10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-K

x	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2016
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 1-6364

SOUTH JERSEY INDUSTRIES, INC.

(Exact name of registrant as specified in its charter)

New Jersey  (State of incorporation) 22-1901645  (IRS employer identification no.)

1 South Jersey Plaza, Folsom, New Jersey 08037	(609) 561-9000
(Address of principal executive offices, including zip code)	(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Common Stock - $1.25 par value per share  (Title of each class) New York Stock Exchange  (Name of exchange on which registered)

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act:  Yes x No o

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Act: Yes o No x

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the 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'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. o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  See the definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer     x	Accelerated filer  o
Non-accelerated filer        o (Do not check if a smaller reporting company)	Smaller reporting company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No x

The aggregate market value of voting stock held by non-affiliates of the registrant as of June 30, 2016 was $2,506,525,273. As of February 15, 2017, there were 79,516,553 shares of the registrant's common stock outstanding.

Documents Incorporated by Reference:

In Part III of Form 10-K:  Portions of the registrant's definitive proxy statement filed for the registrant's 2017 annual meeting of shareholders are incorporated by reference into Part III of this Form 10-K.

TABLE OF CONTENTS

		Page No.
Forward-Looking Statements		1
Units of Measurement		1
	PART I
Item 1.	Business	2
Item 1A.	Risk Factors	8
Item 1B.	Unresolved Staff Comments	11
Item 2.	Properties	12
Item 3.	Legal Proceedings	12
Item 4.	Mine Safety Disclosures	12
Item 4A.	Executive Officers of the Registrant	13
	PART II
Item 5.	Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	15
Item 6.	Selected Financial Data	17
Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations	20
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	50
Item 8.	Financial Statements and Supplementary Data	52
	Statements of Consolidated Income	52
	Statements of Consolidated Comprehensive Income	53
	Statements of Consolidated Cash Flows	54
	Consolidated Balance Sheets	56
	Consolidated Statements of Changes in Equity and Comprehensive Income	58
	Notes to Consolidated Financial Statements	60
	Note  1. Summary of Significant Accounting Policies	60
	Note  2. Stock-Based Compensation Plan	66
	Note 3. Affiliations and Discontinued Operations	69
	Note  4. Income Taxes	71
	Note  5. Preferred Stock	73
	Note  6. Common Stock	74
	Note  7. Financial Instruments	74
	Note  8. Segments of Business	76
	Note  9. Leases	80
	Note  10. Rates and Regulatory Actions	80
	Note  11. Regulatory Assets & Regulatory Liabilities	84
	Note  12. Pension and Other Postretirement Benefits	86
	Note  13. Lines of Credit	96
	Note  14. Long-Term Debt	98
	Note  15. Commitments and Contingencies	100
	Note  16. Derivative Instruments	102
	Note  17. Fair Value of Financial Instruments	105

	Note  18. Accumulated Other Comprehensive Loss	108
	Note  19. Subsequent Events	109
	Report of Independent Registered Public Accounting Firm	110
	Quarterly Financial Data (Unaudited)	111
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	112
Item 9A.	Controls and Procedures	112
Item 9B.	Other Information	112
	PART III
Item 10.	Directors, Executive Officers of the Registrant and Corporate Governance	114
Item 11.	Executive Compensation	114
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	114
Item 13.	Certain Relationships and Related Transactions, and Director Independence	114
Item 14.	Principal Accounting Fees and Services	114
	PART IV
Item 15.	Exhibits and Financial Statement Schedules	115
Signatures		121
Financial Statement Schedules		122

South Jersey Industries, Inc.

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 Industries (SJI or the Company) 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," “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, SJI 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

The Company's Internet address is www.sjindustries.com. We make available free of charge on or through our website SJI's Annual Report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and Exchange Commission (SEC). The SEC maintains an Internet site that contains these reports at http://www.sec.gov. Also, copies of SJI's annual report will be made available, free of charge, upon written request. The content on any web site referred to in this filing is not incorporated by reference into this Report unless expressly noted otherwise.

Units of Measurement
	For Natural Gas:
	1 Bcf	= One billion cubic feet
	1dt	= One decatherm
	1 MMdts	= One million decatherms
	dts/d	= Decatherms per day
	MDWQ	= Maximum daily withdrawal quantity
	For Electric:
	1 MMmwh	= One million megawatt hours
	1 mwh	= One megawatt hour

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South Jersey Industries, Inc.

Part I

PART I

Item 1. Business

Description of Business

The registrant, 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, a public utility, and acquiring and developing non-utility lines of business.

SJI currently provides a variety of energy-related products and services, primarily through the following wholly-owned subsidiaries:

• South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey.

• South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial, industrial and residential customers.

• South Jersey Resources Group, LLC (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.

• South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

• Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include:

• ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey.

• AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.

• MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey.

• South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

• SJI Midstream, LLC (Midstream) invests in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.

Additional Information on the nature of our business can be found in “Management's Discussion and Analysis of Financial Condition and Results of Operations,” under Item 7 of this Report.

Financial Information About Reportable Segments

Information regarding Reportable Segments is incorporated by reference to Note 8 of the consolidated financial statements included under Item 8 of this Report.

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South Jersey Industries, Inc.

Part I

Sources and Availability of Raw Materials

South Jersey Gas Company

Transportation and Storage Agreements

SJG has direct connections to the interstate pipeline systems of both Transcontinental Gas Pipe Line Company, LLC (Transco) and Columbia Gas Transmission, LLC (Columbia). During 2016, 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 SJG's 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. 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.

Transco:

Transco is SJG's largest supplier of long-term gas transmission services which includes both year-round and seasonal firm transportation (FT) service arrangements. When combined, these FT services enable SJG to purchase gas from third parties and have delivered to its city gate stations by Transco a total of 297,958 dts per day (dts/d). Of this total, 133,917 dts/d is long-haul FT (where gas can be transported from the production areas of the Southwest to the market areas of the Northeast) while 164,041 dts/d is market area FT. The terms of SJG's year-round agreements with Transco extend for various periods through 2025. Certain of these agreements are currently operating under their respective evergreen provisions.

Of the 297,958 dts/d of Transco services mentioned above, SJG has released a total of 10,000 dts/d of its long-haul and 20,000 dts/d of its market area FT service. These releases were made in association with SJG's Conservation Incentive Program (CIP) discussed further under Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations."  In addition, SJG released a total of 50,000 dts/d of its long-haul FT as part of Asset Management Agreements (AMA). The AMA-related releases are discussed below under “Gas Supplies.” In addition, SJG released a total of 27,500 dts/d of its market area FT as Off-System Sales capacity releases.

SJG currently has six long-term gas storage service agreements with Transco that, when combined, are capable of storing approximately 5.0 MMdts. Through these agreements, SJG can inject gas into market and production area storages during periods of low demand and extract gas at a Maximum Daily Withdrawal Quantity (MDWQ) of up to 107,407 dts during periods of high demand. The longest term of these storage service agreements extends through March 31, 2023.

Dominion:

SJG subscribes to a firm storage service from Dominion, under its Rate Schedule GSS.  This storage has an MDWQ of 10,000 dts during the period between November 16 and March 31 of each winter season, with an associated total storage capacity of 423,000 dts.  Gas withdrawn from Dominion GSS storage is delivered through both the Dominion and Transco (Leidy Line) pipeline systems for delivery to SJG service territory.  The primary term of this agreement extends through March 31, 2019.

Columbia:

SJG subscribes to four firm transportation agreements with Columbia which currently provide for an aggregate of 114,022 dts/d. The term of 9,000 dts/d of this capacity extends through October 31, 2022; the term of 45,022 dts/d extends through October 31, 2019; and the remaining 60,000 dts/d extends through October 31, 2030. SJG released 8,671 dts/d of the total amount to SJRG in conjunction with its CIP. In addition, SJG released a total of 20,000 dts/d of this capacity to two gas marketers at 10,000 dts/d each, one of which is SJRG, leaving a net total of 85,351 dts/d available to SJG. These AMA-related releases are further discussed below under “Gas Supplies.” Moreover, SJG released a total of 18,543 dts/d of its Columbia FT as Off-System Sales capacity releases.

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Part I

SJG also subscribes to a firm storage service with Columbia under its Rate Schedule FSS along with an associated firm transportation service under Rate Schedule SST, each of which extends through October 31, 2019. SJG has a total FSS MDWQ of 52,891 dts and a related 3,473,022 dts of storage capacity. SJG released to SJRG 19,029 dts/d of its FSS MDWQ along with 1,249,485 dts of its FSS storage capacity. Additionally, SJG released to SJRG 19,029 dts/d of its associated Columbia SST transportation service. Both releases made by SJG were in connection with its CIP and extend through September 30, 2018.

Gas Supplies

During 2016, SJG entered into an AMA with a gas marketer which extends through March 31, 2017. Under this agreement, SJG released to the marketer its firm transportation rights equal to 30,000 dts/d of transportation capacity on Transco. The marketer manages this capacity and provides SJG with up to 30,000 dts/d of firm deliverability each day through March 31, 2017. The marketer's intent was to optimize the capacity released to them under this AMA and pay SJG an asset management fee.

Also during 2016, SJG entered into an additional AMA with a separate gas marketer which extends through October 31, 2017. Under this agreement, SJG has released to the marketer firm transportation rights equal to 10,000 dts/d of transportation capacity on Transco. The marketer manages its capacity and provides SJG with up to 10,000 dts/d of firm deliverability everyday through October 31, 2017. The marketers will seek to optimize the capacity released to it under this AMA and pay SJG an asset management fee.

Also during 2016, SJG entered into two further AMA's with two separate gas marketers which both also extend through October 31, 2017. Under these agreements, SJG has released to each of the marketers firm transportation rights equal to 10,000 dts/d of transportation capacity on Columbia. The marketers manage their respective capacity and each provides SJG with up to 10,000 dts/d of firm deliverability everyday through either March 31 or October 31, 2017, depending on the particular agreement. The marketers will seek to optimize the capacity released to them under these AMA's and pay SJG an asset management fee.

In 2011, SJG entered into a long-term gas purchase agreement with a gas producer, the primary term of which extends through October 31, 2019. The maximum daily quantities (MDQ) available for purchase under this agreement initially start at 6,250 dts/d and ratchet up to an MDQ of 25,000 dts/d. Gas purchased from this producer will be sourced in the Appalachian supply areas and delivered into the Columbia pipeline system for delivery to SJG.

As part of its gas purchasing strategy, SJG uses financial contracts to hedge against forward price risk. These contracts are recoverable through SJG’s Basic Gas Supply Service Clause (BGSS), subject to the New Jersey Board of Public Utilities (BPU) approval.

Supplemental Gas Supplies

During 2016, SJG entered into a Liquefied Natural Gas (LNG) purchase agreement with a third party LNG supplier. This LNG was made available as a supply source to replenish SJG's LNG inventory at its storage facility, located in McKee City, NJ.

SJG operates peaking facilities which liquefies, stores and vaporizes LNG for injection into its distribution system. SJG'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.

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). Gas demand on such a design day for the 2016-2017 winter season is estimated to be 512,891 dts (excluding industrial customers). SJG projects that it has adequate supplies and interstate pipeline entitlements to meet its design day requirements. SJG experienced its highest peak-day demand for calendar year 2016 of 473,178 dts (including industrial customers) on February 13, while experiencing an average temperature of 20.6 degrees F that day.

Natural Gas Prices

SJG's average cost of 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.

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South Jersey Industries, Inc.

Part I

South Jersey Energy Company

Transportation and Storage Agreements - Natural Gas

Access to gas suppliers and cost of gas are significant to the operations of SJE. No material part of the business of SJE is dependent upon a single customer or a few customers. SJE purchases delivered gas only, primarily from SJRG. Consequently, SJE maintains no transportation or storage agreements.

Electric Supply

Due to the liquidity in the market, SJE primarily purchases delivered electric in the day-ahead and real-time markets through regional transmission organizations.

South Jersey Resources Group

Transportation and Storage Agreements

National Fuel Gas Supply Corporation:

SJRG has multiple storage service agreements with National Fuel Gas Supply Corporation (National Fuel). Two contracts totaling 2,581,420 dts of capacity have evergreen provisions that extend year to year.  One additional contract covering 224,576 dts of storage capacity extends through March 31, 2018, while a final contract covering 150,040 dts of capacity expires March 31, 2023.

SJRG holds long-term firm transportation agreements with National Fuel associated with the above-mentioned agreements. Under these agreements, National Fuel will provide SJRG with a maximum daily injection transportation quantity of 16,947 dts/d with primary receipt points from Tennessee Gas Pipeline for delivery into storage, and 25,661 dts/d of maximum daily withdrawal transportation quantity, with a primary receipt point of storage and a primary delivery point of the Transcontinental Gas Pipeline.

SJRG holds firm transportation agreements with National Fuel which expire between March 31, 2018 and November 30, 2023. Under these agreements, National Fuel provides various receipts and deliveries in Pennsylvania, which total 57,882 dts/d.   

Transcontinental Gas Pipeline (Transco):

SJRG has a storage agreement with Transco for storage service at Transco's WSS facility which expires in October 2017. Under this contract, up to 24,479 dts/d may be injected and up to 46,380 dts/d may be withdrawn. Total storage capacity under the agreement is 4,406,135 dts.

SJRG holds a firm transportation agreement with Transco which expires March 31, 2043. Under this agreement, Transco will provide SJRG with 10,000 dts/d of deliveries to New York and receipts at Leidy, PA.

Dominion Gas Transmission:

SJRG has a firm transportation agreement with Dominion which expires October 31, 2022. Under this agreement, Dominion will provide SJRG with 5,000 dts/d of deliveries to Leidy, PA and receipts at Lebanon, Ohio.

Columbia Gas Transmission:

SJRG holds a firm transportation agreement with Columbia. Under this evergreen agreement, Columbia provides receipts at Leach, Kentucky and deliveries of 14,714 dts/d to New Jersey. In addition, SJRG has 10,000 dts/d of Columbia capacity from New York to Maryland expiring October 31, 2018. SJRG also holds capacity ranging from 20,000/dth/d to 50,000 dth/d of receipts from Marcellus to southern New Jersey expiring October 31, 2030. SJRG also holds various transportation contracts with deliveries in New York and Pennsylvania that range in volumes from 4,703 to 20,000 dts/d and that expire at various dates between September 30, 2018 and October 31, 2024.

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South Jersey Industries, Inc.

Part I

SJRG has a storage agreement with Columbia for service under Columbia's FSS rate schedule. Under this evergreen agreement, Columbia will provide SJRG with storage capacity of 1,249,515 dts. Under this agreement, 19,029 dts/d may be withdrawn from storage and 9,996 dts/d may be injected.

SJRG holds firm transportation related to the above mentioned storage agreement which provides for receipts at storage and deliveries to New Jersey of 19,029 dts/d. Under this evergreen contract, these services with Columbia were released to SJRG by SJG.

Columbia Gulf Transmission:

SJRG holds a firm transportation agreement with Columbia Gulf which expires October 31, 2019. Under this agreement, Columbia Gulf provides receipts in Louisiana with deliveries at Leach, Kentucky in the amount of 15,000 dts/d.    

Tennessee Gas Transmission:

SJRG holds multiple firm transportation agreements with the Tennessee Gas Pipeline that have various deliveries and receipts in Pennsylvania and Louisiana. Under these agreements, 162,781dts/d of transportation expires March 31, 2017, with an additional 75,000 dts/d of transportation that expires between October 31, 2018 and October 31, 2024.

Egan Storage:

SJRG holds a storage agreement with Egan Storage for service under Tetco’s FSS rate schedule.  Under this agreement, which expires March 31, 2017, Tetco provides SJRG with storage capacity of 500,000 dts.

Bobcat Storage:

SJRG holds a storage agreement with Bobcat Storage for service under Tetco’s FSS rate schedule.  Under this agreement, which expires March 31, 2017, Tetco provides SJRG with storage capacity of 500,000 dts.

Gas Supplies

SJRG has entered into several long-term natural gas supply agreements to purchase a minimum of 745,000 dts/d and up to 940,000 dts/d, depending upon production levels, for terms ranging from three to ten years at index-based prices.

Patents and Franchises

South Jersey Gas Company

SJG holds nonexclusive franchises granted by municipalities in the seven-county area of southern New Jersey that it serves. No other natural gas public utility presently serves the territory covered by SJG's franchises. Otherwise, patents, trademarks, licenses, franchises and concessions are not material to the business of SJG.

Seasonal Aspects

South Jersey Gas Company

SJG experiences seasonal fluctuations in sales when selling natural gas for heating purposes. SJG meets this seasonal fluctuation 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's revenues and net income are significantly higher during the first and fourth quarters than during the second and third quarters of the year.

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South Jersey Industries, Inc.

Part I

Non-Utility Companies

Among SJI's non-utility activities, wholesale and retail gas marketing have seasonal patterns similar to SJG's. Activities such as energy services and energy project development do not follow seasonal patterns. Other activities, such as retail electric marketing and appliance service, can have seasonal earnings patterns that are different from the utility. 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 Discussion and Analysis of Financial Condition and Results of Operations,” of this Report.

Customers

No material part of the 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 SJI's performance on a consolidated basis.

Backlog

Backlog is not material to an understanding of SJI's business or that of any of its subsidiaries.

Government Contracts

No material portion of the 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 for SJI and its subsidiaries can be found in Item 7, “Management's Discussion and Analysis of Financial Condition and Results of Operations,” of this Report.

Research

During the last three fiscal years, neither 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 15 of the consolidated financial statements included under Item 8 of this Report.

Employees

SJI and its subsidiaries had a total of approximately 750 employees as of December 31, 2016. Of that total, approximately 330 employees are unionized. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76.  SJG and SJESP employees represented by the IBEW operate under collective bargaining agreements that run through February 2018. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017.

Financial Information About Foreign and Domestic Operations and Export Sales

SJI has no foreign operations and export sales have not been a significant part of SJI's business.

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South Jersey Industries, Inc.

Part I

Item 1A. Risk Factors

SJI and its subsidiaries operate in an environment that involves risks, many of which are beyond our control. SJI has identified the following risk factors that could cause SJI's operating results and financial condition to be materially adversely affected. In addition, new risks may emerge at any time, and SJI cannot predict those risks or the extent to which they may affect SJI's businesses or financial 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.

• SJI's business activities are concentrated in southern New Jersey. Changes in the economies of southern New Jersey and surrounding regions could negatively impact the growth opportunities available to SJI and the financial condition of the customers and prospects of SJI.

• Changes in the regulatory environment or unfavorable rate regulation at its utility may have an unfavorable impact on SJI's financial performance or condition.  SJI's utility business is regulated by the New Jersey Board of Public Utilities (BPU) which has authority over many of the activities of the utility business including, but not limited to, the rates it 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's ability to earn a reasonable rate of return on invested capital and/or fully recover operating costs may adversely affect its results of operations, financial condition and cash flows.

• SJI may not be able to respond effectively to competition, which may negatively impact SJI's 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 some of SJI's energy products and services. SJI's utility currently has a conservation incentive program clause that protects its revenues and gross margin against usage that is lower than a set level. Should this clause be terminated without replacement, lower customer energy utilization levels would likely reduce SJI's net income. Further, during periods of warmer temperatures, demand and volatility in the natural gas market could decrease, which would negatively impact the Company's financial results.

• High natural gas prices could cause more of SJI's receivables to be uncollectible. Higher levels of uncollectibles from either residential or commercial customers would negatively impact SJI's income and could result in higher working capital requirements.

• SJI's net income could decrease if it is required to incur additional costs to comply with new governmental safety, health or environmental legislation. SJI is subject to extensive and changing federal and state laws and regulations that impact many aspects of its business; including the storage, transportation and distribution of natural gas, as well as the remediation of environmental contamination at former manufactured gas plant facilities.

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South Jersey Industries, Inc.

Part I

• Climate change legislation could impact SJI'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. Several of SJI's subsidiaries 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 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. SJI uses 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.

• The inability to obtain natural gas or electricity from suppliers would negatively impact the financial performance of SJI. Several of SJI's subsidiaries have businesses based upon the ability to deliver natural gas or electricity to customers. Disruption in the production or transportation to SJI from its suppliers could prevent SJI from completing sales to its customers.

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South Jersey Industries, Inc.

Part I

• Transporting and storing natural gas involves numerous risks that may result in accidents and other operating risks and costs. SJI'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 maintains 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 financial position, results of operations and cash flows.

• Adverse results in legal proceedings could be detrimental to the financial condition of SJI. The outcomes of legalproceedings can be unpredictable and can result in adverse judgments.

• Renewable energy projects at Marina receive significant benefit from regulatory incentives. A significant portion of the expected return on investment of these renewable energy projects is dependent upon the future market for renewable energy credits (RECs). The benefits from RECs are produced during the entire life of the project. As a result, earnings from existing projects would be adversely affected without a liquid REC market. In addition, the return on investment from new projects may not be as attractive if a liquid REC market ceases to exist.  Therefore, these projects are exposed to the risk that favorable regulatory incentives expire or are adversely modified.

• 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.

• The risk of terrorism may adversely affect the economy as well as SJI's business. An act of terror could result in disruptions of natural gas supplies and cause instability in the financial and capital markets. This could adversely impact SJI's ability to deliver products or raise capital and could adversely impact its results of operations.

• Failure to obtain proper approvals and property 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 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.

• 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 has experienced such attacks in the past; however, based on information currently available to SJI, 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.

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South Jersey Industries, Inc.

Part I

• 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. Our current long-term goals are to (i) grow Economic Earnings to at least $150 million by 2020; (ii) improve the quality of our earnings; (iii) strengthen our balance sheet; and (iv) maintain 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 a 100-mile natural gas pipeline in Pennsylvania and New Jersey. However, construction on this project has not yet begun, and this project is subject to a number of regulatory approvals, including approval from the Federal Energy Regulatory Commission. The target completion date for this project has been delayed until the second half of 2018, and may be subject to further delay. As a result, no assurance can be given that this project will be completed on time or at all. Further, the economy of Southern New Jersey has remained depressed relative to other regions, which could cause increased customer delinquencies or otherwise negatively affect achievement of our long-term earnings goals. Due to a term limit, the upcoming 2017 New Jersey gubernatorial election will result in a change in administration, which could lead to unfavorable 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.

Item 1B. Unresolved Staff Comments

None.

11

Item 2. Properties

The principal property of SJI consists of SJG's 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, there were approximately 146.2 miles of mains in the transmission systems and 6,605 miles of mains in the distribution systems.

SJG owns approximately 154 acres of land in Folsom, New Jersey which is the site of SJI's corporate headquarters. Approximately 140 acres of this property is 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.

As of December 31, 2016, SJG's utility plant had a gross book value of $2.4 billion and a net book value, after accumulated depreciation, of $2.0 billion. In 2016, $225.3 million was spent on additions to utility plant and there were retirements of property having an aggregate gross book cost of $16.7 million.

Virtually all of SJG's 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's 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 $670.9 million consists primarily of Marina's energy projects.

South Jersey Fuel, Inc., an inactive subsidiary, owns land in Deptford Township and owns real estate in Upper Township, New Jersey.

Item 3. Legal Proceedings

The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary.

The Company is currently involved in a pricing dispute related to two long-term gas supply contracts whereby the Company had sued the supplier to recover amounts that were improperly invoiced. Subsequently, the supplier countersued the Company claiming it is owed an amount which we extrapolate to be $14.9 million from SJG, plus interest, and $40.2 million from SJRG, plus interest, through December 31, 2016. We believe any monies received or paid associated with the SJG claims would reflect gas costs that would be recovered from SJG's customers through adjusted rates.

The Company is also involved in a dispute related to a three-year capacity management contract with a counterparty whereby the Company is the manager. The counterparty is claiming that it is owed approximately $13.3 million, plus interest, from SJRG under a sharing credit within the contract.

Liabilities related to these claims are accrued when the amount or range of amounts of probable settlement costs or other charges for these claims can be reasonably estimated. The Company has accrued approximately $3.1 million and $3.2 million related to all claims in the aggregate as of December 31, 2016 and 2015, respectively. Although the Company does not presently believe that these matters will have a material adverse effect on its business, given the inherent uncertainties in such situations, the Company can provide no assurance regarding the outcome of litigation.

Item 4. Mine Safety Disclosures

Not applicable.

South Jersey Industries, Inc.

Part I

Item 4A. Executive Officers of the Registrant

Set forth below are the names, ages and positions of our 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 49
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
Vice President	January 2004 - December 2012
Jeffrey E. DuBois, Age 58
Chief Operating Officer	January 2017 - Present
Executive Vice President	April 2015 - Present
Senior Vice President	January 2013 - April 2015
Vice President	January 2004 - December 2012
Stephen H. Clark, Age 58
Executive Vice President	January 2017 - Present
Senior Vice President	April 2015 - December 2016
Chief Financial Officer	November 2013 - Present
Vice President	January 2013 - November 2013
Treasurer	January 2004 - April 2014
Kenneth A. Lynch, Age 51
Chief Risk Officer	January 2017 - Present
Senior Vice President	April 2015 - Present
Chief Accounting Officer	January 2013 - December 2016
Assistant Vice President	July 2006 - December 2012
Kathleen A. McEndy, Age 63
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
Principal, The McEndy Group, LLC	January 2009 - March 2013
Gina M. Merritt-Epps, Age 49
Senior Vice President	April 2015 - Present
General Counsel and Corporate Secretary	May 2009 -  Present
Gregory M. Nuzzo, Age 42
President, South Jersey Energy Solutions	January 2017 - Present
Chief Operating Officer, South Jersey Energy Solutions	January 2017 - Present
Senior Vice President	April 2015 - Present
Vice President	April 2014 - April 2015
Senior Vice President, South Jersey Energy Solutions	January 2013 - December 2016

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Part I

Senior Vice President, South Jersey Resources Group	January 2013 - March 2014
Vice President, South Jersey Energy Solutions	January 2012 - December 2012
Vice President, South Jersey Resources Group	January 2010 - December 2012
David Robbins, Jr., Age 54
President, South Jersey Gas Company	January 2017 - Present
Senior Vice President	April 2015 - Present
Vice President	April 2014 - April 2015
Senior Vice President, South Jersey Energy Solutions	January 2013 - December 2016
Chief Operating Officer, South Jersey Energy Solutions	January 2013 - April 2014
Vice President, South Jersey Energy Solutions	April 2011 - December 2012
Treasurer & Secretary, South Jersey Energy Solutions	January 2010 - December 2012

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South Jersey Industries, Inc.

Part II

PART II

Item 5. Market for the Registrant's Common Equity,

Related Stockholder Matters and Issuer Purchases of Equity Securities

Market Price of Common Stock and Related Information

Quarter Ended	Market Price Per Share				Dividends		Quarter Ended	Market Price Per Share*				Dividends
					Declared							Declared
2016	High		Low		Per Share		2015	High		Low		Per Share*
March 31	$	29.14	$	22.06	$	0.264	March 31	$	30.37	$	26.02	$	0.251
June 30	$	31.64	$	26.29	$	0.264	June 30	$	27.66	$	24.51	$	0.251
September 30	$	32.03	$	28.17	$	0.264	September 30	$	26.09	$	22.91	$	0.251
December 31	$	34.85	$	27.51	$	0.273	December 31	$	27.34	$	21.24	$	0.264
*All 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 May 8, 2015. See Note 1 to the consolidated financial statements.

These quotations are based on the list of composite transactions of the New York Stock Exchange. Our stock is traded on the New York Stock Exchange under the symbol SJI. We have declared and expect to continue to declare regular quarterly cash dividends. As of December 31, 2016, the latest available date, our records indicate there were 6,646 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 2016.

This performance chart assumes:

• $100 invested on December 31, 2011 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.

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South Jersey Industries, Inc.

Part II

	Dec-11		Dec-12		Dec-13		Dec-14		Dec-15		Dec-16
S&P 500	$	100	$	116	$	154	$	175	$	177	$	198
S&P Utilities	$	100	$	101	$	115	$	148	$	141	$	164
SJI	$	100	$	91	$	105	$	114	$	95	$	141

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 stated goal of increasing its dividend annually.

In 2016, non-employee members of SJI's Board of Directors received an aggregate of 35,197 shares of restricted stock, valued at that time at $840,504, 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, 2016.

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South Jersey Industries, Inc.

