating (Loss) Income | (27,052 | ) | (10,827 | ) | 1,859 | |||||||
| Other Income: | ||||||||||||
| Equity in Earnings (Losses) of Subsidiaries (See Note 1) | 65,327 | (2,793 | ) | 119,061 | ||||||||
| Other | 17,608 | 15,083 | 10,295 | |||||||||
| Total Other Income | 82,935 | 12,290 | 129,356 | |||||||||
| Interest Charges | 54,678 | 23,818 | 12,148 | |||||||||
| Income Taxes | (16,698 | ) | (18,951 | ) | 6 | |||||||
| Income (Loss) from Continuing Operations | 17,903 | (3,404 | ) | 119,061 | ||||||||
| Equity in Undistributed Earnings of Discontinued Operations | (240 | ) | (86 | ) | (251 | ) | ||||||
| Net Income (Loss) | $ | 17,663 | $ | (3,490 | ) | $ | 118,810 | |||||
SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(In Thousands)
| 2018 | 2017 | 2016 | ||||||||||
| Net Income (Loss) | $ | 17,663 | $ | (3,490 | ) | $ | 118,810 | |||||
| Other Comprehensive Income (Loss) - Net of Tax | ||||||||||||
| Postretirement Liability Adjustment (A) | 10,636 | (10,920 | ) | (3,197 | ) | |||||||
| Unrealized Gain on Available-for-Sale Securities (B) | — | — | 118 | |||||||||
| Unrealized Gain on Derivatives - Other (B) | 34 | 1,536 | 197 | |||||||||
| Total Other Comprehensive Income (Loss) - Net of Tax | 10,670 | (9,384 | ) | (2,882 | ) | |||||||
| Comprehensive Income (Loss) | $ | 28,333 | $ | (12,874 | ) | $ | 115,928 | |||||
(A) Determined using a combined average statutory tax rate of 25% in 2018; 27% for 2017; and 40% for 2016.
(B) Determined using a combined average statutory tax rate of 25% in 2018; 39% for 2017 and 40% for 2016.
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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF RETAINED EARNINGS
(In Thousands)
| 2018 | 2017 | 2016 | ||||||||||
| Retained Earnings - Beginning | $ | 420,351 | $ | 510,597 | $ | 474,167 | ||||||
| Net Income (Loss) | 17,663 | (3,490 | ) | 118,810 | ||||||||
| 438,014 | 507,107 | 592,977 | ||||||||||
| Dividends Declared - Common Stock | (94,756 | ) | (87,308 | ) | (82,380 | ) | ||||||
| Excess Tax Benefit on Restricted Stock | — | 552 | — | |||||||||
| Retained Earnings - Ending | $ | 343,258 | $ | 420,351 | $ | 510,597 | ||||||
SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF CASH FLOWS
FOR THE TWELVE MONTHS ENDED DECEMBER 31,
(In Thousands)
| 2018 | 2017 | 2016 | ||||||||||
| CASH (USED IN) PROVIDED BY OPERATING ACTIVITIES | $ | (6,447 | ) | $ | 17,339 | $ | 20,507 | |||||
| CASH FLOWS FROM INVESTING ACTIVITIES: | ||||||||||||
| Net Repayments from (Advances to) Associated Companies | 366,342 | (16,096 | ) | 32,300 | ||||||||
| Capital Expenditures | (24,155 | ) | (801 | ) | (345 | ) | ||||||
| Cash Paid for Acquisition | (1,740,291 | ) | — | — | ||||||||
| Proceeds from Sale of PPE | 51 | — | — | |||||||||
| Purchase of Company Owned Life Insurance | (1,298 | ) | (9,180 | ) | (2,398 | ) | ||||||
| Investment in Affiliate | — | (40,000 | ) | (65,000 | ) | |||||||
| Net Cash Used in Investing Activities | (1,399,351 | ) | (66,077 | ) | (35,443 | ) | ||||||
| CASH FLOWS FROM FINANCING ACTIVITIES: | ||||||||||||
| Proceeds from Issuance of Long Term Debt | 1,592,500 | 50,000 | — | |||||||||
| Principal Repayments of Long Term Debt | — | (16,000 | ) | — | ||||||||
| Payments for Issuance of Long Term Debt | (15,513 | ) | (12,174 | ) | (84 | ) | ||||||
| Net Borrowings from (Repayments of) Short-Term Credit Facilities | (217,400 | ) | 102,600 | (105,500 | ) | |||||||
| Dividends on Common Stock | (94,756 | ) | (87,308 | ) | (82,380 | ) | ||||||
| Net Settlement of Restricted Stock (See Note 1) | (776 | ) | (751 | ) | (387 | ) | ||||||
| Proceeds from Sale of Common Stock | 173,750 | — | 214,426 | |||||||||
| Payments for the Issuance of Common Stock | (7,149 | ) | — | — | ||||||||
| Net Cash Provided by Financing Activities | 1,430,656 | 36,367 | 26,075 | |||||||||
| Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash | 24,858 | (12,371 | ) | 11,139 | ||||||||
| Cash, Cash Equivalents and Restricted Cash at Beginning of Year | 476 | 12,847 | 1,708 | |||||||||
| Cash, Cash Equivalents and Restricted Cash at End of Year | $ | 25,334 | $ | 476 | $ | 12,847 | ||||||
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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED BALANCE SHEETS (In Thousands)
| 2018 | 2017 | |||||||
| Assets | ||||||||
| Property Plant and Equipment: | ||||||||
| Nonutility Property, Plant and Equipment, at cost | $ | 4,188 | $ | 3,318 | ||||
| Accumulated Depreciation | (2,488 | ) | (2,194 | ) | ||||
| Property, Plant and Equipment - Net | 1,700 | 1,124 | ||||||
| Investments: | ||||||||
| Investments in Subsidiaries | 2,458,680 | 1,209,308 | ||||||
| Available-for-Sale Securities | 41 | 36 | ||||||
| Total Investments | 2,458,721 | 1,209,344 | ||||||
| Current Assets: | ||||||||
| Cash and Cash Equivalents | 25,334 | 476 | ||||||
| Receivable from Associated Companies | 270,478 | 636,327 | ||||||
| Accounts Receivable | 38 | 52 | ||||||
| Other | 19,100 | 5,017 | ||||||
| Total Current Assets | 314,950 | 641,872 | ||||||
| Other Noncurrent Assets | 53,838 | 50,735 | ||||||
| Total Assets | $ | 2,829,209 | $ | 1,903,075 | ||||
| Capitalization and Liabilities | ||||||||
| Equity: | ||||||||
| Common Stock SJI | ||||||||
| Par Value $1.25 a share | ||||||||
| Authorized - 120,000,000 shares | ||||||||
| Outstanding Shares - 85,506,218 (2018) and 79,549,080 (2017) | $ | 106,883 | $ | 99,436 | ||||
| Premium on Common Stock | 843,268 | 709,658 | ||||||
| Treasury Stock (at par) | (292 | ) | (271 | ) | ||||
| Accumulated Other Comprehensive Loss | (26,095 | ) | (36,765 | ) | ||||
| Retained Earnings | 343,258 | 420,351 | ||||||
| Total Equity | 1,267,022 | 1,192,409 | ||||||
| Long-Term Debt | 708,360 | 364,946 | ||||||
| Current Liabilities: | ||||||||
| Notes Payable - Banks | 77,000 | 294,400 | ||||||
| Current Portion of Long-Term Debt | 715,000 | — | ||||||
| Payable to Associated Companies | 899 | 404 | ||||||
| Accounts Payable | 6,378 | 17,316 | ||||||
| Other Current Liabilities | 27,895 | 7,763 | ||||||
| Total Current Liabilities | 827,172 | 319,883 | ||||||
| Other Noncurrent Liabilities | 26,655 | 25,837 | ||||||
| Total Capitalization and Liabilities | $ | 2,829,209 | $ | 1,903,075 | ||||
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South Jersey Industries, Inc.
Part IV
Notes to Condensed Financial Statements
| 1. | BASIS OF PRESENTATION: |
Pursuant to rules and regulations of the SEC, the parent-company only condensed financial statements of SJI do not reflect all of the information and notes normally included with financial statements prepared in accordance with GAAP in the United States. Therefore, these condensed financial statements should be read in conjunction with the consolidated financial statements and related notes included under Item 8 in this Form 10-K.
Certain reclassifications have been made to SJI's prior period condensed statements of income to conform to the current period presentation. The non-service cost components of net periodic pension and postretirement benefit costs are now included as a reduction to Other Income and Expense, as opposed to being recorded as an Operations Expense, to conform with ASU 2017-07, which is described under "New Accounting Pronouncements" in Note 1 to the consolidated financial statements. This caused a reduction to both Operations Expense and Other Income on the condensed statement of income for the years ended December 31, 2017 and 2016.
Dividends received from subsidiaries were $20.0 million for 2017. Dividends were not received from subsidiaries in 2018 or 2016.