Part II

Item 6. Selected Financial Data

2016 HIGHLIGHTS

Five-Year Summary of Selected Financial Data

(In Thousands Where Applicable)

South Jersey Industries, Inc. and Subsidiaries

Year Ended December 31,

	2016			2015			2014			2013			2012
Operating Results:
Operating Revenues	$	1,036,500		$	959,568		$	886,996		$	731,421		$	706,280
Operating Income	$	189,276		$	156,894		$	127,603		$	69,636		$	109,898
Income from Continuing Operations	$	119,061		$	105,610		$	97,628		$	82,389		$	92,776
Discontinued Operations - Net (1)	(251		)	(503		)	(582		)	(796		)	(1,168		)
Net Income	$	118,810		$	105,107		$	97,046		$	81,593		$	91,608
Total Assets	$	3,730,567		$	3,480,900		$	3,349,425		$	2,924,855		$	2,631,440
Capitalization:
Equity	$	1,289,240		$	1,037,539		$	932,432		$	827,000		$	736,214
Long-Term Debt	808,005			1,006,394			859,491			680,400			601,400
Total Capitalization	$	2,097,245		$	2,043,933		$	1,791,923		$	1,507,400		$	1,337,614
Ratio of Earnings to Fixed Charges (2)	5.4		x	3.8x			3.8x			3.0x			5.1x
Diluted Earnings Per Common Share (Based on Average Diluted Shares Outstanding) (3):
Continuing Operations	$	1.56		$	1.53		$	1.47		$	1.29		$	1.51
Discontinued Operations - Net (1)	—			(0.01		)	(0.01		)	(0.01		)	(0.02		)
Diluted Earnings Per Common Share (3)	$	1.56		$	1.52		$	1.46		$	1.28		$	1.49
Return on Average Equity (4)	10.2		%	10.7		%	11.1		%	10.5		%	13.6		%
Share Data:
Number of Shareholders of Record	6.7			6.7			6.9			6.9			7.1
Average Common Shares (3)	76,362			68,735			66,278			63,978			61,488
Common Shares Outstanding at Year End (3)	79,478			70,966			68,334			65,430			63,306
Dividend Reinvestment Plan:
Number of Shareholders	5.2			5.2			5.2			5.2			4.8
Number of Participating Shares (3)	3,627			4,170			4,082			4,118			4,924
Book Value at Year End (3)	$	16.22		$	14.62		$	13.65		$	12.64		$	11.63
Dividends Declared per Common Share (3)	$	1.07		$	1.02		$	0.96		$	0.90		$	0.83
Market Price at Year End (3)	$	33.69		$	23.52		$	29.46		$	27.98		$	25.17

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Dividend Payout (3):
From Continuing Operations	68.6		%	66.4		%	65.2		%	69.9		%	54.7		%
From Total Net Income	68.8		%	66.7		%	65.6		%	70.6		%	55.4		%
Market-to-Book Ratio (3)	2.1		x	1.6x			2.2x			2.2x			2.2x
Price Earnings Ratio (3, 4)	21.6		x	15.4x			20.0x			21.8x			16.7x
Consolidated Economic Earnings (5)
Income from Continuing Operations	$	119,061		$	105,610		$	97,628		$	82,389		$	92,776
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges (6)	(26,867		)	(8,355		)	8,211			23,422			(1,443		)
Net Loss from Affiliated Companies, Not Part of Ongoing Operations (6,7)	—			—			—			1,252			—
Unrealized Loss on Property, Plant and Equipment (6)	—			—			—			—			2,337
Net Loss from Affiliated Companies (6,8)	—			(2,540		)	2,540			—			—
Other (6,9)	(165		)	(165		)	(165		)	(165		)	—
Income Taxes (10)	10,813			4,424			(4,235		)	(9,804		)	(357		)
Economic Earnings	$	102,842		$	98,974		$	103,979		$	97,094		$	93,313
Earnings per Share from Continuing Operations (3)	$	1.56		$	1.53		$	1.47		$	1.29		$	1.50
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges (6)	(0.35		)	(0.12		)	0.12			0.36			(0.02		)
Net Loss from Affiliated Companies, Not Part of Ongoing Operations (6,7)	—			—			—			0.02			—
Unrealized Loss on Property, Plant and Equipment (6)	—			—			—			—			0.04
Net Loss from Affiliated Companies (6,8)	—			(0.04		)	0.04			—			—
Income Taxes (10)	0.13			0.07			(0.06		)	(0.16		)	(0.01		)
Economic Earnings per Share (3)	$	1.34		$	1.44		$	1.57		$	1.51		$	1.51

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Part II

(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 Consolidated Financial Statements).
(2)	Calculated as Income 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. See Note 1 to the consolidated financial statements.
(4)	Calculated based on Income from Continuing Operations.
(5)	This section includes the non-generally accepted accounting principles (“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.
(6)	Certain reclassifications have been made to the prior period numbers in these tables to conform to the current period presentation. The prior period numbers in these line items have been adjusted to be presented before income taxes.
(7)	Resulting from the termination of the contract at LVE Energy Partners, LLC to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.
(8)	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 (see Note 7 to the consolidated financial statements). 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 of 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.
(9)	Represents additional depreciation expense within Economic Earnings on a solar generating facility. During 2012 an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and, therefore, the related reduction in depreciation expense is being added back.
(10)	Determined using a combined average statutory tax rate of 40% for all periods presented.

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South Jersey Industries, Inc.

Part II

Item 7. Management's Discussion and Analysis of Financial Condition and

Results of Operations

OVERVIEW - South Jersey Industries, Inc. (SJI or the Company) is an energy services holding company that provides a variety of products and services through the following wholly-owned subsidiaries:

South Jersey Gas Company (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. SJG also sells natural gas and pipeline transportation capacity (off-system sales) on a wholesale basis to various customers on the interstate pipeline system and transports natural gas purchased directly from producers or suppliers to their customers. SJG contributed approximately 58.1% of SJI's net income on a consolidated basis in 2016.

SJG's service territory covers approximately 2,500 square miles in the southern part of New Jersey. It includes 115 municipalities throughout Atlantic, Cape May, Cumberland and Salem Counties and portions of Burlington, Camden and Gloucester Counties, with an estimated permanent population of 1.2 million. SJG benefits from its proximity to Philadelphia, PA and Wilmington, DE on the western side of its service territory and the popular shore communities on the eastern side. Continuing expansion of SJG's infrastructure throughout its seven-county region has fueled annual customer growth and creates opportunities for future extension into areas not yet served by natural gas.

SJG believes there is an ongoing transition of southern New Jersey's oceanfront communities from seasonal resorts to year round economies. In mainland communities, building expansions in the medical, education and retail sectors contributed to SJG's growth. At present, SJG serves approximately 71% of households within its territory with natural gas. SJG also serves southern New Jersey's diversified industrial base that includes processors of petroleum and agricultural products; chemical, glass and consumer goods manufacturers; and high technology industrial parks.

As of December 31, 2016, SJG served 377,625 residential, commercial and industrial customers in southern New Jersey, compared with 373,100 customers at December 31, 2015.  No material part of SJG's business is dependent upon a single customer or a few customers. Gas sales, transportation and capacity release for 2016 amounted to 148.4 MMdts, of which 56.8 MMdts were firm sales and transportation, 1.2 MMdts were interruptible sales and transportation and 90.4 MMdts were off-system sales and capacity release. The breakdown of firm sales and transportation includes 42.5% residential, 20.9% commercial, 21.0% industrial, and 15.6% cogeneration and electric generation. As of December 31, 2016, SJG served 352,427 residential customers, 24,767 commercial customers and 431 industrial customers.  This includes 2016 net additions of 4,334 residential customers and 191 commercial and industrial customers.

SJG makes wholesale gas sales to gas marketers for resale and ultimate delivery to end users. These “off-system” sales are made possible through the issuance of the Federal Energy Regulatory Commission (FERC) Orders No. 547 and 636. Order No. 547 issued a blanket certificate of public convenience and necessity authorizing all parties, which are not interstate pipelines, to make FERC jurisdictional gas sales for resale at negotiated rates, while Order No. 636 allowed SJG to deliver gas at delivery points on the interstate pipeline system other than its own city gate stations and release excess pipeline capacity to third parties. During 2016, off-system sales amounted to 16.5 MMdts and capacity release amounted to 73.9 MMdts.

Supplies of natural gas available to SJG 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 SJG at any time if this action is necessary to meet the needs of higher priority customers as described in SJG's tariffs. In 2016, usage by interruptible customers, excluding off-system customers, amounted to 1.2 MMdts, or approximately 1.0% of the total throughput.

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South Jersey Industries, Inc.

Part II

South Jersey Energy Solutions, LLC

SJI groups its nonutility operations into two 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 established South Jersey Energy Solutions, LLC (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:

South Jersey Energy Company (SJE)

SJE provides services for the acquisition and transportation of natural gas and electricity for retail end users and markets total energy management services. SJE markets natural gas and 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 2016, SJE contributed approximately 6.3% of SJI's net income on a consolidated basis.

South Jersey Resources Group, LLC (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 2016, SJRG contributed approximately 21.9% of SJI's net income on a consolidated basis.

South Jersey Exploration, LLC (SJEX)

SJEX owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. SJEX is a wholly-owned subsidiary of SJES and is also considered part of SJI's wholesale energy operations. In 2016, SJEX contributed less than 1.0% of SJI's net income on a consolidated basis.

Marina Energy LLC (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.  Marina also owns numerous solar generation projects.

Marina's other projects include a 50% equity interest in Energenic-US, LLC (Energenic). Energenic developed and operated on-site energy projects such as thermal facilities, combined heat and power facilities, landfill gas-fired electric production facilities and solar projects. On December 31, 2015, Energenic, Marina and its joint venture partner entered into two Equity Distribution and Purchase Agreements, pursuant to which Marina became the sole owner of eight of the Energenic projects and its joint venture partner became the sole owner of seven other Energenic projects.  The project entities that are now wholly owned by Marina are ACB Energy Partners, LLC (ACB), AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE), SX Landfill Energy, LLC (SXLE), MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) & SBS Energy Partners, LLC (SBS).

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-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.

MCS, NBS and SBS own and operate solar-generation sites located in New Jersey.

In 2016, Marina contributed approximately 13.5% of SJI's net income on a consolidated basis.

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South Jersey Energy Service Plus, LLC (SJESP)

SJESP services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. SJESP serves southern New Jersey where it is one of the largest local HVAC service company's with nearly 25 experienced technicians. SJESP receives a commission on all new and renewed service contracts and is paid a fee to service those warranty contracts. In 2016, SJESP contributed less than 1.0% of SJI's net income on a consolidated basis.

Other

SJI Midstream, LLC owns a 20% equity investment in PennEast Pipeline Company, LLC, through which SJI, along with other investors, expect to construct an approximately 100-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, estimated to be completed in the second half of 2018.

Energy & Minerals, Inc. (EMI) principally manages liabilities associated with its discontinued operations of nonutility subsidiaries.

Primary Factors Affecting SJI's Business

SJI's stated long-term goals are to: 1) Grow Economic Earnings to at least $150 million by 2020; 2) Improve the quality of earnings; 3) Strengthen the balance sheet; and 4) Maintain a low-to-moderate risk profile. Management established those goals in conjunction with SJI's Board of Directors based upon a number of different internal and external factors that characterize and 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 SJI's performance and ability to achieve the long-term goals going forward:

Business Model - In developing SJI's current business model, our focus has been on our core utility and natural extensions of that business. That focus enables us to concentrate on business activities that match our core competencies. Going forward we expect to pursue business opportunities that fit this model.

Customer Growth - Southern New Jersey, our 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 customers for SJG grew 1.2% for 2016 as SJG continues its focus on customer conversions.  In 2016, the 4,631 consumers converting their homes and businesses from other heating fuels, such as electric, propane or oil, represented approximately 65% of the total new customer acquisitions for the year. In comparison, conversions over the past five years averaged 5,317 annually. Customers in SJG'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.

Regulatory Environment - SJG is primarily regulated by the New Jersey Board of Public Utilities (BPU). The BPU sets the rates that SJG charges its rate-regulated customers for services provided and establishes the terms of service under which SJG operates. SJG expects the BPU to continue to set rates and establish terms of service that will enable SJG to obtain a fair and reasonable return on capital invested. The BPU approved a Conservation Incentive Program (CIP) effective October 1, 2006, discussed in greater detail under "Results of Operations", that protects SJG's net income from severe fluctuations in gas used by residential, commercial and small industrial customers. In addition, in February 2013, the BPU issued an Order approving the Accelerated Infrastructure Replacement Program (AIRP), 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 all AIRP investments are reflected in base rates. Additionally, the BPU issued an Order approving an extension of the AIRP for a 5-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 until 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), a $103.5 million program to replace low-pressure distribution mains and services with high-pressure mains and services on the barrier islands over a three-year period, with annual investments of approximately $34.5 million. 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. SJG earns a return on SHARP investments until they are included in rate base through annual rate adjustments.

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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. SJG's earnings are largely protected from fluctuations in temperatures by the CIP. The CIP has a stabilizing effect on utility earnings as SJG adjusts revenues when actual usage per customer experienced during an annual period varies from an established baseline usage per customer. 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, Electricity and Solar Renewable Energy Credit (SREC) Prices - The utility's gas costs are passed on directly to customers without any profit margin added by SJG. The price the utility charges its periodic customers 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, SJG can petition the BPU for an incremental rate increase. High prices can make it more difficult for SJG's 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 gas or 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. Marina Energy’s SREC portfolio typically benefits from increases in individual SREC spot markets for any current or future energy year.  Positive spot market movement affords Marina a potential opportunity to sell open production and improve upon or solidify future SREC revenue streams for particular SREC products. 

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 ten fuel supply management transactions under contract and expect to continue expanding this business.

Midstream Investments - Design, engineering and environmental assessments continue moving forward on a natural gas pipeline in Pennsylvania and New Jersey. In September 2015, Midstream, along with other partners in the project, submitted an application to FERC for a permit to proceed with construction. The requested Certificate of Public Convenience and Necessity would authorize PennEast, of which Midstream has a 20% equity interest, to construct, install, own, operate and maintain this pipeline. We expect to make additional investments in similar midstream projects.

Changes in Interest Rates - 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 SJI'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. We expect savings from these changes to gradually increase as new hires replace retiring employees. Our workforce totaled approximately 750 employees at the end of 2016, of which approximately 330 are unionized.

Balance Sheet Strength - Our goal is to maintain a strong balance sheet. Our average equity-to-capitalization ratio was approximately 48% as calculated for the four quarters of 2016 as compared with 42% in 2015.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-to-moderate risk platform.

CRITICAL ACCOUNTING POLICIES - ESTIMATES 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. Five 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, and revenue recognition.

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Regulatory Accounting - SJI's largest subsidiary, SJG, maintains its accounts according to the Uniform System of Accounts as prescribed by the BPU. As a result of the ratemaking process, SJG is required to follow Financial Accounting Standards Board (FASB) ASC Topic 980 - “Regulated Operations.”  SJG is required under Topic 980 to recognize the impact of regulatory decisions on its financial statements. SJG is required under its Basic Gas Supply Service (BGSS) clause to forecast its natural gas costs and customer consumption in setting its rates. Subject to BPU approval, SJG is able to recover or return the difference between gas cost recoveries and the actual costs of gas through a BGSS charge to customers. SJG records any over/under recoveries as a regulatory asset or liability on the consolidated balance sheets and reflects them in the BGSS charge to customers in subsequent years. SJG also enters into derivatives that are used to hedge natural gas purchases. The offset to 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 10 to the consolidated financial statements.

Derivatives - SJI 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 Loss 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 have 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 Accumulated Other Comprehensive Loss on the consolidated balance sheets, are being recorded into earnings over the remaining life of the derivative. These derivatives will mature in 2026.

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 generally accepted in the United States of America (GAAP), derivatives related to SJG's gas purchases that are marked-to-market are recorded through the BGSS.  SJG periodically enters 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 SJG's BGSS, subject to BPU approval (See Notes 10 and 11 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 16 and 17 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 SJI, are incorporated and considered in the valuation of all derivative instruments as appropriate. The effect of counterparty credit risk and the credit risk of SJI 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 these 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.

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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, SJI 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 15 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 SJI.    

During 2015, a combination of factors resulted in lowering the Company’s expected cost of providing pension and other postretirement healthcare costs in 2016. These include increasing discount rates and updated mortality tables released by the Society 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 healthcare 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.

During 2016, the Company's expected cost of providing pension and other postretirement healthcare in 2017 increased primarily due to decreasing discount rates resulting from lower market interest rates at the end of 2016. As a result, the Company is estimating a $0.8 million net increase in the cost of providing these benefits in 2017.

Additional information regarding investment returns and assumptions can be found in Pension and Other Postretirement Benefits in Note 12 to the consolidated financial statements.

Revenue Recognition - Gas and electricity revenues are recognized in the period the commodity is delivered to customers. SJG, SJRG and SJE bill customers monthly. A majority of SJG and SJE customers have their meters read on a cycle basis throughout the month. For SJG and SJE retail customers that are not billed at the end of each month, we record an estimate to recognize unbilled revenues for gas/electricity delivered from the date of the last meter reading to the end of the month. SJG's and SJE's unbilled revenue for natural gas is estimated each month based on 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 customers at rates approved by the BPU. 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.

We recognize revenues related to SJESP's appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenues related to services provided on a time and materials basis are recognized on a monthly basis as the services are provided.

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Marina recognizes revenue on a monthly basis as services are provided and for on-site energy production that is delivered to its customers.

The BPU allows SJG to recover gas costs in rates through the BGSS price structure. SJG defers over/under recoveries of gas costs and includes 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 SJG realizes 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. 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 Notes 10 and 11 to the consolidated financial statements).

Each CIP year begins October 1 and ends September 30 of the subsequent year.  On a monthly basis during a CIP year, SJG records adjustments to earnings based on weather and customer usage factors, as incurred.  Subsequent to each year, SJG 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.

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 - As a public utility, SJG is 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 SJG's business. SJG is affected by Federal regulation with respect to transportation and pricing policies applicable to pipeline capacity from Transcontinental Gas Pipe Line Company, LLC (SJG's major supplier), Columbia Gas Transmission, LLC and Dominion Transmission, Inc., since such services are provided under rates and terms established under the jurisdiction of the FERC. SJG's 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. SJG's primary rate mechanisms include base rates, the BGSS, Accelerated Infrastructure Programs, Energy Efficiency Tracker (EET) and the CIP.

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. 

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 SJG's net income for the last three years and the associated weather comparisons were as follows ($'s in millions):

	2016		2015			2014
Net Income Impact:
CIP - Weather Related	$	5.9	$	0.9		$	(4.7	)
CIP - Usage Related	4.0		(1.9		)	2.0
Total Net Income Impact	$	9.9	$	(1.0	)	$	(2.7	)
Weather Compared to 20-Year Average	8.1% warmer		3.1% warmer			7.5% colder
Weather Compared to Prior Year	2.5% warmer		9.6% warmer			4.6% colder

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As part of the CIP, SJG 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. SJG 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 SJG'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 SJG's return on equity to exceed 9.75% (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.

See additional detailed discussions on Rates and Regulatory Actions in Note 10 to the consolidated financial statements.

ENVIRONMENTAL REMEDIATION - See detailed discussion concerning Environmental Remediation in Note 15 to the consolidated financial statements.

COMPETITION - SJG's franchises are non-exclusive. Currently, no other utility provides retail gas distribution services within SJG's territory. SJG does not expect any other utilities to do so in the foreseeable future because of the extensive investment required for utility plant and related costs. SJG competes with oil, propane and electricity suppliers for residential, commercial and industrial users, with alternative fuel source providers (wind, solar and fuel cells) based upon price, convenience and environmental factors, and with other marketers/brokers in the selling of wholesale natural gas services. The market for natural gas commodity sales is subject to competition due to deregulation. SJG's competitive position was enhanced while maintaining margins by using an unbundled tariff. This tariff allows full cost-of-service recovery when transporting gas for SJG's customers. Under this tariff, SJG profits from transporting, rather than selling, the commodity. SJG's residential, commercial and industrial customers can choose their supplier, while SJG recovers the cost of service through transportation service (See Customer Choice Legislation below).

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.

SJE competes with utilities and other third-party marketers to sell the unregulated natural gas and electricity commodity to customers. Marketers compete largely on price, which is driven by the commodity market. While the utilities are typically indifferent as to where customers get their gas or electricity, the price they set for the commodity they sell creates competition for SJE. Based on its market share, SJE is one of the largest marketers of natural gas in southern New Jersey as of December 31, 2016. In addition, similar to SJG, SJE faces competition from other energy products.

SJESP competes primarily with smaller, local contractors in southern New Jersey that service residential and commercial HVAC systems and provide major appliance repair and plumbing services. These contractors typically only serve their local communities and do not serve the entire southern part of New Jersey.

CUSTOMER CHOICE LEGISLATION - All residential natural gas customers in New Jersey can choose their natural gas commodity supplier under the terms of the “Electric Discount and Energy Competition Act of 1999." This bill created the framework and necessary time schedules for the restructuring of the state's electric and natural gas utilities. The Act established unbundling, where redesigned utility rate structures allow natural gas and electric consumers to choose their energy supplier. It also established time frames for instituting competitive services for customer account functions and for determining whether basic gas supply services should become competitive. Customers purchasing natural gas from a provider other than the local utility (the “marketer”) are charged for the gas costs by the marketer and charged for the transportation costs by the utility. The total number of customers in SJG's service territory purchasing natural gas from a marketer averaged 34,130; 36,191 and 41,837 during 2016, 2015 and 2014, respectively.

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RESULTS OF OPERATIONS:

SJI operates in several different reportable operating segments. These segments are as follows:

• Gas utility operations (SJG) consist primarily of natural gas distribution to residential, commercial and industrial customers.

• Wholesale energy operations include the activities of SJRG and SJEX.

• SJE is involved in both retail gas and retail electric activities.

◦ Retail gas and other operations include natural gas acquisition and transportation service business lines.

◦ Retail electric operations 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. Included in this segment are the activities of the following significant entities: ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS. These entities became wholly-owned subsidiaries of Marina on December 31, 2015 (see Note 3 to the consolidated financial statements).

• Appliance service operations includes SJESP, which services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. 

• Midstream was formed to invest in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey. The activities of Midstream are a part of the Corporate and Services segment.

SJI groups its nonutility operations into two 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 2016 increased $13.7 million, or 13.0%, to $118.8 million compared to 2015 primarily as a result of the following:

• The net income contribution from retail gas and electric operations at SJE increased $8.2 million to $7.5 million, primarily due to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on retail gas and electric as discussed under "Operating Revenues – Nonutility" below.

• The net income contribution from the wholesale energy operations at SJRG increased $4.8 million to $26.0 million, primarily due to an approximately $2.7 million increase related to additional capacity along with margins earned on gas supply contracts with two electric generation facilities compared to the prior year as described in "Gross Margin - Energy Group" below, along with an approximately $2.1 million increase 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.

• The net income contribution from gas utility operations at SJG increased $2.5 million to $69.1 million, primarily due to the rolling into base rates of SHARP and AIRP investments, along with customer growth, as described under "Margin - Gas Utility Operations" below.

• The net income contribution from on-site energy production at Marina increased $0.5 million to $16.0 million, primarily due to the following:

◦ $15.2 million increase due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in 2015 (see Note 7 to the consolidated financial statements), along with other losses incurred at the Energenic operating subsidiaries in 2015.

◦ $9.3 million increase due to several new renewable energy projects that commenced operations over the past twelve months, along with higher prices on SRECs compared to the previous year as discussed in "Gross Margin - Energy Services" below.

◦ $4.5 million increase due to a settlement at Marina in 2016 (see Note 7 to the consolidated financial statements).

◦ $0.7 million increase due to the impact of several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the consolidated financial statements).

◦ $29.2 million decrease due to the impact of lower renewable energy investments on the investment tax credits available as compared to the prior year. This reduction is consistent with the Company's previously announced strategy of substantially reducing solar development in 2016.

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• The net income contribution from SJEX decreased $1.4 million to $0.1 million primarily due to a gain on the sale of a working interest in assets of Potato Creek in 2015, which did not recur in 2016.

SJI's net income for 2015 increased $8.1 million, or 8.3%, to $105.1 million compared to 2014, primarily as a result of the following:

• The net income contribution from the wholesale energy operations at SJRG increased $15.6 million to net income of $21.2 million due primarily to an approximately $11.1 million increase 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, along with an approximately $4.5 million increase related to higher storage hedge gains and higher daily trading margins, partially offset by lower storage volumes sold compared to the prior year as described in "Gross Margin - Energy Group" below.

• The net income contribution from on-site energy production at Marina decreased $6.6 million to $15.5 million due primarily to the impact of a reduction in the carrying amount of an investment, along with an accrual of the cost to settle a legal claim, at one of Energenic's operating subsidiaries, of which Marina has a 50% equity interest (see Note 7 to the consolidated financial statements). Partially offsetting this decrease is the impact of the investment tax credits available on renewable energy facilities compared to the prior year.

• The net income contribution from retail gas and electric operations at SJE decreased $1.6 million to a net loss of $0.7 million due primarily 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 – Nonutility" below.

A significant portion of the volatility in operating results is due to the impact of the accounting methods associated with SJI's derivative activities. The Company uses derivatives to limit its exposure to market risk on transactions to buy, sell, transport and store natural gas and to buy and sell retail electricity. The Company also uses derivatives to limit its exposure to increasing interest rates on variable-rate debt.

The types of transactions that 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 commodity 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.  

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As a result, management also uses the non-generally accepted accounting principles (“non-GAAP”) financial measures of Economic Earnings and Economic Earnings per share when evaluating the results of operations for its nonutility 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, (a) less the change in unrealized gains and plus the change in unrealized losses, as applicable and in each case after tax, on all derivative transactions; (b) less realized gains and plus realized losses, as applicable and in each case after tax, 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; and (c) less the impact of transactions or contractual arrangements where the true economic impact will be realized in a future period. With respect to the third part of the definition of Economic Earnings:

• For the years ended December 31, 2016, 2015 and 2014, Economic Earnings includes additional depreciation expense on a solar generating facility. During 2012, an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and, therefore, the related reduction in depreciation expense is being added back.

• For the year ended December 31, 2015, Economic Earnings includes a pre-tax loss of $2.5 million from affiliated companies that was excluded from Economic Earnings for the year ended December 31, 2014. These adjustments are the result of 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 (see Note 7 to the consolidated financial statements). 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 of 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 for the year ended December 31, 2015.

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 and transactions or contractual arrangements where the true economic impact will be realized in a future period. Specifically, 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. 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 2016 increased $3.9 million, or 3.9%, to $102.8 million compared to 2015, primarily as a result of the following:

• The income contribution from the wholesale energy operations at SJRG increased $2.7 million to $16.3 million, primarily due to additional capacity along with margins earned on gas supply contracts with two electric generation facilities compared to the prior year as described in "Gross Margin - Energy Group" below.

• The income contribution from gas utility operations at SJG increased $2.5 million to $69.1 million, primarily due to the rolling into base rates of SHARP and AIRP investments, along with customer growth, as described under "Margin - Gas Utility Operations" below.

• The income contribution from on-site energy production at Marina increased $1.7 million to $15.7 million, primarily due to the following:

◦ $16.5 million increase due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in 2015 (see Note 7 to the consolidated financial statements), along with other losses incurred at the Energenic operating subsidiaries in 2015.

◦ $9.2 million increase due to several new renewable energy projects that commenced operations over the past twelve months, along with higher prices on SRECs compared to the previous year as discussed in "Gross Margin - Energy Services" below.

◦ $4.5 million increase due to a settlement at Marina in 2016 (see Note 7 to the consolidated financial statements).

◦ $0.7 million increase due to the impact of several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the consolidated financial statements).

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◦ $29.2 million decrease due to the impact of lower renewable energy investments on the investment tax credits available as compared to the prior year. This reduction is consistent with the Company's previously announced strategy of substantially reducing solar development in 2016.

• The net income contribution from SJEX decreased $1.4 million to $0.1 million primarily due to a gain on the sale of a working interest in assets of Potato Creek in 2015, which did not recur in 2016.

Economic Earnings for 2015 decreased $5.0 million, or 4.8%, to $99.0 million compared to 2014, primarily as a result of the following:

• The income contribution from on-site energy production at Marina decreased $10.0 million to $14.0 million due, primarily to the impact of a reduction in the carrying amount of an investment, along with an accrual of the cost to settle a legal claim, at one of Energenic's operating subsidiaries, of which Marina has a 50% equity interest (see Note 7 to the consolidated financial statements). Partially offsetting this decrease is the impact of the investment tax credits available on renewable energy facilities compared to the prior year.

• The income contribution from the wholesale energy operations at SJRG increased $4.5 million to $13.6 million due primarily to higher storage hedge gains and higher daily trading margins, partially offset with lower storage volumes sold compared to the prior year as described in "Gross Margin - Energy Group" below.

The following table presents 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):

	2016			2015			2014
Income from Continuing Operations	$	119,061		$	105,610		$	97,628
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives*	(27,550		)	(8,444		)	7,500
Realized Losses on Inventory Injection Hedges*	683			89			711
Net Loss from Affiliated Companies (A)*	—			(2,540		)	2,540
Other (B)*	(165		)	(165		)	(165		)
Income Taxes (C)	10,813			4,424			(4,235		)
Economic Earnings	$	102,842		$	98,974		$	103,979
Earnings per Share from Continuing Operations (D)	$	1.56		$	1.53		$	1.47
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives*	(0.36		)	(0.12		)	0.11
Realized Losses on Inventory Injection Hedges*	0.01			—			0.01
Net Loss from Affiliated Companies (A)*	—			(0.04		)	0.04
Income Taxes (C)	0.13			0.07			(0.06		)
Economic Earnings per Share (D)	$	1.34		$	1.44		$	1.57

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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):

	2016			2015			2014
Gains (losses) on energy-related commodity contracts	$	26,935		$	8,401		$	(6,592	)
Gains (losses) on interest rate contracts	647			96			(467		)
Total before income taxes	27,582			8,497			(7,059		)
Unrealized mark-to-market losses on derivatives    held by affiliated companies, before taxes	(32		)	(53		)	(441		)
Total unrealized mark-to-market gains (losses) on derivatives*	27,550			8,444			(7,500		)
Realized losses on inventory injection hedges*	(683		)	(89		)	(711		)
Net Loss from Affiliated Companies (A)*	—			2,540			(2,540		)
Other (B)*	165			165			165
Income Taxes (C)	(10,813		)	(4,424		)	4,235
Total reconciling items between income from continuing    operations and Economic Earnings	$	16,219		$	6,636		$	(6,351	)

*Certain reclassifications have been made to the prior period numbers in these tables to conform to the current period presentation. The prior period numbers in these line items have been adjusted to be presented before income taxes.

(A) 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 (see Note 7 to the consolidated financial statements). 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 of 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.

(B) Represents additional depreciation expense within Economic Earnings on a solar generating facility. During 2012, an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and therefore the related reduction in depreciation expense is being added back.

(C) Determined using a combined average statutory tax rate of 40%.

(D) All per share amounts were adjusted for the 2-for-1 stock split, effected in the form of a stock dividend, effective on May 8, 2015. See Note 1 to the consolidated financial statements.

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Throughput - Gas Utility Operations - The following table summarizes the composition of select gas utility data for the years ended December 31 (in thousands, except for customer and degree day data):

	December 31, 2016				December 31, 2015				December 31, 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 Throughput - Utility	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		—
	461,055		100	%	534,290		100	%	501,875		100	%
Less:
Intercompany Sales	7,236				5,527				1,123
Total Utility Operating Revenue	453,819				528,763				500,752

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Less:
Cost of sales	167,154				239,763					230,093
Conservation recoveries *	9,202				21,226					24,836
Remediation Adjustment Clause recoveries *	9,326				9,134					8,255
Energy Efficiency Tracker (EET) recoveries*	2,718				3,611					4,169
Revenue taxes	1,109				1,250					1,141
Utility Margin	$	264,310			$	253,779				$	232,258
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

* Represents expenses for which there is a corresponding credit in operating revenues. Therefore, such recoveries have no impact on our financial results.

** Utility Margin is further defined under the caption "Margin-Gas Utility Operations" below.

*** 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 - Total gas throughput increased 11.6 MMdts, or 8.5%, from 2015 to 2016, primarily due to increases in capacity release. The increase in capacity release volume is primarily related to specific releases made of Columbia pipeline capacity that did not occur in 2015. An increase in third-party supplier deliveries on the Columbia pipeline to SJG’s system freed up capacity at SJG and allowed for additional capacity release of 11.6 MMdts during 2016 compared to 2015. Off-System Sales (OSS) volume also increased 1.9 MMdts, or 13.2%, during 2016 compared to 2015, primarily due to increased opportunity to supply natural gas to gas-fired power generation facilities during the summer months of 2016. These increases were partially offset by a 1.7 MMdts, or 2.9%, decrease in firm throughput, primarily due to weather that was 3% warmer than the previous year.

Total gas throughput decreased 1.5 MMdts, or 1.0%, from 2014 to 2015 due to lower throughput in the firm markets. Residential firm sales and transportation throughput decreased by 1.4 MMdts as a result of weather that was 9.6% warmer than prior year, however, the largest decline in 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 its 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 primarily due to warmer than normal weather, which created less demand in SJG’s service territory and more supply available for OSS.

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Operating Revenues - Gas Utility Operations 2016 vs. 2015 - Revenues decreased $74.9 million, or 14.2%, during 2016 compared with 2015 after eliminating intercompany transactions. Total firm revenue was $75.8 million, or 16.1%, lower in 2016 compared to the prior year due to several factors. Firm throughput was lower during 2016, compared to the prior year, as discussed above under “Throughput - Gas Utility Operations.” The impact of this reduction in throughput lowered SJG’s recovery of natural gas costs through its BGSS mechanism by $38.3 million. In addition, SJG reduced its BGSS rate effective October 1, 2015 and 2016 by 18.6% and 32.9%, respectively, further reducing revenue by $34.7 million during 2016. Finally, SJG provided a $20.0 million and $10.0 million BGSS bill credit to its residential and small commercial customers in January 2016 and December 2016, respectively, of which $28.0 million reduced revenue for 2016, after consideration for sales tax. While changes in natural gas costs and BGSS recoveries/refunds fluctuate from period to period, SJG does not profit from the sale of the commodity. Therefore, fluctuations in Utility Operating Revenue and Cost of Sales, such as those discussed above, did not have an impact on SJG’s profitability. The addition of 4,525 customers in 2016 partially offset the decreases mentioned above. While warmer weather decreased firm sales volume and revenue, the revenue decrease has little impact on SJG profitability under the operation of the CIP, as discussed below under the caption "Margin - Gas Utility Operations."

Higher OSS volumes, discussed above under "Throughput - Gas Utility Operations," resulted in a $2.0 million, or 4.1%, increase in OSS revenues during 2016, compared with 2015. 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. Earnings from OSS can be seen in the "Margin" table above.

Operating Revenues - Gas Utility Operations 2015 vs. 2014 - Revenues increased $28.0 million, or 5.6%, during 2015 compared with 2014 after eliminating intercompany transactions due to higher firm revenue. Total firm revenue increased $31.1 million, or 7.1%, in 2015 as a result of the settlement of SJG’s base rate case and a 22.1% increase in SJG’s periodic BGSS rate, both effective October 1, 2014, as discussed in Note 10 and 11 to the consolidated financial statements. SJG subsequently decreased its periodic BGSS rate by 18.6% effective October 1, 2015; however, the impact of the higher rate in effect for the majority of the year increased revenue by approximately $25.4 million in 2015, compared with 2014. While changes in gas costs and BGSS recoveries/refunds fluctuate from period to period, SJG does not profit from the sale of the commodity. Therefore, corresponding fluctuations in Operating Revenue or Cost of Sales have no impact on SJG profitability, as further discussed below under the caption "Margin - Gas Utility Operations". In addition, the settlement of SJG’s base rate case added $15.5 million of incremental revenue to 2015, compared with 2014. The addition of 6,246 additional customers in 2015 also contributed to higher firm revenue; however, the impact of 9.6% warmer weather more than offset the impact of customer growth during the year. While warmer weather decreased firm sales volume and revenue, the revenue decrease has little impact on SJG profitability under the operation of the CIP, as discussed under the caption "Margin - Gas Utility Operations."    

Operating Revenues - Energy Group 2016 vs. 2015 - Combined revenues for Energy Group, net of intercompany transactions, increased $125.3 million, or 34.8%, to $485.4 million in 2016 compared with 2015.

Revenues from retail gas operations at SJE, net of intercompany transactions, increased $3.7 million, or 4.3%, in 2016 compared with 2015. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(12.2) million, revenues decreased $8.5 million, or 9.3%, in 2016 compared with 2015.

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A summary of SJE's retail gas revenue is as follows (in millions):

	2016			2015		Change
SJE Retail Gas Revenue	$	90.6		$	86.9	$	3.7
Add: Unrealized Losses (Subtract: Unrealized Gains)	(8.2		)	4.0		$	(12.2	)
SJE Retail Gas Revenue, Excluding Unrealized Losses	$	82.4		$	90.9	$	(8.5	)

The decrease in gas revenues, excluding unrealized gains/losses noted above, was primarily due to a 7.7% decrease in the average monthly New York Mercantile Exchange (NYMEX) settle price.

Revenues from retail electric operations at SJE, net of intercompany transactions, increased $30.2 million, or 20.8%, in 2016 compared with 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(2.3) million, revenues increased $27.9 million, or 19.2%, in 2016 compared with 2015.

A summary of SJE's retail electric revenue is as follows (in millions):

	2016			2015		Change
SJE Retail Electric Revenue	$	174.9		$	144.7	$	30.2
Add: Unrealized Losses (Subtract: Unrealized Gains)	(2.2		)	0.1		$	(2.3	)
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains)	$	172.7		$	144.8	$	27.9

The increase in revenues from retail electric operations at SJE, as defined above, was primarily due to a 17.9% increase in sales volumes, which was driven by additional electric contracts entered into during 2016. 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 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 retail electric operations at SJE serve both fixed and market-priced customers.

Revenues from the wholesale energy operations at SJRG, net of intercompany transactions, increased $91.6 million in 2016 compared with 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(3.9) million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.6 million to align them with the related cost of inventory in the period of withdrawal, revenues from the wholesale energy operations at SJRG increased $88.3 million in 2016 compared with 2015.

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A summary of revenues from wholesale energy operations at SJRG is as follows (in millions):

	2016			2015			Change
SJRG Revenue	$	220.7		$	129.1		$	91.6
Add: Unrealized Losses (Subtract: Unrealized Gains)	(16.5		)	(12.6		)	$	(3.9	)
Add:  Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges	0.7			0.1			$	0.6
SJRG Revenue, Excluding Unrealized Losses (Gains) and Realized Losses (Gains) on Inventory Injection Hedges	$	204.9		$	116.6		$	88.3

The increase in revenues from the wholesale energy operations at SJRG, as defined above, was primarily due to revenues earned on gas supply contracts with two electric generation facilities, along with additional capacity, partially offset by a 7.7% decrease in the average monthly NYMEX settle price. As discussed in Note 1 to the consolidated financial statements, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues - Nonutility on the statements of consolidated income.

Operating Revenues - Energy Services 2016 vs. 2015 - Combined revenues for Energy Services, net of intercompany transactions, increased $26.6 million, or 37.6%, to $97.3 million in 2016 compared with 2015.

Revenues from on-site energy production at Marina, net of intercompany transactions, increased $29.9 million, or 50.2%, to $89.4 million in 2016 compared with 2015. These increases were primarily due to higher prices on SREC's compared to the previous periods, an increase in SRECs transferred due to new solar projects and the revenues earned at several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the consolidated financial statements). Solar revenues, net of intercompany transactions, which is included in revenues from on-site energy production above, increased $15.3 million, or 38.5%, to $55.1 million in 2016 compared with 2015.

SRECs represent the renewable energy attribute of the solar electricity generated, which can be sold to customers. Marina does not recognize revenue, or the related margin, until the SREC is certified and transferred to a customer’s electronic account. Customers may purchase SRECs to comply with solar requirements under various state renewable energy regulations. Approximately 76% of Marina’s solar production is in New Jersey.

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 92% and 66% for energy years ending May 31, 2017 and 2018, respectively.

Installed capacity was 198 MW and 135 MW at December 31, 2016 and 2015, respectively.

Revenues from appliance service operations at SJESP, net of intercompany transactions, decreased $3.3 million, or 29.4%, to $7.9 million in 2016 compared with 2015, primarily due to lower installation jobs compared to the prior year.

Operating Revenues - Energy Group 2015 vs. 2014 - Combined revenues for Energy Group, net of intercompany transactions, increased $37.8 million, or 11.7%, to $360.1 million in 2015 compared with 2014.

Revenues from retail gas operations at SJE, net of intercompany transactions, decreased $39.9 million, or 31.5%, in 2015 compared with 2014. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $3.2 million, revenues decreased $36.7 million, or 28.7%, in 2015 compared with 2014.

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A summary of SJE's retail gas revenue is as follows (in millions):

	2015		2014		Change
SJE Retail Gas Revenue	$	86.9	$	126.8	$	(39.9	)
Add: Unrealized Losses (Subtract: Unrealized Gains)	4.0		0.8		3.2
SJE Retail Gas Revenue, Excluding Unrealized Losses	$	90.9	$	127.6	$	(36.7	)

The decrease in gas revenues, excluding unrealized gains/losses noted above, was mainly due to a 39.7% decrease in the average monthly NYMEX settle price, along with a 7.8% decrease in sales volumes compared with 2014. Sales volumes totaled 24,572,554 and 26,664,062 dekatherms for the years ended December 31, 2015 and 2014, respectively.

Revenues from retail electric operations at SJE, net of intercompany transactions, increased $25.7 million, or 21.6%, in 2015 compared with 2014. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(0.8) million, revenues increased $24.9 million, or 20.8%, in 2015 compared with 2014.

A summary of SJE's retail electric revenue is as follows (in millions):

	2015		2014		Change
SJE Retail Electric Revenue	$	144.7	$	119.0	$	25.7
Add: Unrealized Losses (Subtract: Unrealized Gains)	0.1		0.9		(0.8		)
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains)	$	144.8	$	119.9	$	24.9

The increase in revenues from retail electric operations at SJE, as defined above, was mainly due to a 21.8% increase in sales volumes. Partially offsetting the comparative period change was a 7.4% decrease in the average monthly sales price, which was driven by a lower average Locational Marginal Price (LMP) per megawatt hour. 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 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 retail electric operations at SJE serve both fixed and market-priced customers.

Revenues from the wholesale energy operations at SJRG, net of intercompany transactions, increased $52.2 million in 2015 compared with 2014. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(17.5) million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $(0.6) million to align them with the related cost of inventory in the period of withdrawal, revenues from the wholesale energy operations at SJRG increased $34.1 million in 2015 compared with 2014.

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A summary of revenues from wholesale energy operations at SJRG is as follows (in millions):

	2015			2014		Change
SJRG Revenue	$	129.1		$	76.9	$	52.2
Add: Unrealized Losses (Subtract: Unrealized Gains)	(12.6		)	4.9		(17.5		)
Add:  Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges	0.1			0.7		(0.6		)
SJRG Revenue, Excluding Unrealized Losses (Gains) and Realized Losses (Gains) on Inventory Injection Hedges	$	116.6		$	82.5	$	34.1

The increase in revenues from the wholesale energy operations at SJRG as defined above was due mainly to revenues earned on a gas supply contract with an electric generation facility that began operations in the second half of 2014, along with higher storage hedge gains. Partially offsetting these increases was a 17.5% decrease in storage volumes sold. As discussed in Note 1 to the consolidated financial statements, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues - Nonutility on the statements of consolidated income.

Operating Revenues - Energy Services 2015 vs. 2014 - Combined revenues for Energy Services, net of intercompany transactions, increased $6.7 million, or 10.5%, to $70.7 million in 2015 compared with 2014.

Revenues from on-site energy production at Marina, net of intercompany transactions, increased $6.1 million, or 11.3%, to $59.5 million in 2015 compared with 2014 due to several new renewable energy projects that began operations during 2015, along with higher prices on solar renewable energy credits (SRECs) compared to the previous year.

Revenues from appliance service operations at SJESP, net of intercompany transactions, did not change significantly in 2015 compared with 2014.

Margin - Gas Utility Operations - SJG's margin is defined as natural gas revenues less natural gas costs; volumetric and revenue based energy taxes; and regulatory rider expenses. We believe that margin provides a more meaningful basis for evaluating utility operations than revenues since natural gas costs, energy taxes and regulatory rider expenses are passed through to customers, and therefore, have no effect on margin. Natural gas costs are charged to operating expenses on the basis of therm sales at the prices approved by the BPU through the BGSS tariff.

Total margin in 2016 increased $10.5 million, or 4.1%, from 2015. The rolling into base rates of SHARP investments of approximately $36.6 million on October 1, 2015 contributed approximately $3.5 million of additional margin in 2016. In addition, the rolling into base rates of AIRP investments of $74.5 million on December 1, 2016 contributed approximately $1.5 million of additional margin in 2016. Net customer additions of 4,525 over the twelve-month period ended December 31, 2016, representing 1.2% growth over the prior year, contributed approximately $4.0 million in additional margin.

Total Margin in 2015 increased $21.5 million, or 9.3%, from 2014, primarily due to the settlement of the base rate case effective October 1, 2014 and customer additions. The base rate case settlement contributed approximately $15.5 million in additional margin in 2015. Net customer additions of 6,246 over the twelve-month period ended December 31, 2015, representing 1.7% growth over the prior year, contributed approximately $3.7 million in additional margin.

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 margin table above, the CIP mechanism protected $16.6 million, or $9.9 million after taxes, during 2016, due to weather that was 8.1% warmer than average and customer usage variations.

The CIP mechanism reduced margin by $1.8 million, or $1.0 million after taxes, during 2015, primarily due to customer usage variations.

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Gross Margin - Nonutility - Gross margin for the nonutility businesses is defined as revenue less all costs that are directly related to the production, selling and delivery of the Company'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 SJRG are presented on a net basis in Operating Revenues - Nonutility on the statements of consolidated income.

Gross Margin - Energy Group 2016 vs. 2015 - For 2016, combined gross margins for Energy Group, net of intercompany transactions, increased $23.5 million to $80.7 million compared with 2015. This increase is primarily due to the following:

• Gross Margin from SJE's retail gas and other operations increased $11.1 million to $13.5 million in 2016 compared with 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(12.2) million as discussed above, gross margin decreased $1.1 million in 2016 compared with 2015, which does not represent a significant change. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts as discussed above, gross margin as a percentage of Operating Revenues did not change significantly in 2016 compared with 2015.

• Gross Margin from SJE's retail electric operations increased $4.4 million to $10.5 million in 2016 compared with 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(2.3) million as discussed above, gross margin increased $2.1 million in 2016 compared with 2015, primarily due to margins earned on additional electric contracts entered into in 2016. Excluding the impact of the unrealized gains and losses discussed above, gross margin as a percentage of Operating Revenues did not change significantly in 2016 compared with 2015.

• Gross Margin from the wholesale energy operations at SJRG increased $8.1 million to $56.7 million in 2016 compared with 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(3.9) million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.6 million to align them with the related cost of inventory in the period of withdrawal as discussed above, gross margin for SJRG increased $4.8 million. The increase in gross margin was primarily due to additional capacity along with margins earned on gas supply contracts with two 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, 2016, the wholesale energy operations had 7.9 Bcf of storage and 511,587 dts/day of transportation under contract.

Gross Margin - Energy Services 2016 vs. 2015 - For 2016, combined gross margins for Energy Services, net of intercompany transactions, increased $34.1 million to $88.2 million compared with 2015. This increase is primarily due to the following:

• Gross Margin from on-site energy production at Marina increased $34.6 million to $84.0 million in 2016 compared with 2015. Gross margin as a percentage of Operating Revenues increased 10.9 percentage points in 2016 compared with 2015. These increases are primarily due to several higher margin renewable energy projects that began operations over the past twelve months, along with higher prices on SRECs compared to the previous year. Also contributing to the increase were margins earned at several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the consolidated financial statements).

• Gross Margin from the appliance service operations at SJESP did not change significantly in 2016 compared with 2015.

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Gross Margin - Energy Group 2015 vs. 2014 - For 2015, combined gross margins for Energy Group, net of intercompany transactions, increased $25.2 million to $57.2 million compared with 2014. This increase is primarily due to the following:

• Gross Margin from SJE's retail gas and other operations decreased $4.3 million to $2.4 million in 2015 compared with 2014. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $3.2 million as discussed above, gross margin decreased $1.1 million in 2015 compared with 2014. This decrease was primarily due to decreases in sales volumes as discussed in "Operating Revenues-Energy Group" above. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts as discussed above, gross margin as a percentage of Operating Revenues did not change significantly in 2015 compared with 2014.

• Gross margin from SJE's retail electric operations increased $1.6 million to $6.2 million in 2015 compared with 2014. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $(0.8) million as discussed above, gross margin increased $0.8 million in 2015 compared with 2014, which does not represent a significant change. Excluding the impact of the unrealized gains/losses discussed above, gross margin as a percentage of Operating Revenues did not change significantly in 2015 compared with 2014.

• Gross margin from the wholesale energy operations of SJRG increased $28.0 million to $48.7 million in 2015 compared with 2014. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(17.5) million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $(0.6) million to align them with the related cost of inventory in the period of withdrawal as discussed above, gross margin for SJRG increased $9.9 million. The increase in gross margin was mainly due to higher storage hedge gains and higher margins on daily energy trading activities, partially offset with a decrease in storage volumes sold.

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, 2015, the wholesale energy operations had 9.6 Bcf of storage and 442,340 dts/day of transportation under contract.

Gross Margin - Energy Services 2015 vs. 2014 - For 2015, combined gross margins for Energy Services, net of intercompany transactions, increased $6.7 million to $54.0 million compared with 2014. This increase is primarily due to the following:

• Gross Margin from on-site energy production at Marina increased $6.8 million to $49.4 million in 2015 compared with 2014. Gross margin as a percentage of Operating Revenues increased 3.3 percentage points in 2015 compared with 2014. This was due mainly to the impact of several new, higher margin renewable energy projects added during 2015, along with higher prices on SRECs compared to the previous year.

• Gross margin from the appliance service operations at SJESP did not change significantly in 2015 compared with 2014.

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Operations Expense - A summary of net changes in operations expense follows (in thousands):

	2016 vs. 2015			2015 vs. 2014
Gas Utility Operations	$	(12,227	)	$	5,408
Nonutility:
Energy Group:
Wholesale Energy Operations	1,175			1,908
Retail Gas and Other Operations	3,239			(454		)
Retail Electric Operations	(1,778		)	(105		)
Subtotal Energy Group	2,636			1,349
Energy Services:
On-Site Energy Production	11,282			2,422
Appliance Service Operations	(586		)	(290		)
Subtotal Energy Services	10,696			2,132
Total Nonutility	13,332			3,481
Intercompany Eliminations and Other	2,180			(477		)
Total Operations Expense	$	3,285		$	8,412

Gas utility operations expense decreased $12.2 million in 2016 compared with 2015. This decrease was primarily due to lower expenses associated with the New Jersey Clean Energy Program and Energy Efficiency Programs. 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-Gas Utility Operations” above. Also contributing to the decrease from the prior year were expenses associated with write-offs of uncollectible customer accounts receivable, which resulted from fewer customer accounts being eligible to be written off in 2016 as a result of an improvement in the aging of receivables. Gas utility operations expense increased $5.4 million in 2015 compared with 2014. The increase primarily resulted from increases in expenses related to uncollectible customer accounts receivable during 2015 at SJG, as a result of an increase in the aging of receivables following a very cold 2014-2015 winter season. Accounts receivable was higher as of December 31, 2015 due to higher customer billing rates in effect for the majority of 2015 vs. 2014, in addition to customer growth in 2015.

Nonutility operations expense increased $13.3 million in 2016 compared with 2015 primarily due to operating expenses incurred at several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the consolidated financial statements) along with operating expenses at several renewable energy projects that commenced operations over the past twelve months. Also contributing to the increase is additional personnel, governance and compliance costs incurred to support continued growth. Nonutility operations expense increased $3.5 million in 2015 compared with 2014, primarily due to additional personnel, governance and compliance costs incurred to support continued growth.

Other Operating Expenses - A summary of changes in other consolidated operating expenses (in thousands):

	2016 vs. 2015		2015 vs. 2014
Maintenance	$	1,366	$	2,726
Depreciation	$	17,938	$	9,447
Energy and Other Taxes	$	316	$	306

Maintenance Expense - Maintenance expense increased $1.4 million during 2016 compared with 2015 primarily due to increased field activity related to the maintenance of services. Maintenance expense increased $2.7 million during 2015 compared with 2014 primarily due to the BPU-approved amortization and recovery of previously deferred maintenance costs, primarily those associated with a federally-mandated pipeline integrity management program. These amortizations are being recovered through an offsetting amount in revenues. Also contributing to the increase in maintenance expense was increased field activity related to the maintenance of services, along with an increase in Remediation Adjustment Clause (RAC) expense amortization as a result of increased spending on environmental remediation in recent years.

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Depreciation Expense - Depreciation increased $17.9 million in 2016 compared with 2015 primarily due to depreciation incurred at several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the consolidated financial statements), along with increased investment in property, plant and equipment by the gas utility operations at SJG and on-site energy production at Marina. Depreciation increased $9.4 million during 2015 compared with 2014 due mainly to the increased investment in property, plant and equipment by the gas utility operations at SJG and on-site energy production at Marina.

Energy and Other Taxes - The change in energy and other taxes in 2016 and 2015 compared with prior years was not significant.

Other Income and Expense - The change in other income and expense in 2016 compared with 2015 was not significant. Other income and expense decreased $2.3 million in 2015 compared with 2014 primarily due to a realized gain at the gas utility operations at SJG on the sale of available-for-sale securities, along with the settlement of outstanding litigation at SJEX, both of which occurred in 2014 and did not recur in 2015.

Interest Charges - The change in interest charges in 2016 compared with 2015 was not significant. Interest charges increased $2.1 million in 2015 compared with 2014 primarily due to higher amounts of long-term debt outstanding at SJI and SJG, along with lower capitalization of interest costs on construction at the gas utility operations of SJG during 2015. This was a result of the roll-in of capital investments under SJG's AIRP into base rates effective October 1, 2014 and a lower allowance for debt funds used during construction as a result of placing two major technology systems in service during the fourth quarter of 2014. AIRP investments are approved by the BPU to accrue interest on construction until such time they are rolled into base rates.

Income Taxes - Income tax expense increased $52.8 million in 2016 compared with 2015 primarily due to a higher effective tax rate due to a decrease in the investment tax credits available on renewable energy facilities at Marina, along with higher income before income taxes. Income tax expense decreased $3.1 million in 2015 compared with 2014 due to a lower effective tax rate as a result of an increase in the investment tax credits available on renewable energy facilities at Marina in 2015 compared with 2014, partially offset by higher income before income taxes. Investment tax credits from renewable energy facilities at Marina of $9.1 million, $38.3 million and $30.2 million were recognized for the years ended December 31, 2016, 2015 and 2014, respectively.

Equity in Earnings (Loss) of Affiliated Companies - Equity in earnings of affiliated companies increased $33.2 million to earnings of $5.4 million in 2016 compared with 2015 primarily due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in the second quarter of 2015, along with a settlement at Marina in the third quarter of 2016 (see Note 7 to the consolidated financial statements). Equity in loss of affiliated companies increased $20.0 million to a loss of $27.8 million in 2015 compared with 2014 due primarily to the 2015 reduction in the carrying amount of an investment, along with an accrual of the costs of a legal settlement, in the Energenic subsidiaries that operate the central energy center for a hotel, casino and entertainment complex in Atlantic City, New Jersey (see Note 7 to the consolidated financial statements). These were partially offset by a reserve for uncollectible accounts established at one of Energenic's operating subsidiaries during the third quarter of 2014 that did not recur in 2015.

Discontinued Operations - The losses are primarily comprised of environmental remediation and product liability litigation associated with previously disposed of businesses.

LIQUIDITY AND CAPITAL 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 and other regulatory clauses; working capital needs of our 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 - Liquidity needs are first met with net cash provided by operating activities. Net cash provided by operating activities totaled $262.2 million, $186.8 million and $161.3 million in 2016, 2015 and 2014, 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 gas cost recoveries.

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Net cash flow from operating activities increased in 2016 compared to 2015 primarily due to improvements in working capital due to higher customer receivable collections as well as lower gas purchases as a result of the warmer weather experienced during 2016. In addition, SJI did not make a pension payment in 2016. In 2015, SJI made a $15.0 million pension contribution as a result of a decline in the discount rate and new mortality tables released at the end of 2014, both of which negatively impacted the funding status of its pension plans. The Company 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 compensate for that funding shortfall. Partially offsetting the increase was higher spending on environmental remediation at the utility and lower collections under utility regulatory clauses due to warmer weather experienced throughout 2016.

Net cash flow from operating activities increased in 2015 as compared to 2014 primarily as a result of collections of previously deferred gas costs at the utility. Collection of those gas costs had been deferred under the BGSS clause in 2014 as a result of the extremely cold weather experienced during the 2014 winter. This benefit was partially offset by a $15.0 million pension contribution made by SJI as a result of a decline in the discount rate and new mortality tables released at the end of 2014, both of which negatively impacted the funding status of the pension plans. No such contribution was made in 2014. The Company 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 supplant that funding shortfall.

Cash Flows from Investing Activities - SJI has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment. Net cash outflows from investing activities, which are primarily construction projects, for 2016, 2015 and 2014 amounted to $245.2 million, $370.7 million and $375.0 million, respectively. We estimate the net cash outflows for investing activities for 2017, 2018 and 2019 to be approximately $317.4 million, $345.4 million and $293.1 million, respectively.  The high level of investing activities for 2017, 2018 and 2019 is due to a combination of the accelerated infrastructure investment programs and a major pipeline project to support an electric generation facility, both at SJG. Also contributing to the high level of investing activities are potential SJI Midstream investments, net of potential returns, in 2017 through 2019. The Company expects to use short-term borrowings under lines of credit from commercial banks and the commercial paper program to finance these investing activities as incurred. From time to time, the Company may refinance the short-term debt with long-term debt.

In support of its risk management activities, the Company is required to maintain margin accounts with selected counterparties as collateral for its forward contracts, swap agreements, options contracts and futures contracts. These margin accounts are included in Restricted Investments or Margin Account Liability, depending upon the value of the related contracts (the change in the Margin Account Liability is reflected in cash flows from Operating Activities) on the consolidated balance sheets. The required amount of restricted investments changes on a daily basis due to fluctuations in the market value of the related outstanding contracts and is difficult to predict.  Margin posted by the Company decreased by $32.0 million during 2016, decreased by $20.1 million during 2015 and increased by $22.3 million during 2014.

The Company made net investments in unconsolidated affiliates of $7.5 million and $18.0 million in 2016 and 2015, respectively. During 2014, the Company provided net advances to unconsolidated affiliates of $2.4 million.

In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The note bore interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. In December 2015 and February 2016, the borrower exercised each option, respectively. In July 2016, the note was repaid in full, including interest.

Cash Flows from Financing Activities - Short-term borrowings from the commercial paper program and lines of credit from commercial banks are used to supplement cash flows from operations, to support working capital needs and to finance capital expenditures as incurred. From time to time, short-term debt incurred to finance capital expenditures may be refinanced with long-term debt.

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Credit facilities and available liquidity as of December 31, 2016 were as follows (in thousands):

Company	Total Facility		Usage			Available Liquidity		Expiration Date
SJG:
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 SJG	210,000		105,100			104,900
SJI:
Revolving Credit Facility	450,000		196,600		(B)	253,400		Various	(C)
Total SJI	450,000		196,600			253,400
Total	$	660,000	$	301,700		$	358,300

(A) Includes letters of credit outstanding in the amount of $0.8 million.

(B) Includes letters of credit outstanding in the amount of $4.8 million.

(C) In September 2016, the Company entered into an unsecured $50.0 million, 364-day revolving credit agreement. The agreement matures September 2017, at which time the principal and any accrued but unpaid interest must be paid. At the annual request of the Company, but on not more than two occasions, the credit agreement may be extended for an additional period of 364 days. The 364-day revolving facility bears interest at a variable base rate or a variable London Interbank Offered Rate (“LIBOR”), at the Company’s election.

The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary the SJI facilities can also be used to support SJG's liquidity needs. All committed facilities contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements), measured on a quarterly basis. SJI and SJG were in compliance with these covenants as of December 31, 2016. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.47%, 1.13% and 0.83% at December 31, 2016, 2015 and 2014, respectively.  Average borrowings outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $321.9 million and $335.0 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $467.7 million and $471.1 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 facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1, measured at the end of each fiscal quarter. SJI and SJG were in compliance with this covenant as of December 31, 2016.

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 $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 Medium Term Notes (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.

In January 2016, the Company paid $12.7 million to retire outstanding debt of ACB.

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In January 2016, SJG issued $61.0 million of long-term debt on its $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 it was due within one year. In January 2017, SJG issued $200.0 million aggregate principal amount of 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 $200.0 million multiple-draw term facility which was set to expire in June 2017 (see Note 19 to the consolidated financial statements).

As of December 31, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017, are classified in current portion of long-term debt on the consolidated balance sheets. The Company expects to pay off this debt at maturity.

In July 2016, SJG retired $17.0 million of 4.60% MTN's at maturity.

In August 2016, SJG retired $10.0 million of 5.437% MTN's at maturity.

In August 2016, the Company paid an aggregate $8.3 million to retire outstanding long-term debt for ACLE, SCLE and SXLE.

SJG makes payments of $0.9 million annually through December 2025 toward the principal amount of 3.63% MTN's, including a payment made in 2016. 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).

In January 2017, SJG entered into an unsecured, $200.0 million 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 million on January 31, 2017. All loans under the Credit Agreement become due in January 2019.

In June 2015, SJI redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes.

In August 2015, SJG retired $10.0 million aggregate principal amount of 5.387% MTN's at maturity.

In September 2015, SJG issued $80.0 million of long-term debt under a $200.0 million aggregate syndicated bank term facility. The total outstanding amount under this facility as of December 31, 2015 was $139.0 million.

Also in September 2015, SJG redeemed early $0.1 million of the $25.0 million aggregate principal amount variable rate demand bonds that were issued in September 2008. SJG had previously spent all but $0.1 million of the debt proceeds and was permitted under the debt agreement to utilize those remaining funds to redeem the debt early.