The following table provides a reconciliation between SJI's equity in earnings from its subsidiaries to total income from continuing operations (in thousands):
| Year Ended December 31, 2018 | Year Ended December 31, 2017 | Year Ended December 31, 2016 | ||||||||||
| Equity in Earnings (Losses) of Subsidiaries | $ | 65,327 | $ | (2,793 | ) | $ | 119,061 | |||||
| General & Administrative Costs, net of tax (A) | (29,727 | ) | (12,031 | ) | — | |||||||
| Interest Charges, net of tax (B) | (17,697 | ) | — | — | ||||||||
| Impact of Tax Adjustments (C) | — | 11,420 | — | |||||||||
| Income (Loss) From Continuing Operations | $ | 17,903 | $ | (3,404 | ) | $ | 119,061 | |||||
(A) Represents costs incurred on the agreement to acquire the assets of ETG and ELK, along with the implementation of the ERIP, and other general & administrative costs.
(B) Represents interest charges incurred, net of tax, primarily on debt that was issued in 2018 as part of the funding for the Acquisition.
(C) Represents one-time tax adjustments, most notably for Tax Reform.
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South Jersey Industries, Inc.
Part IV
SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
(In Thousands)
| Col. A | Col. B | Col. C | Col. D | Col. E | |||||||||||||||||||
| Additions | |||||||||||||||||||||||
| Classification | Balance at Beginning of Period | Charged to Costs and Expenses | Acquisition Adjustments (a) | Charged to Other Accounts - Describe (b) | Deductions - Describe (c) | Balance at End of Period | |||||||||||||||||
| Provision for Uncollectible | |||||||||||||||||||||||
| Accounts for the Year Ended | |||||||||||||||||||||||
| December 31, 2018 | $ | 13,988 | $ | 7,977 | 6,579 | $ | (466 | ) | $ | 9,236 | $ | 18,842 | |||||||||||
| Provision for Uncollectible | |||||||||||||||||||||||
| Accounts for the Year Ended | |||||||||||||||||||||||
| December 31, 2017 | $ | 12,744 | $ | 6,949 | — | $ | (394 | ) | $ | 5,311 | $ | 13,988 | |||||||||||
| Provision for Uncollectible | |||||||||||||||||||||||
| Accounts for the Year Ended | |||||||||||||||||||||||
| December 31, 2016 | $ | 10,252 | $ | 6,907 | — | $ | (47 | ) | $ | 4,368 | $ | 12,744 | |||||||||||
SOUTH JERSEY GAS COMPANY
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
(In Thousands)
| Col. A | Col. B | Col. C | Col. D | Col. E | Col. B | Col. C | Col. D | Col. E | ||||||||||||||||||||||||||||||
| Additions | Additions | |||||||||||||||||||||||||||||||||||||
| Classification | Balance at Beginning of Period | Charged to Costs and Expenses | Charged to Other Accounts - Describe (a) | Deductions - Describe (b) | Balance at End of Period | Balance at Beginning of Period | Charged to Costs and Expenses | Charged to Other Accounts - Describe (b) | Deductions - Describe (c) | Balance at End of Period | ||||||||||||||||||||||||||||
| Provision for Uncollectible | ||||||||||||||||||||||||||||||||||||||
| Accounts for the Year Ended | ||||||||||||||||||||||||||||||||||||||
| December 31, 2016 | $ | 9,778 | $ | 6,993 | $ | (47 | ) | $ | 4,154 | $ | 12,570 | |||||||||||||||||||||||||||
| December 31, 2018 | $ | 13,799 | $ | 7,997 | $ | (466 | ) | $ | 7,687 | $ | 13,643 | |||||||||||||||||||||||||||
| Provision for Uncollectible | ||||||||||||||||||||||||||||||||||||||
| Accounts for the Year Ended | ||||||||||||||||||||||||||||||||||||||
| December 31, 2015 | $ | 6,601 | $ | 14,689 | $ | (235 | ) | $ | 11,277 | $ | 9,778 | |||||||||||||||||||||||||||
| December 31, 2017 | $ | 12,570 | $ | 6,949 | $ | (394 | ) | $ | 5,326 | $ | 13,799 | |||||||||||||||||||||||||||
| Provision for Uncollectible | ||||||||||||||||||||||||||||||||||||||
| Accounts for the Year Ended | ||||||||||||||||||||||||||||||||||||||
| December 31, 2014 | $ | 4,553 | $ | 9,417 | $ | (102 | ) | $ | 7,267 | $ | 6,601 | |||||||||||||||||||||||||||
| December 31, 2016 | $ | 9,778 | $ | 6,993 | $ | (47 | ) | $ | 4,154 | $ | 12,570 | |||||||||||||||||||||||||||
(a) Additions related to the Acquisition. See Note 20.
(b) Recoveries of accounts previously written off and minor adjustments.