In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2020. This agreement replaced existing facilities that expired in October 2015.

In December 2015, SJG filed a petition with the BPU to issue up to $400.0 million of long-term debt securities in various forms including MTN's and unsecured debt, with maturities of more than 12 months, over the next three years. This petition was approved in March 2016.

No other long-term debt was issued or retired during the years ended December 31, 2016 or 2015.

BCLE was considered to be the lessee of certain electric generating units and related facilities and equipment under a capital lease which was set to expire in October 2027. On December 31, 2016, BCLE terminated the lease and purchased the respective assets in the amount of $10.6 million (see Note 9 to the consolidated financial statements).

In May 2016, the Company issued and sold 8,050,000 shares of its common stock, par value $1.25 per share at a public offering, raising net proceeds of approximately $203.6 million. The net proceeds from this offering were or will be used for capital expenditures, primarily for regulated businesses, including infrastructure investments at its utility business.

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Prior to May 1, 2016, SJI raised equity capital through its Dividend Reinvestment Plan (DRP). Shares of common stock offered by the DRP had been issued directly by SJI from its authorized but unissued shares of common stock. SJI raised $10.8 million and $63.2 million of equity capital through the DRP in 2016 and 2015, respectively. Effective May 1, 2016, SJI switched to purchasing shares on the open market to fund share purchases by DRP participants. SJI does not intend to issue any more new equity capital via the DRP in 2017.

SJI's capital structure was as follows:

	As of December 31,
	2016		2015		(A)
Equity	49.1	%	41.6	%
Long-Term Debt	39.6	%	41.1	%
Short-Term Debt	11.3	%	17.3	%
Total	100.0	%	100.0	%

 (A) Certain reclassifications have been made to the prior period consolidated balance sheets to conform to the current period presentation, causing the amounts as of December 31, 2015 to be adjusted. See Note 1 to the consolidated financial statements.

For 2016, 2015 and 2014, SJI paid quarterly dividends to its common shareholders. SJI has paid dividends on its common stock for 65 consecutive years and has increased that dividend each year for the last 17 years. The Company currently seeks to grow that dividend consistent with earnings growth while targeting a payout ratio of between 55% and 70% 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 the Company 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:

ENVIRONMENTAL REMEDIATION - Costs for remediation projects, net of recoveries from ratepayers, for 2016, 2015 and 2014 amounted to net cash outflows of $39.7 million, $22.1 million and $8.3 million, respectively.  Total net cash outflows for remediation projects are expected to be approximately $40.0 million, $31.7 million and $50.6 million for 2017, 2018 and 2019, respectively.  As discussed in Notes 10 and 15 to the consolidated financial statements, certain environmental costs are subject to recovery from ratepayers.

STANDBY LETTERS OF CREDIT — As of December 31, 2016, SJI provided $4.8 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 $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. The Company also provided $87.5 million of additional letters of credit under separate facilities outside of the revolving credit facilities to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.

CONTRACTUAL OBLIGATIONS - SJG and SJRG have certain commitments for both pipeline capacity and gas supply for which they pay fees regardless of usage. Those commitments as of December 31, 2016, average $73.6 million annually and total $494.7 million over the contracts' lives. Approximately 49% of the financial commitments under these contracts expire during the next five years. These contracts are included in the Company's contractual obligations below. We expect to renew each of these contracts under renewal provisions as provided in each contract. SJG recovers all prudently incurred fees through rates via the BGSS clause.

In addition, in the normal course of business, SJG and SJRG have entered into long-term contracts for natural gas supplies.  SJRG has committed to purchase a minimum of 745,000 dts/d and up to 940,000 dts/d of natural gas, from various suppliers, for terms ranging from three 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. The obligations for these purchases have not been included in the Company's contractual obligations discussed below because the actual volumes and prices are not fixed.

47

The following table summarizes our contractual cash obligations and their applicable payment due dates as of December 31, 2016 (in thousands):

			Up to		Years		Years		More than
Contractual Cash Obligations	Total		1 Year		2 & 3		4 & 5		5 Years
Long-Term Debt	$	1,047,482	$	231,909	$	157,818	$	235,818	$	421,937
Interest on Long-Term Debt	240,544		33,655		55,691		38,092		113,106
Construction Obligations	160,532		160,532		—		—		—
Operating Leases	1,126		684		418		24		—
Commodity Supply Purchase Obligations	1,176,938		705,744		236,469		68,122		166,603
Environmental Remediation Costs	155,013		46,120		82,226		6,578		20,089
New Jersey Clean Energy Program	14,969		14,969		—		—		—
Other Purchase Obligations	2,876		2,876		—		—		—
Total Contractual Cash Obligations	$	2,799,480	$	1,196,489	$	532,622	$	348,634	$	721,735

Long-Term Debt in the table above does not include unamortized debt issuance costs of $7.6 million, which were reclassified to Long-Term Debt on the consolidated balance sheets to conform to ASU 2015-03 (see Note 1 to the consolidated financial statements).

Interest on long-term debt in the table above includes the related interest obligations through maturity as well as the impact of all interest rate swap agreements.  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 2016; however, a pension contribution of $10.0 million was made in January 2017. Future pension contributions beyond January 2017 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.

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, 2016, SJI had issued $6.0 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex. 

In June 2014, the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. As of December 31, 2015, the Energenic subsidiaries were providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries had not been able to secure a permanent or long-term energy services agreement with the new owner.

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In 2015, management of the Company and Energenic evaluated the carrying value of the investment in this project and a related note receivable. Based on the inability of the Energenic subsidiaries to secure a permanent or long-term energy services agreement, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge was included in Equity in Loss of Affiliated Companies for the year ended December 31, 2015 on the statements of consolidated income.

The central energy center and energy distribution system owned by the Energenic subsidiaries was financed in part by the issuance of bonds during 2011. These bonds were collateralized primarily by certain assets of the central energy center and revenue from the energy services agreement with the hotel, casino and entertainment complex. During 2015, due to the cessation of normal business operations of the complex and the inability of the Energenic subsidiaries to meet its obligations under the bonds, the trustee for the bondholders filed suit to foreclose on certain assets of the central energy center. In November 2015 during settlement discussions, the bondholders alleged, among other things, that they were entitled to recover from Energenic itself, any amounts owed under the bonds that were not covered by the collateral, including principal, interest and attorney’s fees. The bondholders’ assertion was based on inconsistent language in the bond documents. In January 2016, Energenic and certain subsidiaries reached a multi-party settlement with the bondholders. This agreement resolves all outstanding litigation and transfers ownership of the bondholders’ collateral to the owners of the entertainment complex. The Company's share of this settlement was $7.5 million, which was accrued by Energenic as of December 31, 2015 and paid in 2016. The Company entered into agreements with its insurance carrier and external legal advisors to recover, net of legal costs, approximately $7.0 million of costs associated with the bondholder settlement discussed above. The Company received $2.1 million in the second quarter of 2016, which is included in Other Income on the statements of consolidated income for the year ended December 31, 2016, and $5.3 million was received in the third quarter of 2016 and is included in Equity in Earnings of Affiliated Companies on the statements of consolidated income for the year ended December 31, 2016, as the loss recorded in the prior year was included in this line item on the statements of consolidated income for the year ended December 31, 2015.

As of December 31, 2016, the Company, through its investment in Energenic, had a remaining net asset of approximately $0.6 million included in Investment in Affiliates on the consolidated balance sheets related to cogeneration assets for this project. In addition, the Company had approximately $13.6 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from Energenic, which is secured by those cogeneration assets. This note is subject to a reimbursement agreement that secures reimbursement for the Company, 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 complex and will evaluate the carrying value of the investment and the note receivable as future events occur.

PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary.

The Company is currently involved in a pricing dispute related to two long-term gas supply contracts whereby the Company had sued the supplier to recover amounts that were improperly invoiced. Subsequently, the supplier countersued the Company claiming it is owed an amount which we extrapolate to be $14.9 million from SJG, plus interest, and $40.2 million from SJRG, plus interest, through December 31, 2016. We believe any monies received or paid associated with the SJG claims would reflect gas costs that would be recovered from SJG's customers through adjusted rates.

The Company is also involved in a dispute related to a three-year capacity management contract with a counterparty whereby the Company is the manager. The counterparty is claiming that it is owed approximately $13.3 million, plus interest, from SJRG under a sharing credit within the contract.

Liabilities related to these claims are accrued when the amount or range of amounts of probable settlement costs or other charges for these claims can be reasonably estimated. The Company has accrued approximately $3.1 million and $3.2 million related to all claims in the aggregate as of December 31, 2016 and 2015, respectively. Although the Company does not presently believe that these matters will have a material adverse effect on its business, given the inherent uncertainties in such situations, the Company can provide no assurance regarding the outcome of litigation.

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Item 7A. Quantitative and Qualitative Disclosures about Market Risks

Commodity Market Risks - Certain regulated and nonregulated SJI subsidiaries are involved in buying, selling, transporting and storing natural gas, and buying and selling retail electricity and SREC's, 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 enter into a variety of physical and financial transactions including forward contracts, swaps, futures and options agreements. To manage these transactions, SJI has a well-defined risk management policy approved by our 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.

As part of its gas purchasing strategy, SJG uses financial contracts to hedge against forward price risk. These contracts are recoverable through SJG's BGSS, subject to BPU approval.

The retail gas operations of SJE transact commodities on a physical basis, and SJE typically does not enter into financial derivative positions directly. SJRG manages risk in the natural gas markets for SJE as well as for its own portfolio by entering into the types of transactions noted above. The retail electric operations of SJE 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 the net pre-tax gain (loss) on these contracts of $26.9 million, $8.4 million and $(6.6) million in earnings during 2016, 2015 and 2014, respectively, which are included with realized gains and losses in Operating Revenues - Nonutility.  

The fair value and maturity of these energy-trading contracts determined under the mark-to-market method as of December 31, 2016 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	$	31,042	$	2,952	$	—	$	33,994
Prices provided by other external sources	11,783		31		—		11,814
Prices based on internal models or other valuation methods	29,565		5,329		191		35,085
Total	$	72,390	$	8,312	$	191	$	80,893
Liabilities
Source of Fair Value	Maturity  < 1 Year		Maturity  1 - 3 Years		Maturity Beyond  3 Years		Total
Prices actively quoted	$	16,208	$	262	$	32	$	16,502
Prices provided by other external sources	21,138		932		—		22,070
Prices based on internal models or other valuation methods	22,736		2,601		713		26,050
Total	$	60,082	$	3,795	$	745	$	64,622

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•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 22.6 MMdts with a weighted average settlement price of $3.11 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 141.6 MMdts with a weighted average settlement price of $(0.26) 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. Volumes of our Fixed Price Gas Daily contracts included in the table above under "Prices provided by other external sources" are 16.8 MMdts with a weighted average settlement price of $4.58 per dt.

•Volumes of electric included in the table above under "Prices based on internal models or other valuation methods" are 0.6 million MWh with a weighted average settlement price of $38.84 per MWh.

A reconciliation of SJI's estimated net fair value of energy-related derivatives follows (in thousands):

Net Derivatives - Energy Related Liabilities, January 1, 2016	$	(13,074	)
Contracts Settled During 2016, Net	21,730
Other Changes in Fair Value from Continuing and New Contracts, Net	7,615
Net Derivatives - Energy Related Assets, December 31, 2016	$	16,271

Interest Rate Risk- Our exposure to interest-rate risk relates to short-term and long-term variable-rate borrowings. Variable-rate debt outstanding, including short-term and long-term debt, at December 31, 2016 was $692.2 million and averaged $669.0 million during 2016. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $4.0 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: 2016 - 47 b.p. increase; 2015 - 14 b.p. increase; 2014 - 1 b.p. decrease; 2013 - 16 b.p. decrease; 2012 - 9 b.p. decrease.  At December 31, 2016, our average interest rate on variable-rate debt was 1.49%.

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, the interest costs on $651.4 million of our long-term debt was either at a fixed rate or hedged via an interest rate derivative.

As of December 31, 2016, SJI's active interest rate swaps were as follows:

Notional Amount		Fixed Interest Rate	Start Date	Maturity	Type of Debt	Obligor
$	14,500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	330,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	12,500,000	3.530%	12/1/2006	2/1/2036	Tax-exempt	SJG
$	12,500,000	3.430%	12/1/2006	2/1/2036	Tax-exempt	SJG

Credit Risk - As of December 31, 2016, approximately $9.3 million, or 11.5%, of the current and noncurrent Derivatives – Energy Related Assets are transacted with three counterparties, all of which are investment-grade-rated.

As of December 31, 2016, SJRG had $102.7 million of Accounts Receivable under sales contracts. Of that total, 56% 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.

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Item 8. Financial Statements and Supplementary Data

Statements of Consolidated Income

(In Thousands Except for Per Share Data)

	South Jersey Industries, Inc. and Subsidiaries
	Year Ended December 31,
	2016			2015			2014
Operating Revenues:
Utility	$	453,819		$	528,763		$	500,752
Nonutility	582,681			430,805			386,244
Total Operating Revenues	1,036,500			959,568			886,996
Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility	167,154			239,763			230,093
- Nonutility	413,833			319,579			306,859
Operations	151,957			148,672			140,260
Maintenance	17,549			16,183			13,457
Depreciation	90,389			72,451			63,004
Energy and Other Taxes	6,342			6,026			5,720
Total Operating Expenses	847,224			802,674			759,393
Operating Income	189,276			156,894			127,603
Other Income and Expense	9,989			9,510			11,819
Interest Charges	(31,449		)	(31,622		)	(29,560		)
Income Before Income Taxes	167,816			134,782			109,862
Income Taxes	(54,151		)	(1,360		)	(4,449		)
Equity in Earnings (Loss) of Affiliated Companies	5,396			(27,812		)	(7,785		)
Income from Continuing Operations	119,061			105,610			97,628
Loss from Discontinued Operations - (Net of tax benefit)	(251		)	(503		)	(582		)
Net Income	$	118,810		$	105,107		$	97,046
Basic Earnings per Common Share:
Continuing Operations	$	1.56		$	1.54		$	1.47
Discontinued Operations	—			(0.01		)	(0.01		)
Basic Earnings per Common Share	$	1.56		$	1.53		$	1.46
Average Shares of Common Stock Outstanding - Basic	76,362			68,735			66,278
Diluted Earnings per Common Share:
Continuing Operations	$	1.56		$	1.53		$	1.47
Discontinued Operations	—			(0.01		)	(0.01		)
Diluted Earnings per Common Share	$	1.56		$	1.52		$	1.46
Average Shares of Common Stock Outstanding - Diluted	76,475			68,931			66,428

The accompanying notes are an integral part of the consolidated financial statements. 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. See Note 1.

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Statements of Consolidated Comprehensive Income

(In Thousands)

	South Jersey Industries, Inc. and Subsidiaries
	Year Ended December 31,
	2016			2015			2014
Net Income	$	118,810		$	105,107		$	97,046
Other Comprehensive Income (Loss), Net of Tax:*
Postretirement Liability Adjustment	(3,197		)	5,518			(9,160		)
Unrealized Gain (Loss) on Available-for-Sale Securities	118			(53		)	(472		)
Unrealized Gain on Derivatives - Other	197			321			247
Other Comprehensive Loss of Affiliated Companies	—			(27		)	(113		)
Other Comprehensive (Loss) Income - Net of Tax*	(2,882		)	5,759			(9,498		)
Comprehensive Income	$	115,928		$	110,866		$	87,548

* Determined using a combined average statutory tax rate of 40%.

The accompanying notes are an integral part of the consolidated financial statements.

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Statements of Consolidated Cash Flows (In Thousands)

	South Jersey Industries, Inc. and Subsidiaries
	Year Ended December 31,
	2016			2015			2014
Cash Flows from Operating Activities:
Net Income	$	118,810		$	105,107		$	97,046
Loss from Discontinued Operations	251			503			582
Income from Continuing Operations	119,061			105,610			97,628
Adjustments to Reconcile Income from Continuing Operations to Net Cash Provided by Operating Activities:
Depreciation and Amortization	109,818			91,042			78,511
Net Unrealized (Gain) Loss on Derivatives - Energy Related	(26,935		)	(8,401		)	6,592
Unrealized (Gain) Loss on Derivatives - Other	(647		)	(96		)	467
Provision for Losses on Accounts Receivable	6,907			14,730			9,519
CIP Receivable/Payable	(24,943		)	(7,324		)	15,226
Deferred Gas Costs - Net of Recoveries	11,753			28,648			(44,976		)
Deferred SBC Costs - Net of Recoveries	(7,102		)	9,557			11,048
Stock-Based Compensation Expense	3,892			2,213			1,893
Deferred and Noncurrent Income Taxes - Net	55,789			3,861			1,670
Environmental Remediation Costs - Net	(39,731		)	(22,057		)	(8,265		)
Gas Plant Cost of Removal	(6,070		)	(5,096		)	(4,848		)
Pension Contribution	—			(15,000		)	—
Changes in:
Accounts Receivable	(67,160		)	92,624			(14,323		)
Inventories	387			9,226			(4,787		)
Prepaid and Accrued Taxes - Net	4,253			(9,091		)	(5,822		)
Accounts Payable and Other Accrued Liabilities	112,199			(103,410		)	27,429
Derivatives - Energy Related	6,723			(8,069		)	169
Other Assets and Liabilities	4,090			8,860			(5,444		)
Cash Flows from Discontinued Operations	(44		)	(1,033		)	(355		)
Net Cash Provided by Operating Activities	262,240			186,794			161,332
Cash Flows from Investing Activities:
Capital Expenditures	(278,002		)	(345,621		)	(342,578		)
Purchase of Available for Sale Securities	—			(6,059		)	—
Proceeds from Restricted Investments	1,738			—			—
Proceeds from Sale of Property, Plant and Equipment	—			—			53
Net Proceeds from (Purchase of) Restricted Investments in Margin Accounts	31,971			20,069			(22,337		)
Net Sale of Restricted Investments from Escrowed Loan Proceeds	—			101			—
Investment in Long-Term Receivables	(10,886		)	(19,033		)	(13,024		)
Proceeds from Long-Term Receivables	10,014			8,769			6,544
Notes Receivable	9,916			(9,916		)	—
Purchase of Company-Owned Life Insurance	(2,398		)	(2,328		)	(1,250		)
Acquisition of Subsidiary, Net of Cash Acquired	—			1,394			—
Investment in Affiliate	(12,943		)	(20,229		)	—
Return of Investment in Affiliate	4,750			—			—
Advances on Notes Receivable - Affiliate	—			(2,075		)	(7,521		)
Net Repayment of Notes Receivable - Affiliate	672			4,276			5,094
Net Cash Used in Investing Activities	(245,168		)	(370,652		)	(375,019		)

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Cash Flows from Financing Activities:
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(135,600		)	186,000			(108,200		)
Proceeds from Issuance of Long-Term Debt	61,000			130,000			329,000
Payments for Issuance of Long-Term Debt	(147		)	(64		)	(2,184		)
Principal Repayments of Long-Term Debt	(49,366		)	(125,009		)	(21,000		)
Dividends on Common Stock	(82,380		)	(70,158		)	(63,869		)
Proceeds from Sale of Common Stock	214,426			63,192			80,680
Payment of Lease Obligation	(10,600		)	—			—
Other	—			(397		)	(387		)
Net Cash (Used in) Provided by Financing Activities	(2,667		)	183,564			214,040
Net Increase (Decrease) in Cash and Cash Equivalents	14,405			(294		)	353
Cash and Cash Equivalents at Beginning of Year	3,877			4,171			3,818
Cash and Cash Equivalents at End of Year	$	18,282		$	3,877		$	4,171
Supplemental Disclosures of Cash Flow Information
Cash paid during the year for:
Interest (Net of Amounts Capitalized)	$	32,372		$	30,915		$	28,854
Income Taxes (Net of Refunds)	$	194		$	1,828		$	6,858
Supplemental Disclosures of Non-Cash Investing Activities
Capital Expenditures acquired on account but unpaid as of year-end	$	39,130		$	51,433		$	36,491
Notes Receivable from Affiliate Exchanged for Notes Receivable from a Third Party	$	—		$	16,389		$	—
Notes Receivable Exchanged for Accounts Payable	$	10,168		$	—		$	—

The accompanying notes are an integral part of the consolidated financial statements.

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Consolidated Balance Sheets

(In Thousands)

	South Jersey Industries, Inc. and Subsidiaries
	December 31,
	2016			2015
Assets
Property, Plant and Equipment:
Utility Plant, at original cost	$	2,424,134		$	2,211,239
Accumulated Depreciation	(471,222		)	(440,473		)
Nonutility Property and Equipment, at cost	821,942			785,646
Accumulated Depreciation	(151,084		)	(108,307		)
Property, Plant and Equipment - Net	2,623,770			2,448,105
Investments:
Available-for-Sale Securities	32			14,810
Restricted Investments	13,628			48,758
Investment in Affiliates	28,906			16,983
Total Investments	42,566			80,551
Current Assets:
Cash and Cash Equivalents	18,282			3,877
Accounts Receivable	222,339			178,359
Unbilled Revenues	59,680			40,044
Provision for Uncollectibles	(12,744		)	(10,252		)
Notes Receivable	1,454			11,800
Notes Receivable - Affiliate	2,461			3,134
Natural Gas in Storage, average cost	53,857			54,211
Materials and Supplies, average cost	6,753			5,088
Prepaid Taxes	17,471			21,753
Derivatives - Energy Related Assets	72,391			83,093
Other Prepayments and Current Assets	31,369			40,167
Total Current Assets	473,313			431,274
Regulatory and Other Noncurrent Assets:
Regulatory Assets	410,746			323,434
Derivatives - Energy Related Assets	8,502			16,238
Notes Receivable - Affiliate	13,275			13,275
Contract Receivables	29,037			28,609
Notes Receivable	25,271			35,439
Goodwill	4,838			8,880
Identifiable Intangible Assets	15,820			21,553
Other	83,429			64,575
Total Regulatory and Other Noncurrent Assets	590,918			512,003
Total Assets	$	3,730,567		$	3,471,933

The accompanying notes are an integral part of the consolidated financial statements.

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	2016			2015
Capitalization and Liabilities
Equity:
Common Stock: Par Value $1.25 per share; Authorized 120,000,000 shares; Outstanding Shares: 79,478,055 (2016) and 70,965,622 (2015)
Balance at Beginning of Year	$	88,707		$	85,418
Common Stock Issued or Granted Under Stock Plans	10,640			3,289
Balance at End of Year	99,347			88,707
Premium on Common Stock	706,943			499,460
Treasury Stock (at par)	(266		)	(296		)
Accumulated Other Comprehensive Loss	(27,381		)	(24,499		)
Retained Earnings	510,597			474,167
Total Equity	1,289,240			1,037,539
Long-Term Debt (See Note 1)	808,005			997,427
Total Capitalization	2,097,245			2,034,966
Current Liabilities:
Notes Payable	296,100			431,700
Current Portion of Long-Term Debt	231,909			29,454
Accounts Payable	243,669			186,400
Customer Deposits and Credit Balances	48,068			20,146
Environmental Remediation Costs	46,120			50,559
Taxes Accrued	2,082			2,336
Derivatives - Energy Related Liabilities	60,082			90,708
Derivatives - Other	681			—
Interest Accrued	6,231			7,316
Pension Benefits	2,463			2,261
Other Current Liabilities	15,219			11,596
Total Current Liabilities	952,624			832,476
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	343,549			295,945
Pension and Other Postretirement Benefits	95,235			76,068
Environmental Remediation Costs	108,893			76,064
Asset Retirement Obligations	59,427			57,943
Derivatives - Energy Related Liabilities	4,540			21,697
Derivatives - Other	9,349			10,943
Regulatory Liabilities	49,121			42,841
Other	10,584			22,990
Total Deferred Credits and Other Noncurrent Liabilities	680,698			604,491
Commitments and Contingencies  (Note 15)
Total Capitalization and Liabilities	$	3,730,567		$	3,471,933

The accompanying notes are an integral part of the consolidated financial statements.

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Consolidated Statements of Changes in Equity and Comprehensive Income

(In Thousands)

	South Jersey Industries, Inc. and Subsidiaries
	Years Ended December 31, 2014, 2015 & 2016
		Common Stock		Premium on Common Stock		Treasury Stock			Accumulated Other Comprehensive Loss			Retained Earnings			Total
Balance at January 1, 2014		$	81,788	$	360,303	$	(372	)	$	(20,760	)	$	406,041		$	827,000
Net Income		—		—		—			—			97,046			97,046
Other Comprehensive Loss, Net of Tax (a)		—		—		—			(9,498		)	—			(9,498		)
Common Stock Issued or Granted Under Stock Plans		3,630		78,081		42			—			—			81,753
Cash Dividends Declared - Common Stock ($0.96 per share)		—		—		—			—			(63,869		)	(63,869		)
Balance at December 31, 2014		85,418		438,384		(330		)	(30,258		)	439,218			932,432
Net Income		—		—		—			—			105,107			105,107
Other Comprehensive Income, Net of Tax (a)		—		—		—			5,759			—			5,759
Common Stock Issued or Granted Under Stock Plans		3,289		61,076		34			—			—			64,399
Cash Dividends Declared - Common Stock ($1.02 per share)		—		—		—			—			(70,158		)	(70,158		)
Balance at December 31, 2015		88,707		499,460		(296		)	(24,499		)	474,167			1,037,539
Net Income		—		—		—			—			118,810			118,810
Other Comprehensive Loss, Net of Tax (a)		—		—		—			(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

(a) Determined using a combined average statutory tax rate of 40%.

The accompanying notes are an integral part of the consolidated financial statements. All 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. See Note 1.

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Disclosure of Changes In Accumulated Other Comprehensive Loss Balances (a)

(In Thousands)

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available- for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Accumulated Other Comprehensive Loss
Balance at January 1, 2014	$	(18,503	)	$	(2,697	)	$	397		$	43		$	(20,760	)
Changes During Year	(9,160		)	247			(472		)	(113		)	(9,498		)
Balance at December 31, 2014	(27,663		)	(2,450		)	(75		)	(70		)	(30,258		)
Changes During Year	5,518			321			(53		)	(27		)	5,759
Balance at December 31, 2015	(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	)

(a) Determined using a combined average statutory tax rate of 40%.

The accompanying notes are an integral part of the consolidated financial statements.

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Notes to Consolidated Financial Statements

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries:

▪ South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey.

▪ South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial, industrial and residential customers.

▪ South Jersey Resources Group, LLC (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.

▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include:

• ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey.

• AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.

• MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey.

▪ South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

• SJI Midstream, LLC invests in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.

BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position, operating results and cash flows at the dates and for the periods presented.  

Certain reclassifications have been made to the prior period's consolidated balance sheets, as well as the prior period's long-term debt carrying value and the prior period's segment disclosures in Notes 7 and 8, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the consolidated balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described below under "New Accounting Pronouncements." This reclassification caused the prior periods long-term debt carrying value in Note 7 to be adjusted, along with the prior periods unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 8 to be removed.

On February 26, 2015, the Board of Directors approved an amendment to SJI's Certificate of Incorporation to increase the authorized number of shares of common stock from 60,000,000 shares to 120,000,000 shares. The principal purpose of the increase was to permit a two-for-one split of all the issued shares of SJI's common stock, effected pursuant to a stock dividend of one share of common stock for each outstanding share of common stock, payable May 8, 2015 to shareholders of record at the close of business on April 17, 2015. All references to number of shares and per share information in the consolidated financial statements and related notes have been adjusted for all periods presented to reflect this stock split.

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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 the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. 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. We include 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.  In 2015, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings due to the reduction in the carrying value of an investment in a project entered into by Energenic (see Note 7). No impairment losses were recorded on Investments during 2016 or 2014.

ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (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, and revenue recognition.

REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980 -”Regulated Operations.”  In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities.

OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy-related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. SJRG presents revenues and expenses related to its energy trading activities on a net basis in operating revenues. This net presentation has no effect on operating income or net income. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers.

REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both utility revenue and energy and other taxes and totaled $1.1 million, $1.2 million, and $1.1 million in 2016, 2015 and 2014, respectively.

ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLECTIBLE ACCOUNTS - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts.

NATURAL GAS IN STORAGE – Natural Gas in Storage is reflected at average cost on the consolidated balance sheets, and represents natural gas that will be utilized in the ordinary course of business.

ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.

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ARO activity was as follows (in thousands):

	2016			2015
AROs as of January 1,	$	57,943		$	42,502
Accretion	1,937			1,675
Additions	1,098			802
Settlements	(1,551		)	(1,110		)
Revisions in Estimated Cash Flows (A)	—			14,074
ARO's as of December 31,	$	59,427		$	57,943

(A) The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account. As of December 31, 2016, SJG's utility plant had a gross book value of $2.4 billion, which consists of utility plant assets along with projects for distribution, some of which are part of SJG's Accelerated Infrastructure Replacement Program (AIRP), as discussed in Note 10. As of December 31, 2016, the gross book value of SJI's nonutility property and equipment is $821.9 million, which consists of $652.8 million of solar assets, $124.2 million of cogeneration assets and $44.9 million of other property and equipment.

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 BPU approval. The composite annual rate for all depreciable utility property was approximately 2.2% in each of 2016, 2015 and 2014. 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, 2016, total accumulated deprecation for utility and nonutility property and equipment was $471.2 million and $151.1 million, respectively.

CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in SJG's last base rate proceeding. For SJG's accelerated infrastructure programs, SJG capitalizes interest on construction at a rate prescribed by the programs (see Note 10), and amounts are included in Utility Plant on the consolidated balance sheets. Marina and Midstream capitalize interest on capital projects in progress based on the actual cost of borrowed funds, and amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the statements of consolidated income.  The amount of interest capitalized by SJI for the years ended December 31, 2016, 2015 and 2014 was $6.6 million, $4.9 million and $4.6 million, respectively.

IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the years ended December 31, 2016, 2015 and 2014, no significant impairments were identified.

DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.”  We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause.

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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 Accumulated Other Comprehensive Loss 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.

GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to 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 during the years ended December 31, 2016, 2015 and 2014. As of December 31, 2016 and 2015, $8.8 million and $8.9 million, respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment and Other Noncurrent Assets on the consolidated balance sheets.

TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of December 31, 2016 and 2015, SJI held 212,617 and 236,571 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI.

INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow-through method.

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.

IDENTIFIABLE INTANGIBLE ASSETS - Identifiable intangible assets were acquired as part of the acquisition of Energenic projects as discussed in Note 3 and are a part of the On-Site Energy Production segment. The primary identifiable intangible assets of the Company are customer relationships. The Company determines the useful lives of identifiable intangible assets after considering the specific facts and circumstances related to each intangible asset. Considerations may include the contractual term of any agreement related to the asset, the historical performance of the asset, the Company's long-term strategy for using the asset, any laws or other local regulations which could impact the useful life of the asset, and other economic factors, including competition and specific market conditions. Intangible assets that are deemed to have definite lives (finite-lived intangible assets) are amortized, primarily on a straight-line basis, over their useful lives, generally ranging from 2 to 20 years. The cost of identifiable intangible assets of $15.8 million and $21.6 million are included in Noncurrent Assets on the consolidated balance sheets as of December 31, 2016 and 2015, respectively. The decrease in intangible assets of $5.7 million was attributable to the finalization of the purchase price allocation (see Note 3), which resulted in an adjustment of $4.6 million, along with amortization expense recorded during 2016 of $1.1 million. No amortization was recorded on these assets during 2015.

GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects as discussed in Note 3 and is a part of the On-Site Energy Production segment. Goodwill represents the excess of the consideration paid 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. The Company performed its annual goodwill impairment test in the fourth quarter of 2016 using a qualitative analysis 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 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.The Company concluded based on the results of the annual testing performed that the carrying value of goodwill was not impaired as of December 31, 2016.

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Goodwill of $4.8 million and $8.9 million is included in Noncurrent Assets on the consolidated balance sheets as of December 31, 2016 and 2015, respectively. The following table summarizes the changes in Goodwill for the year ended December 31, 2016 (in thousands):

	2016
Beginning Balance, January 1	$	8,880
Fair Value Adjustments During Measurement Period (See Note 3)	(4,042		)
Ending Balance, December 31	$	4,838

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 of 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. 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, is 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 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 to the new guidance using the modified retrospective approach.

In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results.

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In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis, which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results.

In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's results of operations; however, balance sheet presentations were modified to conform to this guidance, as described under "Basis of Presentation" above.

Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40). This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's financial statement results.

In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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 adoption of this guidance will have on the Company's financial statement results.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which establishes a new lease accounting model for lessees. The new standard requires 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. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2018, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships. The amendments in this guidance clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-07, Investments- Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting, which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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In March 2016, the FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting, which simplifies various aspects of accounting for share-based payment arrangements. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. This standard is intended to provide guidance concerning the classification of certain cash receipts and cash payments in the statement of cash flows and to eliminate the diversity in practice related to such classifications. This standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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 adoption of this guidance will have on the Company's financial statement results.

In November 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash. This standard is intended to reduce diversity in practice in the classification and presentation of changes in restricted cash on the consolidated statement of cash flows. The ASU requires that the consolidated statement of cash flows explain the change in total cash and cash equivalents and amounts generally described as restricted cash or restricted cash equivalents when reconciling the beginning-of-period and end-of-period total amounts. The ASU also requires a reconciliation between the total of cash and equivalents and restricted cash presented on the consolidated statement of cash flows and the cash and cash equivalents balance presented on the consolidated balance sheets. ASU 2016-18 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have 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 adoption of this guidance will have on the Company's financial statement results.

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's financial statement results.

2. STOCK-BASED COMPENSATION PLAN:

On April 30, 2015, the shareholders of SJI approved the adoption of the Company's 2015 Omnibus Equity Compensation Plan (Plan), replacing the Amended and Restated 1997 Stock-Based Compensation Plan that had terminated on January 26, 2015. Under the 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, 2016, 2015 and 2014.   No stock appreciation rights have been issued under the plans. During the years ended December 31, 2016, 2015 and 2014, SJI granted 194,347, 158,929 and 136,526 restricted shares, respectively, to Officers and other key employees under the 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 units granted.

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Beginning in 2015, SJI began granting time-based shares of restricted stock, one-third of which vests annually over a three-year period and is limited to 100% payout. Vesting of time-based grants is contingent upon SJI achieving a return on equity (ROE) of at least 7% during the initial year of the grant and meeting the service requirement. Provided that the 7% ROE requirement is met in the initial year, payout is solely contingent upon the service requirement being met in years two and three of the grant. In 2016 and 2015, Officers and other key employees were granted 58,304 and 47,678 shares of time-based restricted stock, respectively, which are included in the shares noted above.

Grants containing market-based performance targets use SJI's total shareholder return (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.

Through 2014, grants containing earnings-based targets were based on SJI's earnings growth rate per share (EGR) relative to a peer group to measure performance. In 2015, earnings-based performance targets included predefined EGR and ROE goals to measure performance. Beginning in 2016, performance targets include pre-defined compounded earnings annual growth rate (CEGR) for SJI. As EGR-based, ROE-based and CEGR-based grants are contingent upon performance and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant over the requisite three-year period of each award. The fair value is measured as the market price at the date of grant. The initial accruals of compensation expense are based on the estimated number of shares expected to vest, assuming the requisite service is rendered and probable outcome of the performance condition is achieved. That estimate is revised if subsequent information indicates that the actual number of shares is likely to differ from previous estimates. Compensation expense is ultimately adjusted based on the actual achievement of service and performance targets.

SJI granted 35,197, 26,338 and 23,220 restricted shares to Directors in 2016, 2015 and 2014, respectively.  Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.

The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2016, and the assumptions used to estimate the fair value of the awards:

	Grants	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	2015 - TSR	33,537	$	26.31	16.0	%	1.10	%
	2015 - EGR, ROE, Time	73,118	$	29.47	N/A		N/A
	2016 - TSR	66,101	$	22.53	18.1	%	1.31	%
	2016 - CEGR, Time	122,759	23.52		N/A		N/A
Directors -	2016	35,197	$	23.88	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-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.

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The following table summarizes the total stock-based compensation cost for the years ended December 31 (in thousands):

	2016			2015			2014
Officers & Key Employees	$	3,051		$	1,128		$	1,260
Directors	841			769			633
Total Cost	3,892			1,897			1,893
Capitalized	(385		)	(216		)	(147		)
Net Expense	$	3,507		$	1,681		$	1,746

The table above reflects the reversal of approximately $0.1 million, $1.2 million and $1.1 million of previously recorded costs in 2016, 2015 and 2014, respectively. These reversals are associated with EPS-based grants for which performance goals were not met.

As of December 31, 2016, there was $4.0 million of total unrecognized compensation cost related to nonvested stock-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, excluding accrued dividend equivalents:

	Officers & Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2016	226,191		26,338		$	26.89
Granted	194,347		35,197		$	23.28
Vested*	(113,917	)	(26,338	)	$	25.69
Cancelled/Forfeited**	(11,106	)	—		$	25.11
Nonvested Shares Outstanding, December 31, 2016	295,515		35,197		$	24.96

*Based on performance information available at the filing of this Report, management expects to award 29,044 shares associated with the 2014 grants to Officers and other key employees in 2017.

** Represents shares forfeited as a result of separation of employment prior to the satisfaction of service conditions.

Performance targets during the three-year vesting periods were not attained for the 2012 or 2013 Officer and other key employee grants that vested at December 31, 2014 and 2015, respectively. As a result, no shares were awarded in 2015 or 2016 associated with those grants. However, the initial performance hurdle for the 2015 time-based grant was met. As a result, 13,247 shares were awarded to Officers and other key employees in 2016 at a market value of $0.3 million. Also, during the years ended December 31, 2016, 2015 and 2014, SJI granted 35,197, 26,338 and 23,220 shares to its Directors at a market value of $0.8 million, $0.8 million and $0.6 million, respectively. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the Plan. However, a change in control could result in such 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.

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3. AFFILIATIONS AND DISCONTINUED OPERATIONS:

AFFILIATIONS — The following affiliated entities are accounted for under the equity method:

Energenic – US, LLC (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.

On December 31, 2015, Energenic, Marina and its joint venture partner entered into two Equity Distribution and Purchase Agreements (the "Transaction"), pursuant to which Marina became the sole owner of eight of the Energenic projects ("Marina Projects") and its joint venture partner became the sole owner of seven other Energenic projects ("Partner Projects"). The Transaction has been accounted for as a distribution of member interests by Energenic to its owners and a business combination through the exchange of member interests in various projects between Marina and its joint venture partner. In connection with the exchange, the joint venture partner provided a $19.5 million note payable to Marina. The note and other existing obligations of the joint venture partner to Marina are included in Notes Receivable on the consolidated balance sheets, with approximately $1.5 million being included as a current asset as of December 31, 2016 as it is due within one year. This note is collateralized by security interests in various energy project assets owned by the joint venture partner, as well as personal guarantees from its principals.

As part of the transaction, each party is relieved of any guarantees related to the Projects in which it no longer has an ownership interest. 

The projects that are now wholly-owned by Marina are ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS.

Through December 31, 2015, Marina’s investment in Energenic was accounted for under the equity method of accounting. As such, Marina’s share of the equity value of the projects was included within Investment in Affiliates on the consolidated balance sheets and Marina’s share of the loss or earnings from the projects was included within Equity in (Loss) Earnings of Affiliated Companies on the statements of consolidated income for the years ended December 31, 2015 and 2014, respectively. As of December 31, 2015, the assets and liabilities of the projects that are now wholly-owned by Marina are consolidated into the consolidated balance sheets. Beginning in 2016, the respective results from operations and cash flows of the projects that are now wholly-owned by Marina are consolidated into the statements of consolidated income and cash flows, respectively. This transaction represents a non-cash investing and financing activity. The results of the acquired projects are included in the On-Site Energy Production segment.

The following table summarizes the final purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.0 million, which represents the fair value of the Company’s interest in the Partner Projects exchanged ($31.5 million) as well as the existing value of the Marina Projects immediately prior to the exchange ($14.5 million) (in thousands):

Current assets (excluding inventory)	$	7,804
Inventory	3,154
Note Receivable Received	19,504
Fixed Assets	46,460
Intangible Assets:
Identifiable Intangibles	16,950
Goodwill	4,838
Non-Current Assets	4,783
Current Liabilities	(8,196		)
Note Payable - Affiliate	(16,986		)
Long-Term Debt, including current portion	(21,642		)
Capital Lease Payable	(10,458		)
Other Non-Current Liabilities	(181		)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects	$	46,030

The pro forma impact of this transaction on the operations of the Company is not significant.

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Potato Creek, LLC (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 Pipeline Company, LLC (PennEast) - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 100-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, with a target completion of late 2018.

The Company made net investments in unconsolidated affiliates of $7.5 million and $18.0 million in 2016 and 2015, respectively. During 2014, the Company provided net advances to unconsolidated affiliates of $2.4 million.  As of December 31, 2016 and 2015, the outstanding balance of Notes Receivable – Affiliate was $15.7 million and $16.4 million, respectively. As of December 31, 2016, 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, and the remaining $2.1 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, 2016, the Company had a net asset of approximately $28.9 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, 2016 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the aggregate amount of $44.6 million.

DISCONTINUED OPERATIONS - Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (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.

Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts):

	2016			2015			2014
Loss before Income Taxes:
Sand Mining	$	(205	)	$	(422	)	$	(620	)
Fuel Oil	(179		)	(338		)	(274		)
Income Tax Benefits	133			257			312
Loss from Discontinued Operations — Net	$	(251	)	$	(503	)	$	(582	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic and Diluted	$	—		$	(0.01	)	$	(0.01	)

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4. INCOME TAXES:

SJI files a consolidated federal income tax return. State income tax returns are filed on a separate company basis in states where SJI has operations and/or a requirement to file. 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 the following reasons (in thousands):

	2016			2015			2014
Tax at Statutory Rate	$	60,624		$	37,440		$	35,727
Increase (Decrease) Resulting from:
State Income Taxes	6,438			3,985			1,960
ESOP Dividend	(1,300		)	(1,298		)	(1,232		)
Amortization of Investment Tax Credits - Utility	—			(149		)	(211		)
AFUDC	(900		)	(1,109		)	(1,481		)
Investment and Other Tax Credits	(10,706		)	(37,503		)	(30,661		)
Other - Net	(5		)	(6		)	347
Income Taxes:
Continuing Operations	54,151			1,360			4,449
Discontinued Operations	(133		)	(257		)	(312		)
Total Income Tax Expense	$	54,018		$	1,103		$	4,137
The provision for Income Taxes is comprised of the following (in thousands):
	2016			2015			2014
Current:
Federal	$	—		$	—		$	(62	)
State	(1,638		)	(2,352		)	3,052
Total Current	(1,638		)	(2,352		)	2,990
Deferred:
Federal	44,246			(4,622		)	1,707
State	11,543			8,483			(37		)
Total Deferred	55,789			3,861			1,670
Investment Tax Credit - Utility	—			(149		)	(211		)
Income Taxes:
Continuing Operations	54,151			1,360			4,449
Discontinued Operations	(133		)	(257		)	(312		)
Total Income Tax Expense	$	54,018		$	1,103		$	4,137

For the year ended December 31, 2016, the Company's overall tax expense increased primarily due to a decrease in the investment tax credits available on renewable energy facilities at Marina, along with higher income before income taxes.

Investment Tax Credits attributable to SJG are deferred and amortized at the annual rate of 3.0%, which approximates the life of related assets.

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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 at December 31 (in thousands):

	2016		2015
Deferred Tax Assets:
Net Operating Loss Carryforward	$	211,004	$	195,358
Investment and Other Tax Credits	213,946		200,491
Derivatives / Unrealized Gain	—		5,652
Deferred State Tax	28,833		24,833
Pension & Other Post Retirement Benefits	19,351		29,998
Deferred Revenues	7,669		4,924
Provision for Uncollectibles	5,231		4,200
Other	8,368		6,448
Total Deferred Tax Asset	$	494,402	$	471,904
Deferred Tax Liabilities:
Book versus Tax Basis of Property	$	732,535	$	675,521
Deferred Gas Costs - Net	2,052		3,998
Derivatives / Unrealized Loss	1,794		—
Environmental Remediation	32,885		19,207
Deferred Regulatory Costs	1,554		566
Budget Billing - Customer Accounts	3,347		830
Deferred Pension & Other Post Retirement Benefits	34,432		42,216
Conservation Incentive Program	11,846		1,132
Equity In Loss Of Affiliated Companies	3,092		9,111
Other	14,414		15,268
Total Deferred Tax Liability	$	837,951	$	767,849
Deferred Tax Liability - Net	$	343,549	$	295,945

As of December 31, 2016, SJI has the following federal and state net operating loss carryforwards (in thousands):

	Net Operating Loss Carryforwards
Expire in:	Federal		State
2031	$	163,572	$	45,866
2032	42,988		19,356
2033	67,496		34,940
2034	119,122		28,622
2035	70,992		9,860
2036	93,508		81,369
	$	557,678	$	220,013

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As of December 31, 2016, SJI has the following investment tax credit carryforwards (in thousands):

Expire in:	Investment Tax Credit Carryforward
2030	$	11,628
2031	25,664
2032	32,071
2033	45,606
2034	37,699
2035	45,097
2036	11,659
	$	209,424

SJI has $1.2 million of federal alternative minimum tax credits which have no expiration date. SJI also has research and development credits of $3.3 million that will expire between 2031 and 2035. A valuation allowance is recorded when it is more likely than not that any of SJI's deferred tax assets will not be realized. SJI believes that it will generate sufficient future taxable income to realize the income tax benefits related to SJI's net deferred tax assets.

The total unrecognized tax benefits as of December 31, 2016, 2015, and 2014 were $1.4 million, $0.6 million, and $0.6 million, respectively, which excludes $0.7 million, of accrued interest and penalties for each period.

A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands):

	2016		2015		2014
Balance at January 1,	$	559	$	552	$	547
Increase as a result of tax positions taken in prior years	886		7		5
Balance at December 31,	$	1,445	$	559	$	552

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 2016, 2015 or 2014. 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 2013 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.

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6. COMMON STOCK:

The following shares were issued and outstanding at December 31 (See Note 1):

	2016	2015	2014
Beginning of Year	70,965,622	68,334,860	65,430,084
New Issues During Year:
Dividend Reinvestment Plan	417,095	2,604,424	2,881,556
Stock-Based Compensation Plan	45,338	26,338	23,220
Public Equity Offering	8,050,000	—	—
End of Year	79,478,055	70,965,622	68,334,860

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, 2016 of approximately $207.5 million was recorded in Premium on Common Stock.

In May 2016, the Company issued and sold 8,050,000 shares of its common stock, par value $1.25 per share pursuant to a public offering, raising net proceeds of approximately $203.6 million. The net proceeds from this offering were or will be used for capital expenditures, primarily for regulated businesses, including infrastructure investments at its utility business.

EARNINGS PER COMMON SHARE (EPS) — 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 112,590, 195,139, and 150,062 shares for the years ended December 31, 2016, 2015 and 2014, respectively. These shares relate to SJI’s restricted stock as discussed in Note 2.

DIVIDENDS PER SHARE - Dividends per share were $1.07, $1.02 and $0.96 for the years ended December 31, 2016, 2015 and 2014, respectively.

DIVIDEND REINVESTMENT PLAN (DRP) — The Company offered a DRP which allowed participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases, prior to May 1, 2016. Shares of common stock offered by the DRP had been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $10.8 million and $63.2 million of equity capital through the DRP in 2016 and 2015, respectively. Effective May 1, 2016, SJI switched to purchasing shares on the open market to fund share purchases by DRP participants. SJI does not intend to issue any more new equity capital via the DRP in 2017.

7. FINANCIAL INSTRUMENTS:

RESTRICTED INVESTMENTS —Marina is required to maintain escrow accounts related to ongoing capital projects as well as unused loan proceeds pending approval of construction expenditures. As of December 31, 2016 and 2015, the escrowed funds, including interest earned, totaled $1.9 million and $3.4 million, respectively.

The Company maintains margin accounts with selected counterparties to support its 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, 2016 and 2015, the balances in these accounts totaled $11.7 million and $43.7 million, respectively.

As of December 31, 2015, in accordance with an outstanding loan agreement with a third party, ACB was required to maintain control accounts, which included a debt service reserve of $1.7 million. In January 2016, the remaining debt on the loan agreement was paid (see Note 14); accordingly, there was no such reserve as of December 31, 2016.

The carrying amounts of the Restricted Investments approximate their fair values at December 31, 2016 and 2015, which would be included in Level 1 of the fair value hierarchy (see Note 17).

INVESTMENT IN AFFILIATES - During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex.

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In June 2014, the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. As of December 31, 2015, the Energenic subsidiaries were providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries had not been able to secure a permanent or long-term energy services agreement with the new owner.

In 2015, management of the Company and Energenic evaluated the carrying value of the investment in this project and a related note receivable. Based on the inability of the Energenic subsidiaries to secure a permanent or long-term energy services agreement, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge was included in Equity in Loss of Affiliated Companies for the year ended December 31, 2015 on the statements of consolidated income.

The central energy center and energy distribution system owned by the Energenic subsidiaries was financed in part by the issuance of bonds during 2011. These bonds were collateralized primarily by certain assets of the central energy center and revenue from the energy services agreement with the hotel, casino and entertainment complex. During 2015, due to the cessation of normal business operations of the complex and the inability of the Energenic subsidiaries to meet its obligations under the bonds, the trustee for the bondholders filed suit to foreclose on certain assets of the central energy center. In November 2015 during settlement discussions, the bondholders alleged, among other things, that they were entitled to recover from Energenic itself, any amounts owed under the bonds that were not covered by the collateral, including principal, interest and attorney’s fees. The bondholders’ assertion was based on inconsistent language in the bond documents. In January 2016, Energenic and certain subsidiaries reached a multi-party settlement with the bondholders. This agreement resolves all outstanding litigation and transfers ownership of the bondholders’ collateral to the owners of the entertainment complex. The Company's share of this settlement was $7.5 million, which was accrued by Energenic as of December 31, 2015 and paid in 2016. The Company entered into agreements with its insurance carrier and external legal advisors to recover, net of legal costs, approximately $7.0 million of costs associated with the bondholder settlement discussed above. The Company received $2.1 million in the second quarter of 2016, which is included in Other Income on the statements of consolidated income for the year ended December 31, 2016, and $5.3 million was received in the third quarter of 2016 and is included in Equity in Earnings of Affiliated Companies on the statements of consolidated income for the year ended December 31, 2016, as the loss recorded in the prior year was included in this line item on the statements of consolidated income for the year ended December 31, 2015.

As of December 31, 2016, the Company, through its investment in Energenic, had a remaining net asset of approximately $0.6 million included in Investment in Affiliates on the consolidated balance sheets related to cogeneration assets for this project. In addition, the Company had approximately $13.6 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from Energenic, which is secured by those cogeneration assets. This note is subject to a reimbursement agreement that secures reimbursement for the Company, 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 complex and will evaluate the carrying value of the investment and the note receivable as future events occur.

NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The note bore interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. In December 2015 and February 2016, the borrower exercised each option, respectively. In July 2016, the note was repaid in full, including interest.

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 $9.5 million and $12.9 million as of December 31, 2016 and 2015, 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 $0.9 million and $1.3 million as of December 31, 2016 and 2015, respectively.  The annual amortization to interest is not material to the Company’s consolidated financial statements.   The carrying amounts of these receivables approximate their fair value at December 31, 2016 and 2015, which would be included in Level 2 of the fair value hierarchy (see Note 17).

CREDIT RISK - As of December 31, 2016, approximately $9.3 million or 11.5% of current and noncurrent Derivatives–Energy Related Assets are transacted with three counterparties, all of which are investment-grade-rated.

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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 financial instruments approximate their fair values at December 31, 2016 and 2015, except as noted below.

• For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJI 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, including current maturities, as of December 31, 2016 and 2015, were $1,080.8 million and $1,079.0 million, respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of December 31, 2016 and 2015, was $1,039.9 million and $1,026.9 million, respectively. The carrying amounts as of December 31, 2016 and 2015 are net of unamortized debt issuance costs of $7.6 million and $9.0 million, respectively (see Note 1).

OTHER FINANCIAL INSTRUMENTS - The carrying amounts of SJI's other financial instruments approximate their fair values at December 31, 2016 and 2015.

8. SEGMENTS OF BUSINESS:

SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. These segments are as follows:

• Gas utility operations (SJG) consist primarily of natural gas distribution to residential, commercial and industrial customers.

• Wholesale energy operations include the activities of SJRG and SJEX.

• SJE is involved in both retail gas and retail electric activities.

◦ Retail gas and other operations include natural gas acquisition and transportation service business lines.

◦ Retail electric operations 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. Included in this segment are the activities of the following significant entities: ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS. These entities became wholly-owned subsidiaries of Marina on December 31, 2015 (see Note 3).

• Appliance service operations includes SJESP, which services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

• 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. The activities of Midstream are a part of the Corporate and Services segment.

SJI groups its nonutility operations into two 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.  Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices.

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Information about SJI’s operations in different reportable operating segments is presented below (in thousands):

	2016			2015			2014
Operating Revenues:
Gas Utility Operations	$	461,055		$	534,290		$	501,875
Energy Group:
Wholesale Energy Operations	220,707			129,098			77,048
Retail Gas and Other Operations	92,371			87,198			127,001
Retail Electric Operations	182,540			150,049			123,773
Subtotal Energy Group	495,618			366,345			327,822
Energy Services:
On-Site Energy Production	94,375			63,665			56,129
Appliance Service Operations	7,898			11,186			10,518
Subtotal Energy Services	102,273			74,851			66,647
Corporate & Services	35,147			31,156			30,174
Subtotal	1,094,093			1,006,642			926,518
Intersegment Sales	(57,593		)	(47,074		)	(39,522		)
Total Operating Revenues	$	1,036,500		$	959,568		$	886,996

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	2016			2015			2014
Operating Income:
Gas Utility Operations	$	122,455		$	119,585		$	113,690
Energy Group:
Wholesale Energy Operations	41,667			35,024			9,493
Retail Gas and Other Operations	4,680			(3,218		)	479
Retail Electric Operations	7,007			1,042			(466		)
Subtotal Energy Group	53,354			32,848			9,506
Energy Services:
On-Site Energy Production	13,301			2,027			2,560
Appliance Service Operations	582			468			362
Subtotal Energy Services	13,883			2,495			2,922
Corporate and Services	(416		)	1,966			1,485
Total Operating Income	$	189,276		$	156,894		$	127,603
Depreciation and Amortization:
Gas Utility Operations	$	63,901		$	58,668		$	52,155
Energy Group:
Wholesale Energy Operations	484			435			168
Retail Gas and Other Operations	337			161			83
Subtotal Energy Group	821			596			251
Energy Services:
On-Site Energy Production	43,395			30,242			25,020
Appliance Service Operations	301			316			269
Subtotal Energy Services	43,696			30,558			25,289
Corporate and Services	1,400			1,220			816
Total Depreciation and Amortization	$	109,818		$	91,042		$	78,511
Interest Charges:
Gas Utility Operations	$	17,875		$	19,906		$	17,872
Energy Group:
Wholesale Energy Operations	—			441			371
Retail Gas and Other Operations	350			185			267
Subtotal Energy Group	350			626			638
Energy Services:
On-Site Energy Production	11,961			8,169			8,723
Corporate and Services	12,118			11,822			8,803
Subtotal	42,304			40,523			36,036
Intersegment Borrowings	(10,855		)	(8,901		)	(6,476		)
Total Interest Charges	$	31,449		$	31,622		$	29,560

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	2016			2015			2014
Income Taxes:
Gas Utility Operations	$	39,366		$	36,945		$	34,895
Energy Group:
Wholesale Energy Operations	15,882			14,410			4,822
Retail Gas and Other Operations	2,118			(978		)	787
Retail Electric Operations	2,862			426			(190		)
Subtotal Energy Group	20,862			13,858			5,419
Energy Services:
On-Site Energy Production	(6,353		)	(49,225		)	(36,404		)
Appliance Service Operations	232			186			223
Subtotal Energy Services	(6,121		)	(49,039		)	(36,181		)
Corporate and Services	44			(404		)	316
Total Income Taxes	$	54,151		$	1,360		$	4,449
Property Additions:
Gas Utility Operations	$	228,275		$	218,260		$	201,737
Energy Group:
Wholesale Energy Operations	7			382			18
Retail Gas and Other Operations	1,642			2,053			1,421
Subtotal Energy Group	1,649			2,435			1,439
Energy Services:
On-Site Energy Production (1)	38,193			139,018			132,214
Appliance Service Operations	431			379			84
Subtotal Energy Services	38,624			139,397			132,298
Corporate and Services	1,141			1,902			3,995
Total Property Additions	$	269,689		$	361,994		$	339,469

(1) The property additions for On-Site Energy Production in 2016 and 2015 do not include the approximately $5.6 million and $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3.

	2016			2015
Identifiable Assets (See Note 1):
Gas Utility Operations	$	2,551,923		$	2,281,576
Energy Group:
Wholesale Energy Operations	233,019			231,660
Retail Gas and Other Operations	52,729			55,111
Retail Electric Operations	41,280			55,528
Subtotal Energy Group	327,028			342,299
Energy Services:
On-Site Energy Production	767,710			790,231
Appliance Service Operations	2,879			4,885
Subtotal Energy Services	770,589			795,116
Discontinued Operations	1,756			1,545
Corporate and Services	649,795			652,325
Intersegment Assets	(570,524		)	(600,928		)
Total Identifiable Assets	$	3,730,567		$	3,471,933

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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, 2016 and 2015, the carrying costs of this property and equipment under operating lease was $75.9 million and $78.2 million, respectively (net of accumulated depreciation of $31.4 million and $28.5 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, 2016 for each of the next five years and in the aggregate are (in thousands):

Year ended December 31,
2017	$	5,396
2018	5,396
2019	5,396
2020	5,396
2021	5,396
Thereafter	29,230
Total minimum future rentals	56,210

Minimum future rentals do not include additional amounts to be received based on actual use of the leased property.

BCLE was considered to be the lessee of certain electric generating units and related facilities and equipment under a capital lease which was set to expire in October 2027. The interest rate related to the obligation was 6.8%, and the related facilities and equipment were being amortized over the useful life ranging from 7-39 years. As of December 31, 2015, the carrying costs of this property and equipment under capital lease was $4.1 million and was included in Nonutility Property and Equipment in the consolidated balance sheets. On December 31, 2016, BCLE terminated the lease and purchased the respective assets for $10.6 million. Total accumulated depreciation taken on this capital lease, prior to termination, was $0.2 million as of December 31, 2016; no depreciation was taken on this lease by Marina as of December 31, 2015.

10. RATES AND REGULATORY ACTIONS:

BASE RATES - SJG is subject to the rules and regulations of the BPU.  

In September 2014, the BPU granted SJG a base rate increase of $20.0 million, which was predicated, in part, upon a 7.10% rate of return on rate base that included a 9.75% return on common equity.  The $20.0 million includes approximately $7.5 million of revenue associated with previously approved Accelerated Infrastructure Replacement Program (AIRP) investments that were rolled into base rates. SJG was also permitted to recover certain regulatory assets and to reduce its composite depreciate rate from 2.4% to 2.1%. These changes became effective on October 1, 2014.

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. SJG expects the base rate case to be concluded during 2017 (see Note 19).

RATE MECHANISMS - SJG's tariff, a schedule detailing the terms, conditions and rate information applicable to its various types of natural gas service, as approved by the BPU, has several primary rate mechanisms as discussed in detail below:

Basic Gas Supply Service (BGSS) Clause - The BGSS price structure allows SJG to recover all prudently incurred gas costs. BGSS charges to customers can be either monthly or periodic (annual). Monthly BGSS charges are applicable to large use customers and are referred to as monthly because the rate changes on a monthly basis pursuant to a BPU-approved formula based on commodity market prices. Periodic BGSS charges are applicable to lower usage customers, which include all of SJG's residential customers, and are evaluated at least annually by the BPU. However, to some extent, more frequent rate changes to the periodic BGSS are allowed. SJG collects gas costs from customers on a forecasted basis and defers periodic over/under recoveries to the following BGSS year, which runs from October 1 through September 30. If SJG is in a net cumulative undercollected position, gas costs deferrals are reflected on the balance sheet as a regulatory asset. If SJG is in a net cumulative overcollected position, amounts due back to customers are reflected on the balance sheet as a regulatory liability. SJG pays interest on net overcollected BGSS balances at the rate of return on rate base utilized by the BPU to set rates in the last base rate proceeding.

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Regulatory actions regarding the BGSS were as follows:

• January 2014 - SJG credited the accounts of its periodic BGSS customer with refunds totaling $11.2 million due to gas costs that were lower than projected.

• May 2014 - SJG filed its annual BGSS filing with the BPU requesting a $27.0 million, or a 9.3% increase in gas cost recoveries.

• September 2014 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $27.0 million increase in gas cost recoveries.

• June 2015 - SJG filed its annual BGSS filing with the BPU, requesting a $28.4 million decrease in gas cost recoveries.

• September 2015 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $28.4 million decrease in gas cost recoveries.

• 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.

Conservation Incentive Program (CIP) - The primary purpose of the CIP is to promote conservation efforts, without negatively impacting financial stability, and to base SJG's profit margin on the number of customers rather than the amount of natural gas distributed to customers.  Each CIP year begins October 1 and ends September 30 of the subsequent year. On a monthly basis during the CIP year, SJG records adjustments to earnings based on weather and customer usage factors, as incurred. Subsequent to each year, SJG 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.

Regulatory actions regarding the CIP were as follows:

• May 2014 - SJG made its annual CIP filing with the BPU requesting a revenue reduction of $21.8 million, which includes a $4.2 million increase in non-weather related revenues and a $26.0 million reduction in weather related revenues.

• September 2014 - The BPU issued an Order approving, on a provisional basis, the 2014-2015 CIP rates filed in May 2014, effective October 1 2014.

• June 2015 - SJG filed its annual CIP filing with the BPU, requesting a decrease in revenues of $11.3 million, which includes a $8.8 million decrease in non-weather related revenues and a $2.5 million decrease in weather related revenues.

• September 2015 - The BPU issued an Order approving, on a provisional basis, the 2015-2016 CIP rates filed in June 2015, effective October 1, 2015.

• 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.

Accelerated Infrastructure Replacement Program (AIRP) - In February 2013, the BPU issued an Order approving 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. Pursuant to the Order, AIRP investments are to be reviewed and included in rate base in future base rate proceedings.

Regulatory actions regarding AIRP were as follows:

• September 2014 - The BPU approved SJG’s base rate case, which included a $7.5 million increase in revenues associated with the roll in of $69.9 million of AIRP investments, inclusive of $3.2 million of AFUDC, into base rates.

• 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, 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.

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• 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.

Storm Hardening and Reliability Program (SHARP) - In September 2013, SJG filed with the BPU an asset hardening program pursuant to which SJG will invest approximately $280.0 million over seven years to replace low pressure distribution mains and services with high pressure mains and services in coastal areas that are susceptible to flooding during major storm events.

Regulatory actions regarding SHARP were as follows:

• August 2014 - The BPU approved the SHARP, authorizing SJG to invest $103.5 million over three years for system hardening on barrier islands.  SJG will earn a return on these investments as they are made and will reflect the investments in base rates through annual rate adjustments.

• April 2015 - SJG filed a petition seeking a base rate adjustment to increase annual revenues by approximately $4.0 million to reflect approximately $36.6 million of SHARP investments made from July 2014 through June 2015.

• September 2015 - The BPU approved SJG’s request to increase annual revenues from base rates by $4.0 million, effective October 1, 2015.

• 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.

Energy Efficiency Tracker (EET) - Under this program, SJG was permitted to invest $17.0 million over two years in energy efficiency measures to be installed in customer homes and businesses. SJG also recovered incremental operating and maintenance expenses and earn a return of, and return on, program investments. In June 2013, the BPU authorized SJG to continue to offer Energy Efficiency Programs (EEPs) through June 2015 with an approved budget of $24.0 million. In August 2015, the BPU approved a two-year extension of SJG’s EEPs through August 31, 2017, with a program budget of $36.3 million.

Regulatory actions regarding the EET/EEP were as follows:

• May 2014 - SJG filed its annual EET rate adjustment petition requesting a $1.4 million increase in revenues to recover the costs of, and the allowed return on, prior investments associated with energy efficiency programs.

• September 2014 - The BPU approved a revenue increase of $2.2 million associated with the 2012-2013 annual EET rate adjustment filing, with rates effective October 1, 2014.

• January 2015 - SJG filed a petition with the BPU seeking to continue offering energy efficiency programs through June 2018 with a proposed budget of $56.0 million and with the same rate recovery mechanism that exists for its current EEPs.

• June 2015, SJG filed its annual EET rate adjustment petition, requesting a $7.6 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with EEPs.

• August 2015, the BPU approved a two-year extension of SJG's EEPs through August 31, 2017, with a program budget of $36.3 million. The BPU’s approval permitted SJG to adjust its EET rate, effective September 1, 2015, to increase annual revenues by $2.6 million, to recover projected costs and the allowed return on the first year of its investments in the EEP extension.

• 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”) through December 31, 2018, allowing SJG to spend the remainder of its existing BPU approved budget over the extended term. The BPU approved this extension in January 2017.

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Societal Benefits Clause (SBC) - The SBC allows SJG to recover costs related to several BPU-mandated programs. Within the SBC are a Remediation Adjustment Clause (RAC), a New Jersey Clean Energy Program (NJCEP) and a Universal Service Fund (USF) program.

Regulatory actions regarding the SBC, with the exception of USF, which requires separate regulatory filings, were as follows:

• July 2014 - SJG made its annual 2014-2015 SBC filing requesting a $25.7 million decrease in SBC revenues. The BPU approved this filing in May 2015.

• July 2015 - SJG made its annual 2015-2016 SBC filing, requesting a $5.0 million decrease in SBC revenues. The BPU approved this filing in April 2016.

• July 2016 - SJG made its annual 2016-2017 SBC filing, requesting a $16.0 million increase in SBC revenues. This petition is currently pending.

Remediation Adjustment Clause (RAC) - The RAC recovers environmental remediation costs of 12 former gas manufacturing plants (see Note 15). The BPU allows SJG to recover such costs over seven-year amortization periods. The net between the amounts actually spent and amounts recovered from customers is recorded as a regulatory asset, "Environmental Remediation Cost Expended - Net." RAC activity affects revenue and cash flows but does not directly affect earnings because of the cost recovery over seven-year amortization periods. As of December 31, 2016 and 2015, SJG reflected the unamortized remediation costs of $72.0 million and $42.0 million, respectively, on the consolidated balance sheets under Regulatory Assets (see Note 11). Since implementing the RAC in 1992, SJG has recovered $112.7 million through rates.

Clean Energy Program Clause (CLEP) - A component of the SBC, the CLEP recovers costs associated with state mandated NJCEP as it relates to SJG's energy efficiency and renewable energy programs. In June 2013, the BPU approved a NJCEP funding level of $345.0 million through June 2014, of which SJG was responsible for $14.5 million. In June 2014, the BPU approved a NJCEP funding level of $345.0 million through June 2015, of which SJG was responsible for $14.5 million. In June 2015, the BPU approved a NJCEP funding level of $345.0 million through June 2016, of which SJG was responsible for $14.6 million.  In June of 2016, the BPU approved a NJCEP funding level of $345.0 million through June 2017, of which SJG was responsible for $14.6 million.

CLEP 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.

Universal Service Fund (USF) - The USF is a statewide program through which funds for the USF and Lifeline Credit and Tenants Assistance Programs are collected from customers of all New Jersey electric and gas utilities. USF adjustments affect cash flows but do not directly affect revenue or earnings as related costs are deferred and recovered through rates on an on-going basis.

Separate regulatory actions regarding the USF were as follows:

• June 2014 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to increase the statewide gas revenues by $19.9 million. This proposal was designed to increase SJG’s annual USF revenue by $2.6 million.

• September 2014 - The BPU approved the statewide budget of $71.8 million for all the State’s gas utilities.  SJG's portion of the total is approximately $7.9 million, which increased rates effective October 1, 2014, resulting in a $2.6 million increase to its USF recoveries.

• June 2015 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to decrease the statewide gas revenues by $46.4 million. This proposal was designed to decrease SJG’s annual USF revenue by $3.4 million.

• September 2015 - The BPU approved the statewide budget of $46.4 million for all the State’s gas utilities.  SJG's portion of the total is approximately $5.2 million, which decreased rates effective October 1, 2015, resulting in a $3.4 million decrease to its USF recoveries.

• 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.

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Other Regulatory Matters-

Unbundling - This allows all natural gas consumers to select their natural gas commodity supplier. As of December 31, 2016, 33,467 of SJG's customers were purchasing their gas commodity from someone other than 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 utility 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 recovers 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 2014 base rate case, it was permitted to recover previously deferred pipeline integrity costs incurred from October 2010 through June 2014.  In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in the next base rate proceeding, subject to review by the BPU.  As of December 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 11).

Filings and petitions described above are still pending, unless otherwise indicated.

11. REGULATORY ASSETS & REGULATORY LIABILITIES:

The discussion under Note 10, Rates and Regulatory Actions, is integral to the following explanations of specific regulatory assets and liabilities.

Regulatory Assets consisted of the following items (in thousands):

	December 31, 2016		December 31, 2015
Environmental Remediation Costs:
Expended - Net	$	71,997	$	42,032
Liability for Future Expenditures	153,047		123,194
Deferred Asset Retirement Obligation Costs	43,014		42,430
Deferred Pension and Other Postretirement Benefit Costs	85,693		79,779
Deferred Gas Costs - Net	—		2,701
Conservation Incentive Program Receivable	27,567		2,624
Deferred Interest Rate Contracts	7,365		7,631
Energy Efficiency Tracker	219		496
Pipeline Supplier Service Charges	2,122		3,776
Pipeline Integrity Cost	4,810		4,596
AFUDC - Equity Related Deferrals	12,434		11,423
Other Regulatory Assets	2,478		2,752
Total Regulatory Assets	$	410,746	$	323,434

Except where noted below, all regulatory assets are or will be recovered through utility rate charges, as detailed in the following discussion. SJG is currently permitted to recover interest on 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.

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Environmental Remediation Costs - SJG has two regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or its predecessors previously operated gas manufacturing plants. 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 SJG 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.  SJG 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" and "Deferred Credits and Other Noncurrent Liabilities." The BPU allows SJG to recover the deferred costs over seven-year periods after they are spent. The increase from December 31, 2015 is a result of expenditures made during 2016 and an increase in the expected future expenditures for remediation activities, primarily due to an increase in the scope of the remediation at a site related to additional contamination being discovered.

Deferred Asset Retirement Obligation (ARO) Costs - This regulatory asset resulted from the recording of ARO and additional utility plant, primarily related to a legal obligation SJG has for certain safety requirements upon the retirement of its gas distribution and transmission system. SJG recovers asset retirement costs through rates charged to customers. All related accumulated accretion and depreciation amounts for these ARO represent timing differences in the recognition of retirement costs that SJG is currently recovering in rates and, as such, SJG is deferring such differences as regulatory assets.

Deferred Pension and Other Postretirement Benefit Costs - The BPU authorized SJG to recover costs related to postretirement benefits under the accrual method of accounting consistent with GAAP. SJG's regulatory asset represents the recognition of the underfunded positions of SJG'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 Note 12).

Deferred Gas Costs - Net- Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability (see Note 10). Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval (see Note 16).

Conservation Incentive Program Receivable - The impact of the CIP is recorded as an adjustment to earnings as incurred, while cash recovery under the CIP generally occurs during the subsequent CIP year (see Note 10).

Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 16.

Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program.

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 10).

Pipeline Integrity Cost - As part of SJG's September 2014 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2014. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in SJG's next base rate proceeding, subject to review by the BPU (see Note 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 balance is being amortized over the life of the associated utility plant.

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.

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Regulatory Liabilities consisted of the following items (in thousands):

	December 31, 2016		December 31, 2015
Excess Plant Removal Costs	$	28,226	$	32,644
Deferred Revenue - Net	17,800		—
Societal Benefit Costs Payable	3,095		10,197
Total Regulatory Liabilities	$	49,121	$	42,841

Excess Plant Removal Costs- Represents amounts accrued in excess of actual utility plant removal costs incurred to date.  As part of SJG's September 2014 base rate increase, SJG is required to amortize approximately $1.1 million of this balance to depreciation expense each year.

Deferred Revenue - Net - The BGSS changed from a $2.7 million regulatory asset at December 31, 2015 to a $17.8 million regulatory liability at December 31, 2016, primarily due to the gas costs recovered from customers exceeding the actual cost of the commodity. See previous discussion under "Deferred Gas Costs - Net" above.

Societal Benefit Costs Payable - This regulatory liability primarily represents cumulative costs less recoveries under the USF and CLEP programs (see Note 10).

12. PENSION AND OTHER POSTRETIREMENT BENEFITS:

SJI has several defined benefit pension plans and other postretirement benefit plans. Approximately 38.2% of the Company's current, full-time, regular employees will be entitled to annuity payments upon retirement. Participation in the Company's qualified defined benefit pension plans was closed to new employees beginning in 2003; however, employees who are not eligible for these pension plans are eligible to receive an enhanced version of SJI's defined contribution plan. Certain SJI officers also participate in a non-funded supplemental executive retirement plan (SERP), a non-qualified defined benefit pension plan. The other postretirement benefit plans provide health care and life insurance benefits to some retirees.

Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):

	Pension Benefits
	2016			2015			2014
Service Cost	$	4,843		$	5,337		$	4,510
Interest Cost	12,125			11,168			10,735
Expected Return on Plan Assets	(13,508		)	(14,789		)	(13,491		)
Amortizations:
Prior Service Cost	212			212			175
Actuarial Loss	9,394			10,608			5,716
Net Periodic Benefit Cost	13,066			12,536			7,645
Capitalized Benefit Costs	(4,645		)	(4,805		)	(3,047		)
Deferred Benefit Costs	(645		)	(1,007		)	—
Total Net Periodic Benefit Expense	$	7,776		$	6,724		$	4,598

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	Other Postretirement Benefits
	2016			2015			2014
Service Cost	$	851		$	1,116		$	891
Interest Cost	2,615			2,973			2,852
Expected Return on Plan Assets	(3,104		)	(2,993		)	(2,603		)
Amortizations:
Prior Service (Credits) Cost	(344		)	608			152
Actuarial Loss	1,109			1,342			974
Net Periodic Benefit Cost	1,127			3,046			2,266
Capitalized Benefit Costs	(277		)	(1,043		)	(722		)
Deferred Benefit Costs	—			(256		)	—
Total Net Periodic Benefit Expense	$	850		$	1,747		$	1,544

Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to the deferral of incremental expenses associated with the adoption of new mortality tables in 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case.

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 SJG recovers all prudently incurred pension and postretirement benefit costs from its ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this requirement are reported as regulatory assets (see Note 11).

Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands):

	Regulatory Assets						Accumulated Other Comprehensive Loss  (pre-tax)
	Pension Benefits			Other Postretirement Benefits			Pension Benefits			Other Postretirement Benefits
Balance at January 1, 2015	$	71,177		$	27,863		$	39,468		$	6,755
Amounts Arising during the Period:
Net Actuarial (Loss)/Gain	(463		)	(3,155		)	59			(2,285		)
Prior Service Cost				(499		)				(106		)
Amounts Amortized to Net Periodic Costs:
Net Actuarial Loss	(6,079		)	(1,107		)	(4,452		)	(221		)
Prior Service Cost	(203		)	(7,755		)	(9		)	(2,081		)
Balance at December 31, 2015	64,432			15,347			35,066			2,062
Amounts Arising during the Period:
Net Actuarial Gain	9,706			2,584			8,370			829
Prior Service Credit	—			257			—			84
Amounts Amortized to Net Periodic Costs:
Net Actuarial Loss	(5,485		)	(945		)	(3,838		)	(154		)
Prior Service Cost	(203		)	—			(8		)	—
Balance at December 31, 2016	$	68,450		$	17,243		$	39,590		$	2,821

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The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2017 are as follows (in thousands): 

	Pension Benefits		Other Postretirement Benefits
Prior Service Cost/(Credit)	$	127	$	(257	)
Net Actuarial Loss	$	6,202	$	1,040

The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2017 are as follows (in thousands):

	Pension Benefits		Other Postretirement  Benefits
Prior Service Cost/(Credit)	$	5	$	(87	)
Net Actuarial Loss	$	3,943	$	207

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A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands): 

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	$	254,195		$	265,434		$	57,430		$	75,592
Service Cost	4,843			5,337			851			1,116
Interest Cost	12,125			11,168			2,615			2,973
Actuarial Loss (Gain)	18,254			(17,349		)	3,121			(8,591		)
Retiree Contributions	—			—			81			700
Plan Amendments	—			—			—			(9,899		)
Benefits Paid	(11,129		)	(10,395		)	(3,748		)	(4,461		)
Benefit Obligation at End of Year	$	278,288		$	254,195		$	60,350		$	57,430
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	$	184,824		$	180,523		$	47,759		$	43,222
Actual Return on Plan Assets	13,569			(2,321		)	2,784			(423		)
Employer Contributions	2,278			17,017			3,656			8,721
Retiree Contributions	—			—			81			700
Benefits Paid	(11,129		)	(10,395		)	(3,748		)	(4,461		)
Fair Value of Plan Assets at End of Year	$	189,542		$	184,824		$	50,532		$	47,759
Funded Status at End of Year:	$	(88,746	)	$	(69,371	)	$	(9,818	)	$	(9,671	)
Amounts Related to Unconsolidated Affiliate	326			204			540			509
Accrued Net Benefit Cost at End of Year	$	(88,420	)	$	(69,167	)	$	(9,278	)	$	(9,162	)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$	(2,463	)	$	(2,261	)	$	—		$	—
Noncurrent Liabilities	(85,957		)	(66,906		)	(9,278		)	(9,162		)
Net Amount Recognized at End of Year	$	(88,420	)	$	(69,167	)	$	(9,278	)	$	(9,162	)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	$	538		$	741		$	(3,032	)	$	(3,289	)
Net Actuarial Loss	67,912			63,691			20,275			18,636
	$	68,450		$	64,432		$	17,243		$	15,347
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	$	69		$	77		$	(989	)	$	(1,074	)
Net Actuarial Loss	39,521			34,989			3,810			3,136
	$	39,590		$	35,066		$	2,821		$	2,062

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The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of SJI's qualified employee pension plans were $224.3 million and $208.3 million, respectively, as of December 31, 2016; and $207.7 million and $191.9 million, respectively, as of December 31, 2015.  The ABO of these plans exceeded the value of the plan assets as of December 31, 2016 and 2015.  The value of these assets were $189.5 million and $184.8 million as of December 31, 2016 and 2015, respectively, and can be seen in the table above. The PBO and ABO for SJI's non-funded SERP were $53.9 million and $51.9 million, respectively, as of December 31, 2016; and $46.5 million and $45.0 million, respectively, as of December 31, 2015. The SERP obligation is reflected in the tables above and has no assets.

The weighted-average assumptions used to determine benefit obligations at December 31 were:

	Pension Benefits				Other Postretirement Benefits
	2016		2015		2016		2015
Discount Rate	4.30	%	4.83	%	4.13	%	4.73	%
Rate of Compensation Increase	3.50	%	3.50	%	3.50	%	3.50	%

The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were:

	Pension Benefits						Other Postretirement Benefits
	2016		2015		2014		2016		2015		2014
Discount Rate	4.83	%	4.25	%	5.09	%	4.73	%	4.20	%	4.91	%
Expected Long-Term Return on Plan Assets	7.50	%	7.75	%	7.75	%	6.50	%	6.25	%	6.25	%
Rate of Compensation Increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%

In 2014, the Society of Actuaries (SOA) released new mortality tables (RP-2014 base table with MP-2014 generational projection scale), which indicated that the average life expectancy of both active and retired plan participants had increased. Obligations as of December 31, 2014, disclosed herein reflect the use of those new 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, 2016 and 2015, disclosed herein, reflect the use of the updated 2015 tables. While the adoption of the new tables impacts liabilities significantly as of December 31of the year of adoption, the impact on expense did not occur until the subsequent year.

The discount rates used to determine the benefit obligations at December 31, 2016 and 2015, 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'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. 

The retiree medical plan changed effective January 1, 2016. Retirees are provided a fixed contribution to a health reimbursement account, allowing them to obtain coverage from health-care exchanges, rather than utilizing the Company provided health-care plan. Since the health-care benefits are now a fixed dollar amount under the new plan and will not increase in the future, the plan no longer has health care trend assumptions as of December 31, 2015. As a result, assumed health care cost trend rates no longer have a significant effect on the amounts reported for SJI's postretirement health care plans.

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PLAN ASSETS - The Company'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 has implemented this diversification strategy primarily with commingled common/collective trust funds.  The target allocations for pension plan assets are 28-48 percent U.S. equity securities, 13-25 percent international equity securities, 32-42 percent fixed income investments, and 0-7 percent to all other types of investments.  Equity securities include investments in commingled common/collective trust funds as well as large-cap and mid-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.  We 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.

SJI evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2016.  Types of concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, and individual fund.  As of December 31, 2016, there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in SJI's pension and other postretirement benefit plan assets.

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 17, which will serve as the basis for presentation throughout the remainder of this Note.

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The fair values of SJI's pension plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands): 

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2016
Cash / Cash Equivalents:
Cash	$	63	$	63	$	—	$	—
Common/Collective Trust Funds (a)	460		—		460		—
STIF-Type Instrument (b)	1,431		—		1,431		—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	51,902		—		51,902		—
Common/Collective Trust Funds - International (a)	33,096		—		33,096		—
U.S. Large-Cap (c)	17,792		17,792		—		—
U.S. Mid-Cap (c)	2,479		2,479		—		—
International (c)	3,340		3,340		—		—
Fixed Income:
Common/Collective Trust Funds (a)	54,970		—		54,970		—
Guaranteed Insurance Contract (d)	9,714		—		—		9,714
Other types of investments:
Private Equity Fund (f)	5,100		—		—		5,100
Common/Collective Trust Fund - Real Estate (g)	9,195		—		—		9,195
Total	$	189,542	$	23,674	$	141,859	$	24,009

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2015
Cash / Cash Equivalents:
Cash	$	35	$	35	$	—	$	—
Common/Collective Trust Funds (a)	858		—		858		—
STIF-Type Instrument (b)	1,360		—		1,360		—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	52,058		—		52,058		—
Common/Collective Trust Funds - International (a)	33,236		—		33,236		—
U.S. Large-Cap (c)	14,305		14,305		—		—
U.S. Mid-Cap (c)	3,407		3,407		—		—
U.S. Small-Cap (c)	260		260		—		—
International (c)	1,695		1,695		—		—
Fixed Income:
Common/Collective Trust Funds (a)	50,664		—		50,664		—
Guaranteed Insurance Contract (d)	9,960		—		—		9,960
Hedge Funds (e)	4,159		—		—		4,159
Other types of investments:
Private Equity Fund (f)	4,312		—		—		4,312
Common/Collective Trust Fund - Real Estate (g)	8,515		—		—		8,515
Total	$	184,824	$	19,702	$	138,176	$	26,946

(a) 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 markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.

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(b) 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.

(c) 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.

(d) 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.

(e) This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments.

(f) This category represents a limited partnership/commingled trust 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 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments.  Fund investments are illiquid and resale is restricted.  These funds are classified as Level 3 investments.

(g) 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.  Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments.

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Fair Value Measurement Using Significant

Unobservable Inputs (Level 3)

(In thousands)

	Guaranteed						Private
	Insurance			Hedge			Equity			Real
	Contract			Funds			Funds			Estate		Total
Balance at January 1, 2015	$	10,912		$	4,331		$	3,616		$	7,476	$	26,335
Actual return on plan assets:
Relating to assets still held at the reporting date	(106		)	(172		)	(302		)	1,039		459
Relating to assets sold during the period	25			—			429			—		454
Purchases, Sales and Settlements	(871		)	—			569			—		(302		)
Balance at December 31, 2015	9,960			4,159			4,312			8,515		26,946
Actual return on plan assets:
Relating to assets still held at the reporting date	541			(67		)	(140		)	680		1,014
Relating to assets sold during the period	14			—			245			—		259
Purchases, Sales and Settlements	(801		)	(4,092		)	683			—		(4,210		)
Balance at December 31, 2016	$	9,714		$	—		$	5,100		$	9,195	$	24,009

As with the pension plan assets, the Company'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 has 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 30-43 percent U.S. equity securities, 20-30 percent international equity securities, and 32-42 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.

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The fair values of SJI's other postretirement benefit plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands):

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2016:
Cash	$	—	$	—	$	—	$	—
Equity Securities:
Common/Collective Trust Funds - U.S. (a)	$	14,878	$	—	$	14,878	$	—
Common/Collective Trust Funds - International (a)	8,674		—		8,674		—
Fixed Income:
Common/Collective Trust Funds - Bonds (a)	13,537		—		13,537		—
Other Types of Investments:
Company Owned Life Insurance (c)	13,443		—		13,443		—
Total	$	50,532	$	—	$	50,532	$	—
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)	$	13,522	$	—	$	13,522	$	—
Common/Collective Trust Funds - International (a)	8,313		—		8,313		—
Mutual Fund - U.S. (b)	1,309		1,309		—		—
Mutual Funds - International (b)	983		983		—		—
Fixed Income:
Common/Collective Trust Funds - Bonds (a)	13,187		—		13,187		—
Mutual Funds - Bonds (b)	1,441		1,441		—		—
Other Types of Investments:
Mutual Funds - REITS (b)	152		152		—		—
Company Owned Life Insurance (c)	8,826		—		8,826		—
Total	$	47,759	$	3,911	$	43,848	$	—

(a) 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 markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.

(b) 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.

(c) This category represents Company-owned life insurance policies with a nationally known life insurance company. The value of these policies is backed by a series of common/collective trust funds held by the insurance carrier similar to category (a) above. Holdings in these insurance policies are classified as Level 2 investments.

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FUTURE BENEFIT PAYMENTS - The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following years (in thousands):

	Pension Benefits		Other Postretirement Benefits
2017	$	12,141	$	4,399
2018	$	12,583	$	4,316
2019	$	13,529	$	4,403
2020	$	14,056	$	4,514
2021	$	14,757	$	4,511
2022 - 2025	$	86,727	$	21,308

CONTRIBUTIONS - SJI contributed $15.0 million to the pension plans in 2015, with no pension contribution made in 2016 or 2014. Payments related to the unfunded SERP plan in 2016, 2015 and 2014 were $2.3 million, $2.0 million and $1.5 million, respectively. SERP payments are expected to approximate $2.5 million in 2017. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to its other postretirement benefit plans’ trusts, less costs incurred directly by SJG.

DEFINED CONTRIBUTION PLAN - SJI offers an Employees' Retirement Savings Plan (Savings Plan) to eligible employees.  For employees eligible for participation in SJI's defined benefit pension plan, SJI matches 50% of participants' contributions up to 6% of base compensation. For employees who are not eligible for participation in SJI's defined benefit pension plans, SJI matches 50% of participants' contributions up to 8% of base compensation. Employees not eligible for the pension plans also receive a year-end contribution of $1,500, if 10 or fewer years of service, or $2,000, if more than 10 years of service. The amount expensed and contributed for the matching provision of the Savings Plan approximated $2.3 million, $2.1 million and $2.0 million for the years ended December 31, 2016, 2015 and 2014, respectively.

13. LINES OF CREDIT:

Credit facilities and available liquidity as of December 31, 2016 were as follows (in thousands):

Company	Total Facility		Usage			Available Liquidity		Expiration Date
SJG:
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 SJG	210,000		105,100			104,900
SJI:
Revolving Credit Facility	450,000		196,600		(B)	253,400		Various	(C)
Total SJI	450,000		196,600			253,400
Total	$	660,000	$	301,700		$	358,300

(A) Includes letters of credit outstanding in the amount of $0.8 million.

(B) Includes letters of credit outstanding in the amount of $4.8 million.

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(C) In September 2016, the Company entered into an unsecured $50.0 million, 364-day revolving credit agreement. The agreement matures September 2017, at which time the principal and any accrued but unpaid interest must be paid. At the annual request of the Company, but on not more than two occasions, the credit agreement may be extended for an additional period of 364 days. The 364-day revolving facility bears interest at a variable base rate or a variable London Interbank Offered Rate (“LIBOR”), at the Company’s election.

The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.47%, 1.13% and 0.83% at December 31, 2016, 2015 and 2014, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $321.9 million and $335.0 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $467.7 million and $471.1 million, respectively.

The SJI and SJG facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1, measured at the end of each fiscal quarter.

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.

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14. LONG-TERM DEBT:

Outstanding Long-Term Debt at December 31 consisted of the following:

			2016			2015
Long-Term Debt (A):
South Jersey Gas Company:
First Mortgage Bonds: (B)
5.437%		Series due 2016 (C)	$	—		$	10,000
4.6%		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 Bonds at variable rates due 2036 (J)			24,900			24,900
SJG Term Facility (K)			200,000			139,000
Marina Energy LLC:  (L)
Series A 2001 Bonds at variable rates due 2031			20,000			20,000
Series B 2001 Bonds at variable rates due 2021			25,000			25,000
Series A 2006 Bonds at variable rates due 2036			16,400			16,400
South Jersey Industries:
2.71%		Series B 2012 Notes due 2017 (M)	16,000			16,000
3.05%		Series due 2019	60,000			60,000
3.05%		Series due 2019	30,000			30,000
3.05%		Series due 2019	50,000			50,000
3.46%		Series C 2012 Notes due 2022	35,000			35,000
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
ACB Energy Partners, LLC:
7.60	%	Loan & Security Agreement (P)	—			12,735
Other Energy Project Debt (Q):
4.83	%	ACLE	—			3,551
4.83	%	SCLE	—			1,738
4.83	%	SXLE	—			3,433
Total Long-Term Debt Outstanding (R)			$	1,047,482		$	1,035,848
Less Current Maturities			(231,909		)	(29,454		)
Total Long-Term Debt (R)			$	815,573		$	1,006,394

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(A) Long-term debt maturities for the succeeding five years are as follows (in thousands): 2017: $231,909; 2018: $38,909; 2019: $258,909; 2020: $67,909; and 2021: $52,909.

(B) The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. In January 2017, the First Mortgage was amended and restated in its entirety (see Note 19).

(C) In July 2016, SJG retired $17.0 million of 4.60% Medium Term Notes (MTN's) at maturity. In August 2016, SJG retired $10.0 million of 5.437% MTN's at maturity.

(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.

(I) SJG has $50.0 million of 4.01% MTN's with several due dates, as follows: $8.0 million each due November 2018 and 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) These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2016 was 0.74%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August 2018. These bonds contain no financial covenants.

(K) SJG had a $200.0 million multiple-draw term facility offered by a syndicate of banks which was set to expire in June 2017. This facility bore interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of December 31, 2015, SJG had borrowed an aggregate $139.0 million under this facility at an average interest rate of 1.17% and the proceeds were used to pay down short-term debt. In January 2016, SJG issued an additional $61.0 million of long-term debt at an average interest rate of 1.41% under this facility. As such, 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 it was due within one year. In January 2017, this term facility was paid in full (see Note 19).

(L) Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2016 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.72%, 0.73% and 0.72% respectively. The interest rate on all but $46.1 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026.  These bonds contain no financial covenants.  Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March 2018.

(M) As of December 31, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017, are classified in current portion of long-term debt on the consolidated balance sheets. SJI plans to pay off this debt at maturity.

(N) At December 31, 2016, the floating rate on these Senior Notes was 2.32%.

(O) In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2016 was 1.79%.

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(P) ACB had a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million. Under the LSA, ACB paid principal and interest (at a fixed rate of 7.60%) in equal quarterly installments that began in February 2011 and was scheduled to run through February 2021. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In January 2016, the Company paid $12.7 million to retire outstanding debt.

(Q) ACLE, SCLE and SXLE (the "Other Energy Projects") had long-term debt agreements with a third party to borrow up to $10.0 million. Under the debt agreements, the Other Energy Projects paid principal and interest (at a fixed rate of 4.83%) in equal installments that began December 2013 and was scheduled to run through December 2020. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the outstanding debt of $8.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In August 2016, the Company paid an aggregate $8.3 million to retire outstanding long-term debt for the Other Energy Projects.

(R) Total Long-Term Debt in the table above does not include unamortized debt issuance costs of $7.6 million and $9.0 million for the years ended December 31, 2016 and 2015, respectively, which were reclassified to Long-Term Debt on the consolidated balance sheets to conform to ASU 2015-03 (see Note 1).

In December 2015, SJG filed a petition with the BPU to issue up to $400.0 million of long term debt securities in various forms including MTN's and unsecured debt, with maturities of more than 12 months, over the next three years. This petition was approved in March 2016.

15. COMMITMENTS AND CONTINGENCIES:

GAS SUPPLY CONTRACTS - In the normal course of business, SJG and SJRG 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. SJRG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services is approximately $0.5 million per month. SJG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services averages approximately $5.6 million per month and is recovered on a current basis through the BGSS.  SJRG has also committed to purchase a minimum of 745,000 dts/d and up to 940,000 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index based prices.

PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary.

The Company is currently involved in a pricing dispute related to two long-term gas supply contracts whereby the Company had sued the supplier to recover amounts that were improperly invoiced. Subsequently, the supplier countersued the Company claiming it is owed an amount which we extrapolate to be $14.9 million from SJG, plus interest, and $40.2 million from SJRG, plus interest, through December 31, 2016. We believe any monies received or paid associated with the SJG claims would reflect gas costs that would be recovered from SJG's customers through adjusted rates.

The Company is also involved in a dispute related to a three-year capacity management contract with a counterparty whereby the Company is the manager. The counterparty is claiming that it is owed approximately $13.3 million, plus interest, from SJRG under a sharing credit within the contract.

Liabilities related to these claims are accrued when the amount or range of amounts of probable settlement costs or other charges for these claims can be reasonably estimated. The Company has accrued approximately $3.1 million and $3.2 million related to all claims in the aggregate as of December 31, 2016 and 2015, respectively. Although the Company does not presently believe that these matters will have a material adverse effect on its business, given the inherent uncertainties in such situations, the Company can provide no assurance regarding the outcome of litigation.

COLLECTIVE BARGAINING AGREEMENTS— Unionized personnel represent approximately 45.0% of our workforce at December 31, 2016. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76.  SJG and SJESP employees represented by the IBEW operate under collective bargaining agreements that run through February 2018. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017.

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GUARANTEES - As of December 31, 2016, 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 and for Marina's construction and operating activities. As of December 31, 2016, these guarantees support future firm commitments of SJI's consolidated subsidiaries and $125.4 million of the Accounts Payable already recorded on SJI's consolidated balance sheet.

As of December 31, 2016, SJI had issued $6.0 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

STANDBY LETTERS OF CREDIT — As of December 31, 2016, SJI provided $4.8 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 $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. The Company also provided $87.5 million of additional letters of credit under separate facilities outside of the revolving credit facilities to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.

ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage.

SJI successfully entered into settlements with all of its historic comprehensive general liability carriers regarding the environmental remediation expenditures at the SJG sites. Also, SJG had purchased a Cleanup Cost Cap Insurance Policy limiting the amount of remediation expenditures that SJG was required to make at 11 of its sites. This policy provided coverage up to $50.0 million, which was exhausted in 2012.

Since the early 1980s, SJI accrued environmental remediation costs of $437.1 million, of which $282.1 million was spent as of December 31, 2016.

The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands):

	2016			2015
Beginning of Year	$	126,623		$	128,172
Accruals	60,713			19,489
Expenditures	(32,323		)	(21,038		)
End of Year	$	155,013		$	126,623

The balances are segregated between current and noncurrent on the consolidated balance sheets under the captions Current Liabilities and Deferred Credits and Other Noncurrent Liabilities.

Management estimates that undiscounted future costs to clean up SJG's sites will range from $153.0 million to $257.1 million. Six of SJG's 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. SJG recorded the lower end of this range 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. 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 SJG'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.

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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 continued implementation of the approved remedy, 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 is being developed for proposal to the regulatory authority. Steps remaining to remediate the site include selection of a final remedy, 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 - Remedial investigation activities are complete at this site and a final remedy has been approved by the regulatory authority.  Steps remaining to remediate the site include installation of a sub-surface containment unit, post remediation groundwater monitoring, and issuance of a Response Action Outcome.

Site 5 -The remedial action to address impacted soil at the site is ongoing. Steps remaining include long-term groundwater monitoring and issuance of a Response Action Outcome.

Site 6 - Remedial investigation activities have been completed at this site and a final site remedy is being developed for proposal to the regulatory authority. Steps remaining to remediate the site include selection of a final remedy, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy and issuance of a Response Action Outcome.

With Morie's sale in 1996, EMI assumed responsibility for environmental liabilities currently estimated between $1.3 million and $2.1 million. The information available on these sites is sufficient only to establish a range of probable liability and no point within the range is more likely than any other. Therefore, EMI has accrued the lower end of the range. 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 future remediation of five sites where fuel oil operations existed years ago to range from $0.7 million to $1.3 million. The lower end of this range has been recorded under Current Liabilities and Deferred Credits and Other Noncurrent Liabilities as of December 31, 2016.

16. DERIVATIVE INSTRUMENTS:

Certain SJI subsidiaries 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. The Company uses 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, 2016, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 67.9 MMdts of expected future purchases of natural gas, 62.1 MMdts of expected future sales of natural gas, 2.3 MMmwh of expected future purchases of electricity and 1.7 MMmwh of expected future sales of electricity.  In addition to these derivative contracts, the Company has basis and index related purchase and sales contracts totaling 141.6 MMdts.  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. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.

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 gas operations of SJE transact commodities on a physical basis and typically does not directly enter into positions that financially settle. SJRG performs this risk management function for SJE and enters into the types of financial transactions noted above. 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.

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The Company 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 have 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 for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously recorded in Accumulated Other Comprehensive Loss (AOCL) on the consolidated balance sheets, are being recorded into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.

As of December 31, 2016, SJI's active interest rate swaps were as follows:

Notional Amount		Fixed Interest Rate	Start Date	Maturity	Type of Debt	Obligor
$	14,500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	330,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	12,500,000	3.530%	12/1/2006	2/1/2036	Tax-exempt	SJG
$	12,500,000	3.430%	12/1/2006	2/1/2036	Tax-exempt	SJG

The unrealized gains and losses on interest rate derivatives that are not designated as cash flow hedges are included in Interest Charges. 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):

Derivatives not designated as hedging instruments under GAAP	2016				2015
	Assets		Liabilities		Assets		Liabilities
Energy-related commodity contracts:
Derivatives – Energy Related – Current	$	72,391	$	60,082	$	83,093	$	90,708
Derivatives – Energy Related – Non-Current	8,502		4,540		16,238		21,697
Interest rate contracts:
Derivatives - Other - Current	—		681		—		—
Derivatives - Other - Non-Current	—		9,349		—		10,943
Total derivatives not designated as hedging instruments under GAAP	80,893		74,652		99,331		123,348
Total Derivatives	$	80,893	$	74,652	$	99,331	$	123,348

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The Company enters into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. The Company presents derivatives at gross fair values on the consolidated balance sheets. As of December 31, 2016 and2015, information related to these offsetting arrangements were as follows (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	$	80,893		$	—	$	80,893		$	(38,809	)	(A)	$	(3,474	)	$	38,610
Derivatives - Energy Related Liabilities	$	(64,622	)	$	—	$	(64,622	)	$	38,809		(B)	$	—		$	(25,813	)
Derivatives - Other	$	(10,030	)	$	—	$	(10,030	)	$	—			$	—		$	(10,030	)

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	$	99,331		$	—	$	99,331		$	(35,491	)	(A)	$	—	$	63,840
Derivatives - Energy Related Liabilities	$	(112,405	)	$	—	$	(112,405	)	$	35,491		(B)	$	23,045	$	(53,869	)
Derivatives - Other	$	(10,943	)	$	—	$	(10,943	)	$	—			$	—	$	(10,943	)

(A) The balances at December 31, 2016 and 2015 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at December 31, 2016 and 2015 were related to derivative assets which can be net settled against derivative liabilities.

The effect of derivative instruments on the statements of consolidated income and comprehensive income for the year ended December 31 is as follows (in thousands):

Derivatives in Cash Flow Hedging Relationships	2016			2015			2014
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	—		$	—
Losses reclassified from AOCL into income (a)	$	(333	)	$	(551	)	$	(419	)
Losses recognized in income on ineffective portion (a)	$	—		$	—		$	—

(a) Included in Interest Charges

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Derivatives Not Designated as Hedging Instruments under GAAP	2016		2015		2014
Gains (losses) on energy-related commodity contracts (a)	$	26,935	$	8,401	$	(6,592	)
Gains (losses) on interest rate contracts (b)	647		96		(467		)
Total	$	27,582	$	8,497	$	(7,059	)

(a)  Included in Operating Revenues - Nonutility

(b)  Included in Interest Charges

Net realized (losses) gains associated with SJG’s energy-related financial commodity contracts of $(3.0) million, $(9.1) million and $1.7 million for the years ended 2016, 2015 and 2014, respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy-related financial commodity contracts are deferred in Regulatory Assets or Liabilities, as applicable, and there is no impact on earnings.

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, 2016, is $9.6 million.  If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2016, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $8.1 million after offsetting asset positions with the same counterparties under master netting arrangements.

17. FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES:

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	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	32	$	32	$	—	$	—
Derivatives – Energy Related Assets (B)	80,893		33,994		11,814		35,085
	$	80,925	$	34,026	$	11,814	$	35,085
Liabilities
Derivatives – Energy Related Liabilities (B)	$	64,622	$	16,502	$	22,070	$	26,050
Derivatives – Other (C)	10,030		—		10,030		—
	$	74,652	$	16,502	$	32,100	$	26,050

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As of December 31, 2015	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	14,810	$	2,925	$	11,885	$	—
Derivatives – Energy Related Assets (B)	99,331		16,006		24,730		58,595
	$	114,141	$	18,931	$	36,615	$	58,595
Liabilities
Derivatives – Energy Related Liabilities (B)	$	112,405	$	42,170	$	11,008	$	59,227
Derivatives – Other (C)	10,943		—		10,943		—
	$	123,348	$	42,170	$	21,951	$	59,227

(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 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.

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The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands, except for ranges):

Type	Fair Value at December 31, 2016				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	23,301	$	18,109	Discounted Cash Flow	Forward price (per dt)	$1.03 - $11.33 [$2.71]	(A)
Forward Contract - Electric	$	11,784	$	7,941	Discounted Cash Flow	Fixed electric load profile (on-peak)	21.43% - 100.00% [55.14%]	(B)
						Fixed electric load profile (off-peak)	0.00% - 78.57% [44.86%]	(B)

Type	Fair Value at December 31, 2015				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	29,459	$	31,733	Discounted Cash Flow	Forward price (per dt)	$(0.77) - $10.00 [$2.15]	(A)
Forward Contract - Electric	$	29,136	$	27,494	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.47% - 100.00% [56.20%]	(B)
						Fixed electric load profile (off-peak)	0.00% - 91.53% [43.80%]	(B)

(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, 2016 and 2015, using significant unobservable inputs (Level 3), are as follows (in thousands):

	Year Ended December 31, 2016
Balance at January 1, 2016	$	(632	)
Other changes in fair value from continuing and new contracts, net	5,657
Transfers in to/(out of) of Level 3 (A)	4,116
Settlements	(106		)
Balance at December 31, 2016	$	9,035

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	Year Ended December 31, 2015
Balance at January 1, 2015	$	(5,608	)
Other changes in fair value from continuing and new contracts, net	(5,069		)
Transfers in to/(out of) of Level 3 (A)	7,402
Settlements	2,643
Balance at December 31, 2015	$	(632	)

(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.  During the years ended December 31, 2016 and 2015, $4.1 million and $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management.

Total gains for 2016 included in earnings for the year ended December 31, 2016 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, 2016, are $5.7 million.  These gains are included in Operating Revenues-Nonutility on the statements of consolidated income.

18. ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL):

The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2016 (in thousands):

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Total
Balance at January 1, 2016 (a)	$	(22,145	)	$	(2,129	)	$	(128	)	$	(97	)	$	(24,499	)
Other comprehensive income before reclassifications	(5,617		)	—			323			—			(5,294		)
Amounts reclassified from AOCL (b)	2,420			197			(205		)	—			2,412
Net current period other comprehensive income	(3,197		)	197			118			—			(2,882		)
Balance at December 31, 2016 (a)	$	(25,342	)	$	(1,932	)	$	(10	)	$	(97	)	$	(27,381	)

(a) Determined using a combined average statutory tax rate of 40%.

(b) See table below.

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The following table provides details about reclassifications out of AOCL for the year ended December 31, 2016 (in thousands):

	Amounts Reclassified from AOCL			Affected Line Item in the Statements of Consolidated Income
	For the Year Ended December 31, 2016
Actuarial Loss on Postretirement Benefits	$	4,001		Operating Expenses: Operations
Income Taxes	(1,581		)	Income Taxes (a)
	$	2,420
Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	333		Interest Charges
Income Taxes	(136		)	Income Taxes (a)
	$	197
Unrealized Gain on Available-for-Sale Securities	$	(342	)	Other Income
Income Taxes	137			Income Taxes (a)
	$	(205	)
Losses from reclassifications for the period net of tax	$	2,412

(a) Determined using a combined average statutory tax rate of 40%.

19. SUBSEQUENT EVENTS:

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 (see Note 14). The New Mortgage 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.

In January 2017, SJG issued $200.0 million aggregate principal amount of MTN's, Series E, 2017, due January 2047, with principal payments beginning in 2025. The MTN's bear interest at an annual rate of 3.0% payable semiannually. Proceeds were used to pay down the $200.0 million multiple-draw term facility which was set to expire in June 2017.

In January 2017, SJG entered into an unsecured, $200.0 million 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 million on January 31, 2017. All loans under the Credit Agreement become due in January 2019.     

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. SJG expects the base rate case to be concluded during 2017.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

South Jersey Industries, Inc.

Folsom, New Jersey

We have audited the accompanying consolidated balance sheets of South Jersey Industries, Inc. and subsidiaries (the "Company") as of December 31, 2016 and 2015, and the 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, 2016. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of South Jersey Industries, Inc. and subsidiaries as of December 31, 2016 and 2015, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2016, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company's internal control over financial reporting as of December 31, 2016, based on the criteria established in Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2017 expressed an unqualified opinion on the Company's internal control over financial reporting.

/s/ Deloitte & Touche LLP

Philadelphia, Pennsylvania

February 27, 2017

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Quarterly Financial Data (Unaudited)

(Summarized quarterly results of SJI's operations, in thousands except for per share amounts)

	2016 Quarter Ended												2015 Quarter Ended
	March 31			June 30			Sept. 30			Dec. 31			March 31			June 30			Sept. 30			Dec. 31
Operating Revenues	$	333,035		$	154,402		$	219,082		$	329,981		$	382,952		$	177,710		$	141,062		$	257,844
Expenses:
Cost of Sales - (Excluding depreciation)	152,975			98,340			142,988			186,684			241,707			90,945			99,124			127,566
Operations and Maintenance Including Fixed Charges	73,042			71,034			69,410			77,858			71,279			62,634			63,867			71,148
Income Taxes	39,267			(7,189		)	2,807			19,266			16,613			(3,279		)	(10,968		)	(1,006		)
Energy and Other Taxes	1,925			1,243			1,449			1,725			2,196			1,265			1,231			1,334
Total Expenses	267,209			163,428			216,654			285,533			331,795			151,565			153,254			199,042
Other Income and Expense	2,361			4,228			7,236			1,560			2,696			(12,804		)	(340		)	(7,854		)
Income (Loss) from Continuing Operations	68,187			(4,798		)	9,664			46,008			53,853			13,341			(12,532		)	50,948
Loss from Discontinued Operations  -  (Net of tax benefit)	(118		)	(29		)	(29		)	(75		)	(276		)	(74		)	(91		)	(62		)
Net Income (Loss)	$	68,069		$	(4,827	)	$	9,635		$	45,933		$	53,577		$	13,267		$	(12,623	)	$	50,886
Basic Earnings Per Common Share:
Continuing Operations	$	0.96		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Discontinued Operations	—			—			—			—			—			—			—			—
Basic Earnings Per Common Share	$	0.96		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Average Shares of Common Stock Outstanding - Basic	71,127			75,298			79,478			79,478			68,397			68,467			68,607			69,460
Diluted Earnings Per Common Share:
Continuing Operations	$	0.95		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Discontinued Operations	—			—			—			—			—			—			—			—
Diluted Earnings Per Common Share	$	0.95		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Average Shares of Common Stock Outstanding - Diluted	71,416			75,298			79,635			79,643			68,618			68,653			68,607			69,646

The sum of the quarters for basic and diluted earnings per common share for 2016 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 to the consolidated financial statements). The sum of the quarters for basic and diluted earnings per common share for 2015 does not equal the year's total due to rounding.

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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. See Note 1 to the consolidated financial statements.

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, with the participation of its chief executive officer and chief financial officer, evaluated the effectiveness of the design and operation of the Company's disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) as of December 31, 2016. Based on that evaluation, the Company's chief executive officer and chief financial officer concluded that the disclosure controls and procedures employed at the Company are effective.

Management's Report on Internal Control over Financial Reporting

Management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined under Exchange Act Rule 13a-15(f). The Company's internal control system is designed to provide reasonable assurance to its management and board of directors regarding the preparation and fair presentation of published financial statements.Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework (2013 Framework) issued by the Committee of Sponsoring Organizations of the Treadway Commission.  Based on our evaluation under that framework, management concluded that our internal control over financial reporting was effective as of December 31, 2016.

The effectiveness of our internal control over financial reporting as of December 31, 2016 has been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their report which is included under this Item 9A.

Changes in Internal Control over Financial Reporting

There has not been any change in the Company's internal control over financial reporting, as defined in Rule 13a-15(f) under the Exchange Act, during the fiscal quarter ended December 31, 2016 that has materially affected, or is reasonably likely to materially affect, the Company's internal control over financial reporting.

Item 9B. Other Information

None

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

South Jersey Industries, Inc.

Folsom, New Jersey

We have audited the internal control over financial reporting of South Jersey Industries, Inc. and subsidiaries (the "Company") as of December 31, 2016, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. 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 conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). 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.

A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2016, based on the criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedules as of and for the year ended December 31, 2016 of the Company and our reports dated February 27, 2017 expressed an unqualified opinion on those consolidated financial statements and financial statement schedules.

/s/ Deloitte & Touche LLP

Philadelphia, Pennsylvania

February 27, 2017

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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 2017 Annual Meeting of Shareholders (the “2017 Proxy Statement”), which will be filed within the 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 2017 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.

Code of Ethics

The Company has adopted a Code of Ethics for its Principal Executive, Financial and 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 the Code to our website.

Item 11. Executive Compensation

Information concerning executive compensation may be found under the caption “Compensation Discussion & Analysis” of our 2017 Proxy Statement. Such information is incorporated herein by reference.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The information in our 2017 Proxy Statement set forth under the caption “Security Ownership” is incorporated herein by reference.

Item 13. Certain Relationships and Related Transactions, and Director Independence

The information in our 2017 Proxy Statement set forth under the caption “The Board of Directors” and “Certain Relationships” is incorporated herein by reference.

Item 14. Principal Accountant Fees and Services

The information in our 2017 Proxy Statement set forth under the caption “Audit Committee Report” is incorporated herein by reference.

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PART IV

Item 15. Exhibits and Financial Statement Schedules

(a) Listed below are all financial statements and schedules filed as part of this Report:

1 - The consolidated financial statements and notes to consolidated financial statements together with the report thereon of Deloitte & Touche LLP, dated February 27, 2017, are filed as part of this Report under Item 8 - Financial Statements and Supplementary Data.

2 - Supplementary Financial Information

Information regarding selected quarterly financial data can be found on page 111 of this Report.

Schedule I - Supplemental Schedules as of December 31, 2016 and 2015 and for the three years ended December 31, 2016, 2015, and 2014 (page 123).

Report of Independent Registered Public Accounting Firm of Deloitte & Touche LLP (page 122).

Schedule II - Valuation and Qualifying Accounts (page 127).

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).

Exhibit Number	Description	Reference
(3)(a)(i)	Certificate of Incorporation of South Jersey Industries, Inc., as amended through April 19, 1984.	Incorporated by reference from Exhibit (4)(a) of Form S-2 (2-91515).
(3)(a)(ii)	Amendment to Certificate of Incorporation relating to two-for-one stock split effective as of April 28, 1987.	Incorporated by reference from Exhibit (4)(e)(1) of Form S-3 (33-1320).
(3)(a)(iii)	Amendment to Certificate of Incorporation relating to director and officer liability.	Incorporated by reference from Exhibit (4)(e)(2) of Form S-3 (33-1320).
(3)(a)(iv)	Amendment to Certificate of Incorporation relating to two-for-one stock split effective as of June 30, 2005.	Incorporated by reference from Exhibit 3 of Form 10-Q of SJI filed on May 10, 2005.

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(3)(a)(v)	Amendment to Certificate of Incorporation as of April 23, 2009 establishing the annual election of the South Jersey Industries, Inc. directors	Incorporated by reference from Exhibit 99.2 of Form 8-K filed on April 28, 2009.
(3)(a)(vi)	Amendment to Certificate of Incorporation relating to two-for-one stock split effective February 27, 2015.	Incorporated by reference from Exhibit 3 of Form 8-K filed on March 2, 2015.
(3)(b)(i)	Bylaws of South Jersey Industries, Inc. as amended and restated through April 29, 2016.	Incorporated by reference from Exhibit 3.2(ii) of Form 8-K of SJI as filed May 3, 2016.
(4)(a)	Form of Stock Certificate for common stock.	Incorporated by reference from Exhibit (4)(a) of Form 10-K for 1985 (1-6364).
(4)(b)(i)	Supplemental Indenture Amending and Restating First Mortgage Indenture, dated as of January 23, 2017, for SJG.	Incorporated by reference from Exhibit 4.1 of Form 8-K of SJG dated January 30, 2017.
(4)(b)(ii)	First Supplemental Indenture, dated as of January 23, 2017, for SJG	Incorporated by reference from Exhibit 4.2 of Form 8-K of SJG dated January 30, 2017.
(4)(c)(i)	Medium Term Note Indenture of Trust dated October 1, 1998.	Incorporated by reference from Exhibit 4(e) of Form S-3 (333-62019).
(4)(c)(ii)	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.
(4)(c)(iii)	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.
(4)(c)(iv)	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.
(4)(c)(v)	Fourth Supplement to Indenture of Trust dated as of February 26, 2010.	Incorporated by reference from Exhibit 4.1 of Form 8-K of SJG dated March 5, 2010.
(4)(c)(vi)	Fifth Supplement, dated as of January 25, 2017, for SJG	Incorporated by reference from Exhibit 4.3 of Form 8-K of SJG dated January 30, 2017.
(10)(a)(i)	Gas storage agreement (GSS) between South Jersey Gas Company and Transco dated October 1, 1993.	Incorporated by reference from Exhibit (10)(d) of Form 10-K for 1993 (1-6364).

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Exhibit Number	Description	Reference
(10)(a)(ii)	Gas storage agreement (LG-A) between South Jersey Gas Company and Transco dated June 3, 1974.	Incorporated by reference from Exhibit (5)(f) of Form S-7 (2-56223).
(10)(a)(iii)	Gas storage agreement (WSS) between South Jersey Resources Group LLC and Transco dated May 1, 2006.	Incorporated by reference from Exhibit (10)(a)(iii) of Form 10-K for 2008.
(10)(a)(iv)	Gas storage agreement (LSS) between South Jersey Gas Company and Transco dated October 1, 1993.	Incorporated by reference from Exhibit (10)(i) of Form 10-K for 1993 (1-6364).
(10)(a)(v)	Gas storage agreement (SS-1) between South Jersey Gas Company and Transco dated May 10, 1987 (effective April 1, 1988).	Incorporated by reference from Exhibit (10)(i)(a) of Form 10-K for 1988 (1-6364).
(10)(b)(i)	Gas storage agreement (SS-2) between South Jersey Gas Company and Transco dated July 25, 1990.	Incorporated by reference from Exhibit (10)(i)(i) of Form 10-K for 1991 (1-6364).
(10)(b)(ii)	Amendment to gas transportation agreement dated December 20, 1991 between South Jersey Gas Company and Transco dated October 5, 1993.	Incorporated by reference from Exhibit (10)(i)(k) of Form 10-K for 1993 (1-6364).
(10)(b)(iii)	CNJEP Service agreement between South Jersey Gas Company and Transco dated June 27, 2005.	Incorporated by reference from Exhibit (10)(i)(l) of Form 10-K for 2005  (1-6364).
(10)(c)(i)	FTS Service Agreement No. 38099 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993.	Incorporated by reference from Exhibit (10)(k)(n) of Form 10-K for 1993 (1-6364).
(10)(c)(ii)	NTS Service Agreement No. 39305 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993.	Incorporated by reference from Exhibit (10)(k)(o) of Form 10-K for 1993 (1-6364).
(10)(c)(iii)	FSS Service Agreement No. 38130 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993.	Incorporated by reference from Exhibit (10)(k)(p) of Form 10-K for 1993 (1-6364).

(10)(d)(i)	SST Service Agreement No. 38086 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993.	Incorporated by reference from Exhibit (10)(k)(q) of Form 10-K for 1993 (1-6364).
(10)(e)(i)*	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 for 1994 (1-6364).
(10)(e)(ii)*	Schedule of Deferred Compensation Agreements.	Incorporated by reference from Exhibit (10)(l)(b) of Form 10-K for 1997 (1-6364).
(10)(e)(iii)*	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.
(10)(e)(iv)*	Schedule of Officer Agreements (filed herewith).
(10)(f)(i)*	Officer Severance Plan.	Incorporated by reference from Exhibit (10)(f)(i) of Form 10-K for 2014.

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(10)(f)(ii)*	Supplemental Executive Retirement Program, as amended and restated effective January 1, 2009 and Form of Agreement between certain SJI or subsidiary officers.	Incorporated by reference from Exhibit (10)(f)(ii) of Form 10-K for 2009.
(10)(f)(iii)*	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.
(10)(g)(i)	Four-Year Revolving Credit Agreement, for SJI.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated May 2, 2011.
(10)(g)(ii)	Four-Year Revolving Credit Agreement, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated May 6, 2011.
(10)(g)(iii)	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.
(10)(g)(iv)	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.
(10)(g)(v)	Commercial Paper Dealer Agreement, dated as of July 1, 2011, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated July 1, 2011.
(10)(g)(vi)	Commercial Paper Dealer Agreement, dated as of January 5, 2012, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated January 9, 2012.
(10)(g)(vii)	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.
(10)(g)(viii)	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.
(10)(g)(ix)	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.
(10)(g)(x)	Note Purchase Agreement, dated as of September 20, 2012, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated September 25, 2012.
(10)(g)(xi)	First Amendment to Credit Agreement, dated as of February 11, 2013, for SJI.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated February 14, 2013.
(10)(g)(xii)	First Amendment to Credit Agreement, dated as of September 27, 2013, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated September 30, 2013.
(10)(g)(xiii)	Note Purchase Agreement, dated as of November 21, 2013, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated November 21, 2013.
(10)(g)(xiv)	Second Amendment to Credit Agreement, dated as of September 27, 2013, for SJI.	Incorporated by reference from Exhibit 10(g)(xvi) of Form 10-K of SJI as filed February 28, 2014.
(10)(g)(xv)	Note Purchase Agreement, dated as of June 26, 2014, for SJI.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated June 26, 2014.
(10)(g)(xvi)	Term Loan Credit Agreement, dated as of October 28, 2015, for SJI.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated November 2, 2015.

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(10)(g)(xvii)	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.
(10)(g)(xviii)	364-Day Revolving Credit Agreement, dated as of September 7, 2016.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated September 9, 2016.
(10)(g)(xix)	Note Purchase Agreement, dated as of January 25, 2017, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated January 30, 2017.
(10)(g)(xx)	Term Loan Credit Agreement, dated as of January 26, 2017, for SJG.	Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated January 30, 2017.
(10)(g)(xxi)	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.
(10)(h)(i)	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, 2015.
(10)(h)(ii)	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, 2015.
(12)	Calculation of Ratio of Earnings to Fixed Charges (Before Federal Income Taxes) (filed herewith).
(14)	Code of Ethics.	Incorporated by reference from Exhibit 14 of Form 10-K for 2007.
(21)	Subsidiaries of the Registrant (filed herewith).
(23)	Independent Registered Public Accounting Firm's Consent (filed herewith).
(31.1)	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
(31.2)	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
(32.1)	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith).
(32.2)	Certification of Chief 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).

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(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/ Stephen H. Clark
	Stephen H. Clark
	Executive Vice President & Chief Financial Officer
Date:	February 27, 2017

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, 2017
(Walter M. Higgins, III)
/s/ Michael J. Renna	Director, President & Chief Executive Officer	February 27, 2017
(Michael J. Renna)	(Principal Executive Officer)
/s/ Stephen H. Clark	Executive Vice President & Chief Financial Officer	February 27, 2017
(Stephen H. Clark)	(Principal Financial and Accounting Officer)
/s/ Sarah M. Barpoulis	Director	February 27, 2017
(Sarah M. Barpoulis)
/s/ Thomas A. Bracken	Director	February 27, 2017
(Thomas A. Bracken)
/s/ Keith S. Campbell	Director	February 27, 2017
(Keith S. Campbell)
/s/ Victor A. Fortkiewicz	Director	February 27, 2017
(Victor A. Fortkiewicz)
/s/ Sheila Hartnett-Devlin	Director	February 27, 2017
(Sheila Hartnett-Devlin)
/s/ Sunita Holzer	Director	February 27, 2017
(Sunita Holzer)
/s/ Joseph H. Petrowski	Director	February 27, 2017
(Joseph H. Petrowski)
/s/ Joseph M. Rigby	Director	February 27, 2017
(Joseph M. Rigby)
/s/ Frank L. Sims	Director	February 27, 2017
(Frank L. Sims)

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

South Jersey Industries, Inc.

Folsom, New Jersey

We have audited the consolidated financial statements of South Jersey Industries, Inc. and subsidiaries (the “Company”) as of December 31, 2016 and 2015, and for each of the three years in the period ended December 31, 2016, and the Company's internal control over financial reporting as of December 31, 2016, and have issued our reports thereon dated February 27, 2017; such reports are included elsewhere in this 2016 Annual Report on Form 10-K. Our audits also included the financial statement schedules of the Company listed in Item 15(a)2. These financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion based on our audits. In our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.

/s/ Deloitte & Touche LLP

Philadelphia, Pennsylvania

February 27, 2017

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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF INCOME

(In Thousands)

	2016			2015			2014
Management Service Fee Revenues	$	25,463		$	20,990		$	21,118
Operating Expenses:
Operations	23,852			17,979			18,183
Depreciation	377			406			439
Energy and Other Taxes	1,033			806			813
Total Operating Expenses	25,262			19,191			19,435
Operating Income	201			1,799			1,683
Other Income:
Equity in Earnings of Subsidiaries	119,061			105,610			97,628
Other	11,953			10,145			7,283
Total Other Income	131,014			115,755			104,911
Interest Charges	12,148			11,822			8,803
Income Taxes	6			122			163
Income from Continuing Operations	119,061			105,610			97,628
Equity in Undistributed Earnings of Discontinued Operations	(251		)	(503		)	(582		)
Net Income	$	118,810		$	105,107		$	97,046

SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(In Thousands)

	2016			2015			2014
Net Income	$	118,810		$	105,107		$	97,046
Other Comprehensive Income (Loss) - Net of Tax*
Postretirement Liability Adjustment	(3,197		)	5,518			(9,160		)
Unrealized Gain (Loss) on Available-for-Sale Securities	118			(53		)	(472		)
Unrealized Gain on Derivatives - Other	197			294			134
Total Other Comprehensive (Loss) Income - Net of Tax*	(2,882		)	5,759			(9,498		)
Comprehensive Income	$	115,928		$	110,866		$	87,548

*  Determined using a combined average statutory tax rate of 40%.

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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF RETAINED EARNINGS

(In Thousands)

	2016			2015			2014
Retained Earnings - Beginning	$	474,167		$	439,218		$	406,041
Net Income	118,810			105,107			97,046
	592,977			544,325			503,087
Dividends Declared - Common Stock	(82,380		)	(70,158		)	(63,869		)
Retained Earnings - Ending	$	510,597		$	474,167		$	439,218

SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF CASH FLOWS

FOR THE TWELVE MONTHS ENDED DECEMBER 31,

(In Thousands)

	2016			2015			2014
CASH PROVIDED BY OPERATING ACTIVITIES	$	20,120		$	38,593		$	22,244
CASH FLOWS FROM INVESTING ACTIVITIES:
Net Repayments from (Advances to) Associated Companies	32,300			(118,802		)	(104,979		)
Capital Expenditures	(345		)	(150		)	(1,610		)
Proceeds from Sale of Property, Plant & Equipment	—			—			27
Purchase of Company Owned Life Insurance	(2,398		)	(2,328		)	(1,250		)
Investment in Affiliate	(65,000		)	—			(25,000		)
Net Cash Used in Investing Activities	(35,443		)	(121,280		)	(132,812		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt	—			50,000			240,000
Principal Repayments of Long Term Debt	—			(114,000		)	—
Payments for Issuance of Long Term Debt	(84		)	(55		)	(1,558		)
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(105,500		)	153,000			(144,100		)
Dividends on Common Stock	(82,380		)	(70,158		)	(63,869		)
Proceeds from Sale of Common Stock	214,426			63,192			80,680
Net Cash Provided by Financing Activities	26,462			81,979			111,153
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	11,139			(708		)	585
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	1,708			2,416			1,831
CASH AND CASH EQUIVALENTS AT END OF YEAR	$	12,847		$	1,708		$	2,416

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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED BALANCE SHEETS (In Thousands)

	2016			2015
Assets
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost	$	2,685		$	2,468
Accumulated Depreciation	(2,026		)	(1,768		)
Property, Plant and Equipment - Net	659			700
Investments:
Investments in Subsidiaries	1,233,856			1,051,675
Available-for-Sale Securities	32			3,860
Total Investments	1,233,888			1,055,535
Current Assets:
Cash and Cash Equivalents	12,847			1,708
Receivable from Associated Companies	550,227			582,406
Accounts Receivable	49			49
Other	—			2,859
Total Current Assets	563,123			587,022
Other Noncurrent Assets (See Note 1)	44,974			38,168
Total Assets	$	1,842,644		$	1,681,425
Capitalization and Liabilities
Equity:
Common Stock SJI
Par Value $1.25 a share
Authorized - 120,000,000 shares
Outstanding Shares - 79,478,055 (2016) and 70,965,622 (2015)	$	99,347		$	88,707
Premium on Common Stock	706,943			499,460
Treasury Stock (at par)	(266		)	(296		)
Accumulated Other Comprehensive Loss	(27,381		)	(24,499		)
Retained Earnings	510,597			474,167
Total Equity	1,289,240			1,037,539
Long-Term Debt (See Note 1)	323,971			339,665
Current Liabilities:
Notes Payable - Banks	191,800			297,300
Current Portion of Long-Term Debt	16,000			—
Payable to Associated Companies	382			262
Accounts Payable	211			425
Other Current Liabilities	7,707			3,579
Total Current Liabilities	216,100			301,566
Other Noncurrent Liabilities	13,333			2,655
Total Capitalization and Liabilities	$	1,842,644		$	1,681,425

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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 the prior period's condensed balance sheets to conform to the current period presentation. The unamortized debt issuance costs previously included in "Other Noncurrent Assets" on the condensed balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described under "New Accounting Pronouncements" in Note 1 of the consolidated financial statements.

No dividends were received from subsidiaries in 2016. Dividends received from subsidiaries amounted to $40.8 million and $18.2 million in 2015 and 2014, respectively.

126

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		Charged to Other Accounts - Describe (a)			Deductions - Describe (b)		Balance at End of Period
Provision for Uncollectible
Accounts for the Year Ended
December 31, 2016	$	10,252	$	6,907	$	(47	)	$	4,368	$	12,744
Provision for Uncollectible
Accounts for the Year Ended
December 31, 2015	$	7,910	$	14,730	$	(79	)	$	12,309	$	10,252
Provision for Uncollectible
Accounts for the Year Ended
December 31, 2014	$	5,854	$	9,519	$	(102	)	$	7,361	$	7,910

(a) Recoveries of accounts previously written off and minor adjustments.

(b) Uncollectible accounts written off.

127

EX-10.(E)(IV)

Exhibit 10(e)(iv)

SOUTH JERSEY INDUSTRIES, INC.

SCHEDULE OF OFFICER AGREEMENTS

Pursuant to Rule 12b-31, the following sets forth the material details which differ in the Officer Change in Control Agreements, the form of which is filed herewith as Exhibit 10(e)(iii).

Name	Capacities in Which Served	Effective  Date  of Agreement	Severance Multiple of Base Salary and Average Annual Bonus	Duration of Continued Medical Insurance
Michael J. Renna	Director, President and Chief Executive Officer, South Jersey Industries, Inc.	1/1/16	3X	3 years
Stephen H. Clark	Executive Vice President and Chief Financial Officer, South Jersey Industries, Inc.	1/1/16	2X	2 years
Jeffrey E. DuBois	Executive Vice President and Chief Operating Officer, South Jersey Industries, Inc.	1/1/16	2X	2 years
Gina M. Merritt-Epps	Senior Vice President, General Counsel and Corporate Secretary, South Jersey Industries, Inc.	1/1/16	2X	2 years
Kathleen A. McEndy	Senior Vice President and Chief Administrative Officer, South Jersey Industries, Inc.	1/1/16	2X	2 years
Kenneth A. Lynch	Senior Vice President and Chief Risk Officer, South Jersey Industries, Inc.	1/1/16	2X	2 years
David Robbins, Jr.	Senior Vice President, South Jersey Industries, Inc.	1/1/16	2X	2 years
Gregory M. Nuzzo	Senior Vice President, South Jersey Industries, Inc.	1/1/16	2X	2 years

EX-12

													Exhibit 12
SOUTH JERSEY INDUSTRIES, INC. Calculation of Ratio of Earnings from Continuing Operations to Fixed Charges (Before Income Taxes) (IN THOUSANDS)
	Fiscal Year Ended December 31,
	2016			2015			2014			2013			2012
Net Income*	$	119,061		$	105,610		$	97,628		$	82,389		$	92,776
Income Taxes	54,151			1,360			4,449			(19,014		)	11,479
Fixed Charges**	38,042			36,541			34,196			27,509			24,344
Capitalized Interest	(6,593		)	(4,919		)	(4,636		)	(8,684		)	(5,358		)
Total Available	$	204,661		$	138,592		$	131,637		$	82,200		$	123,241
Total Available	5.4		x	3.8		x	3.8		x	3.0		x	5.1		x
Fixed Charges
* Income from Continuing Operations.
** Includes interest charges and capitalized interest.

EX-21

			Exhibit 21
SOUTH JERSEY INDUSTRIES, INC.
SUBSIDIARIES OF REGISTRANT
AS OF DECEMBER 31, 2016
The following is a list of the significant subsidiaries of South Jersey Industries, Inc.
	Percentage of
	Voting Securities
	Directly or Indirectly		State of
	Owned by Immediate Parent	Relationship	Incorporation/Formation
South Jersey Gas Company	100	(1)	New Jersey
Marina Energy LLC	100	(2)	New Jersey
South Jersey Energy Company	100	(2)	New Jersey
South Jersey Resources Group, LLC	100	(2)	Delaware
South Jersey Exploration, LLC	100	(2)	Delaware
South Jersey Energy Service Plus, LLC	100	(2)	New Jersey
South Jersey Energy Solutions, LLC	100	(1)	New Jersey
Energenic - US, LLC	50	(3)	Delaware
SJI Midstream, LLC	100	(1)	Delaware
(1)  Subsidiary of South Jersey Industries, Inc.
(2)  Subsidiary of South Jersey Energy Solutions, LLC
(3)  Subsidiary of Marina Energy LLC

EX-23

Exhibit 23

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statement No. 333-207918 and 333-204553 on Form S-8 and Registration Statements No. 333-200543 and 333-211259 on Form S-3 of our reports dated February 27, 2017, relating to the consolidated financial statements and financial statement schedules of South Jersey Industries, Inc. and subsidiaries (the “Company”), and the effectiveness of the Company's internal control over financial reporting, appearing in this Annual Report on Form 10-K of South Jersey Industries, Inc. for the year ended December 31, 2016.

/s/ Deloitte & Touche LLP

Philadelphia, Pennsylvania

February 27, 2017

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Michael J. Renna, certify that:

1.  I have reviewed this Annual Report on Form 10-K for the period ended December 31, 2016, of South Jersey Industries, Inc.;

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.  The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15 d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c) evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting.

5.  The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent function):

a) all significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

		South Jersey Industries, Inc.
Date:	February 27, 2017	By:	/s/ Michael J. Renna
			Michael J. Renna
			Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Stephen H. Clark, certify that:

1. I have reviewed this Annual Report on Form 10-K for the period ended December 31, 2016, of South Jersey Industries, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15 d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent function):

a) all significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

		South Jersey Industries, Inc.
Date:	February 27, 2017	By:	/s/ Stephen H. Clark
			Stephen H. Clark
			Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002

In connection with the filing of the Annual Report on Form 10-K of South Jersey Industries, Inc. (the “Company”) for the period ended December 31, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael J. Renna, Chief Executive Officer of the Company, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1)           The Report fully complies with the requirements of Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934; and

(2)           The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Michael J. Renna

-----------------------------------------------------

Name:  Michael J. Renna

Title:  Chief Executive Officer

February 27, 2017

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002

In connection with the filing of the Annual Report on Form 10-K of South Jersey Industries, Inc. (the “Company”) for the period ended December 31, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Stephen H. Clark, Chief Financial Officer of the Company, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Stephen H. Clark

Name:  Stephen H. Clark

Title:  Chief Financial Officer

February 27, 2017

XML

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 15, 2017	Jun. 30, 2016
Entity [Abstract]
Entity Registrant Name	SOUTH JERSEY INDUSTRIES INC
Entity Central Index Key	0000091928
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		79,516,553
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 2,506,525,273

XML

Statements of Consolidated Income shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016 USD ($) $ / shares shares	Dec. 31, 2015 USD ($) $ / shares shares	Dec. 31, 2014 USD ($) $ / shares shares
Operating Revenues:
Utility	$ 453,819	$ 528,763	$ 500,752
Nonutility	582,681	430,805	386,244
Total Operating Revenues	1,036,500	959,568	886,996
Cost of Sales - (Excluding depreciation)
- Utility	167,154	239,763	230,093
- Nonutility	413,833	319,579	306,859
Operations	151,957	148,672	140,260
Maintenance	17,549	16,183	13,457
Depreciation	90,389	72,451	63,004
Energy and Other Taxes	6,342	6,026	5,720
Total Operating Expenses	847,224	802,674	759,393
Operating Income	189,276	156,894	127,603
Other Income and Expense	9,989	9,510	11,819
Interest Charges	(31,449)	(31,622)	(29,560)
Income Before Income Taxes	167,816	134,782	109,862
Income Taxes	(54,151)	(1,360)	(4,449)
Equity in Earnings (Loss) of Affiliated Companies	5,396	(27,812)	(7,785)
Income from Continuing Operations	119,061	105,610	97,628
Loss from Discontinued Operations - (Net of tax benefit)	(251)	(503)	(582)
Net Income	$ 118,810	$ 105,107	$ 97,046
Basic Earnings per Common Share:
Continuing Operations (in USD per share) | $ / shares	$ 1.56	$ 1.54	$ 1.47
Discontinued Operations (in USD per share) | $ / shares	(0.00)	(0.01)	(0.01)
Basic Earnings per Common Share (in USD per share) | $ / shares	$ 1.56	$ 1.53	$ 1.46
Average Shares of Common Stock Outstanding - Basic (in shares) | shares	76,362	68,735	66,278
Diluted Earnings per Common Share:
Continuing Operations (in USD per share) | $ / shares	$ 1.56	$ 1.53	$ 1.47
Discontinued Operations (in USD per share) | $ / shares	(0.00)	(0.01)	(0.01)
Diluted Earnings per Common Share (in USD per share) | $ / shares	$ 1.56	$ 1.52	$ 1.46
Average Shares of Common Stock Outstanding - Diluted (in shares) | shares	76,475	68,931	66,428

XML

Statements of Consolidated Comprehensive Income - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Net Income		$ 118,810	$ 105,107	$ 97,046
Other Comprehensive Income (Loss), Net of Tax:
Postretirement Liability Adjustment		(3,197)	5,518	(9,160)
Unrealized Gain (Loss) on Available-for-Sale Securities		118	(53)	(472)
Unrealized Gain on Derivatives - Other		197	321	247
Other Comprehensive Loss of Affiliated Companies		0	(27)	(113)
Other Comprehensive (Loss) Income - Net of Tax	[1],[2]	(2,882)	5,759	(9,498)
Comprehensive Income		$ 115,928	$ 110,866	$ 87,548
Additional Statement Information [Abstract]
Combined average statutory tax rate		40.00%

[1] Determined using a combined average statutory tax rate of 40%.

[2] Determined using a combined average statutory tax rate of 40%.

XML

Statements of Consolidated Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows from Operating Activities:
Net Income	$ 118,810	$ 105,107	$ 97,046
Loss from Discontinued Operations	251	503	582
Income from Continuing Operations	119,061	105,610	97,628
Adjustments to Reconcile Income from Continuing Operations to Net Cash Provided by Operating Activities:
Depreciation and Amortization	109,818	91,042	78,511
Net Unrealized (Gain) Loss on Derivatives - Energy Related	(26,935)	(8,401)	6,592
Unrealized (Gain) Loss on Derivatives - Other	(647)	(96)	467
Provision for Losses on Accounts Receivable	6,907	14,730	9,519
CIP Receivable/Payable	(24,943)	(7,324)	15,226
Deferred Gas Costs - Net of Recoveries	11,753	28,648	(44,976)
Deferred SBC Costs - Net of Recoveries	(7,102)	9,557	11,048
Stock-Based Compensation Expense	3,892	2,213	1,893
Deferred and Noncurrent Income Taxes - Net	55,789	3,861	1,670
Environmental Remediation Costs - Net	(39,731)	(22,057)	(8,265)
Gas Plant Cost of Removal	(6,070)	(5,096)	(4,848)
Pension Contribution	0	(15,000)	0
Changes in:
Accounts Receivable	(67,160)	92,624	(14,323)
Inventories	387	9,226	(4,787)
Prepaid and Accrued Taxes - Net	4,253	(9,091)	(5,822)
Accounts Payable and Other Accrued Liabilities	112,199	(103,410)	27,429
Derivatives - Energy Related	6,723	(8,069)	169
Other Assets and Liabilities	4,090	8,860	(5,444)
Cash Flows from Discontinued Operations	(44)	(1,033)	(355)
Net Cash Provided by Operating Activities	262,240	186,794	161,332
Cash Flows from Investing Activities:
Capital Expenditures	(278,002)	(345,621)	(342,578)
Purchase of Available for Sale Securities	0	(6,059)	0
Proceeds from Restricted Investments	1,738	0	0
Proceeds from Sale of Property, Plant and Equipment	0	0	53
Net Proceeds from (Purchase of) Restricted Investments in Margin Accounts	31,971	20,069	(22,337)
Net Sale of Restricted Investments from Escrowed Loan Proceeds	0	101	0
Investment in Long-Term Receivables	(10,886)	(19,033)	(13,024)
Proceeds from Long-Term Receivables	10,014	8,769	6,544
Notes Receivable	9,916	(9,916)	0
Purchase of Company-Owned Life Insurance	(2,398)	(2,328)	(1,250)
Acquisition of Subsidiary, Net of Cash Acquired	0	1,394	0
Investment in Affiliate	(12,943)	(20,229)	0
Return of Investment in Affiliate	4,750	0	0
Advances on Notes Receivable - Affiliate	0	(2,075)	(7,521)
Net Repayment of Notes Receivable - Affiliate	672	4,276	5,094
Net Cash Used in Investing Activities	(245,168)	(370,652)	(375,019)
Cash Flows from Financing Activities:
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(135,600)	186,000	(108,200)
Proceeds from Issuance of Long-Term Debt	61,000	130,000	329,000
Payments for Issuance of Long-Term Debt	(147)	(64)	(2,184)
Principal Repayments of Long-Term Debt	(49,366)	(125,009)	(21,000)
Dividends on Common Stock	(82,380)	(70,158)	(63,869)
Proceeds from Sale of Common Stock	214,426	63,192	80,680
Payment of Lease Obligation	(10,600)	0	0
Other	0	(397)	(387)
Net Cash (Used in) Provided by Financing Activities	(2,667)	183,564	214,040
Net Increase (Decrease) in Cash and Cash Equivalents	14,405	(294)	353
Cash and Cash Equivalents at Beginning of Year	3,877	4,171	3,818
Cash and Cash Equivalents at End of Year	18,282	3,877	4,171
Cash paid during the year for:
Interest (Net of Amounts Capitalized)	32,372	30,915	28,854
Income Taxes (Net of Refunds)	194	1,828	6,858
Supplemental Disclosures of Non-Cash Investing Activities
Capital Expenditures acquired on account but unpaid as of year-end	39,130	51,433	36,491
Notes Receivable from Affiliate Exchanged for Notes Receivable from a Third Party	0	16,389	0
Notes Receivable Exchanged for Accounts Payable	$ 10,168	$ 0	$ 0

XML

Consolidated Balance Sheets - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment:
Utility Plant, at original cost	$ 2,424,134	$ 2,211,239
Accumulated Depreciation	(471,222)	(440,473)
Nonutility Property and Equipment, at cost	821,942	785,646
Accumulated Depreciation	(151,084)	(108,307)
Property, Plant and Equipment - Net	2,623,770	2,448,105
Investments:
Available-for-Sale Securities	32	14,810
Restricted Investments	13,628	48,758
Investment in Affiliates	28,906	16,983
Total Investments	42,566	80,551
Current Assets:
Cash and Cash Equivalents	18,282	3,877
Accounts Receivable	222,339	178,359
Unbilled Revenues	59,680	40,044
Provision for Uncollectibles	(12,744)	(10,252)
Notes Receivable	1,454	11,800
Notes Receivable - Affiliate	2,461	3,134
Natural Gas in Storage, average cost	53,857	54,211
Materials and Supplies, average cost	6,753	5,088
Prepaid Taxes	17,471	21,753
Derivatives - Energy Related Assets	72,391	83,093
Other Prepayments and Current Assets	31,369	40,167
Total Current Assets	473,313	431,274
Regulatory and Other Noncurrent Assets:
Regulatory Assets	410,746	323,434
Derivatives - Energy Related Assets	8,502	16,238
Notes Receivable - Affiliate	13,275	13,275
Contract Receivables	29,037	28,609
Notes Receivable	25,271	35,439
Goodwill	4,838	8,880
Identifiable Intangible Assets	15,820	21,553
Other	83,429	64,575
Total Regulatory and Other Noncurrent Assets	590,918	512,003
Total Assets	3,730,567	3,471,933
Common Stock: Par Value $1.25 per share; Authorized 120,000,000 shares; Outstanding Shares: 79,478,055 (2016) and 70,965,622 (2015)
Balance at Beginning of Year	88,707	85,418
Common Stock Issued or Granted Under Stock Plans	10,640	3,289
Balance at End of Year	99,347	88,707
Premium on Common Stock	706,943	499,460
Treasury Stock (at par)	(266)	(296)
Accumulated Other Comprehensive Loss	(27,381)	(24,499)
Retained Earnings	510,597	474,167
Total Equity	1,289,240	1,037,539
Long-term Debt, Excluding Current Maturities	808,005	997,427
Total Capitalization	2,097,245	2,034,966
Current Liabilities:
Notes Payable	296,100	431,700
Current Portion of Long-Term Debt	231,909	29,454
Accounts Payable	243,669	186,400
Customer Deposits and Credit Balances	48,068	20,146
Environmental Remediation Costs	46,120	50,559
Taxes Accrued	2,082	2,336
Derivatives - Energy Related Liabilities	60,082	90,708
Derivatives - Other	681	0
Interest Accrued	6,231	7,316
Pension Benefits	2,463	2,261
Other Current Liabilities	15,219	11,596
Total Current Liabilities	952,624	832,476
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	343,549	295,945
Pension and Other Postretirement Benefits	95,235	76,068
Environmental Remediation Costs	108,893	76,064
Asset Retirement Obligations	59,427	57,943
Derivatives - Energy Related Liabilities	4,540	21,697
Derivatives - Other	9,349	10,943
Regulatory Liabilities	49,121	42,841
Other	10,584	22,990
Total Deferred Credits and Other Noncurrent Liabilities	680,698	604,491
Commitments and Contingencies (Note 15)
Total Capitalization and Liabilities	$ 3,730,567	$ 3,471,933

XML

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2016	May 31, 2016	Dec. 31, 2015	Feb. 26, 2015	Feb. 25, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]
Common stock, par value (in USD per share)	$ 1.25	$ 1.25	$ 1.25
Common stock, authorized (in shares)	120,000,000		120,000,000	120,000,000	60,000,000
Common stock, outstanding (in shares)	79,478,055		70,965,622			68,334,860	65,430,084

XML

Consolidated Statements of Changes in Equity and Comprehensive Income - USD ($) $ in Thousands		Total		Common Stock	Premium on Common Stock	Treasury Stock	Accumulated Other Comprehensive Loss		Retained Earnings	Postretirement Liability Adjustment		Unrealized Gain (Loss) on Derivatives-Other		Unrealized Gain (Loss) on Available- for-Sale Securities		Other Comprehensive Income (Loss) of Affiliated Companies
Balance at Dec. 31, 2013		$ 827,000		$ 81,788	$ 360,303	$ (372)	$ (20,760)		$ 406,041
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		97,046							97,046
Common Stock Issued or Granted Through Equity Offering or Stock Plans		81,753		3,630	78,081	42
Cash Dividends Declared - Common Stock		(63,869)							(63,869)
Balance at Dec. 31, 2014		932,432		85,418	438,384	(330)	(30,258)		439,218
Balance at January 1 at Dec. 31, 2013	[1]						(20,760)			$ (18,503)		$ (2,697)		$ 397		$ 43
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Changes During Year		(9,498)	[2],[3]				(9,498)	[1],[3]		(9,160)	[1]	247	[1]	(472)	[1]	(113)	[1]
Balance at December 31 at Dec. 31, 2014	[1]						(30,258)			(27,663)		(2,450)		(75)		(70)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		105,107							105,107
Common Stock Issued or Granted Through Equity Offering or Stock Plans		64,399		3,289	61,076	34
Cash Dividends Declared - Common Stock		(70,158)							(70,158)
Balance at Dec. 31, 2015		1,037,539		88,707	499,460	(296)	(24,499)		474,167
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Changes During Year		5,759	[2],[3]				5,759	[1],[3]		5,518	[1]	321	[1]	(53)	[1]	(27)	[1]
Balance at December 31 at Dec. 31, 2015		(24,499)					(24,499)	[1]		(22,145)	[1]	(2,129)	[1]	(128)	[1]	(97)	[1]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		118,810							118,810
Common Stock Issued or Granted Through Equity Offering or Stock Plans		218,153		10,640	207,483	30
Cash Dividends Declared - Common Stock		(82,380)							(82,380)
Balance at Dec. 31, 2016		$ 1,289,240		$ 99,347	$ 706,943	$ (266)	(27,381)		$ 510,597
Additional Statement Information [Abstract]
Combined average statutory tax rate		40.00%
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Changes During Year		$ (2,882)	[2],[3]				(2,882)	[1],[3]		(3,197)	[1]	197	[1]	118	[1]	0	[1]
Balance at December 31 at Dec. 31, 2016		$ (27,381)					$ (27,381)	[1]		$ (25,342)	[1]	$ (1,932)	[1]	$ (10)	[1]	$ (97)	[1]

[1] Determined using a combined average statutory tax rate of 40%.

[2] Determined using a combined average statutory tax rate of 40%.

[3] Determined using a combined average statutory tax rate of 40%.

XML

Consolidated Statements of Changes in Equity and Comprehensive Income (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Stockholders' Equity [Abstract]
Cash Dividends Declared - Common Share (in USD per share)	$ 1.07	$ 1.02	$ 0.96
Combined average statutory tax rate	40.00%

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

12 Months Ended

Dec. 31, 2016

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries:

▪ South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey.

▪ South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial, industrial and residential customers.

▪ South Jersey Resources Group, LLC (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.

▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include:

• ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey.

• AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.

• MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey.

▪ South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

• SJI Midstream, LLC invests in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.

BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position, operating results and cash flows at the dates and for the periods presented.  

Certain reclassifications have been made to the prior period's consolidated balance sheets, as well as the prior period's long-term debt carrying value and the prior period's segment disclosures in Notes 7 and 8, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the consolidated balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described below under "New Accounting Pronouncements." This reclassification caused the prior periods long-term debt carrying value in Note 7 to be adjusted, along with the prior periods unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 8 to be removed.

On February 26, 2015, the Board of Directors approved an amendment to SJI's Certificate of Incorporation to increase the authorized number of shares of common stock from 60,000,000 shares to 120,000,000 shares. The principal purpose of the increase was to permit a two-for-one split of all the issued shares of SJI's common stock, effected pursuant to a stock dividend of one share of common stock for each outstanding share of common stock, payable May 8, 2015 to shareholders of record at the close of business on April 17, 2015. All references to number of shares and per share information in the consolidated financial statements and related notes have been adjusted for all periods presented to reflect this stock split.

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 the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. 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. We include 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.  In 2015, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings due to the reduction in the carrying value of an investment in a project entered into by Energenic (see Note 7). No impairment losses were recorded on Investments during 2016 or 2014.

ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (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, and revenue recognition.

REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980 -”Regulated Operations.”  In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities.

OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy-related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. SJRG presents revenues and expenses related to its energy trading activities on a net basis in operating revenues. This net presentation has no effect on operating income or net income. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers.

REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both utility revenue and energy and other taxes and totaled $1.1 million, $1.2 million, and $1.1 million in 2016, 2015 and 2014, respectively.

ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLECTIBLE ACCOUNTS - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts.

NATURAL GAS IN STORAGE – Natural Gas in Storage is reflected at average cost on the consolidated balance sheets, and represents natural gas that will be utilized in the ordinary course of business.

ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.

ARO activity was as follows (in thousands):

	2016			2015
AROs as of January 1,	$	57,943		$	42,502
Accretion	1,937			1,675
Additions	1,098			802
Settlements	(1,551		)	(1,110		)
Revisions in Estimated Cash Flows (A)	—			14,074
ARO's as of December 31,	$	59,427		$	57,943

(A) The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account. As of December 31, 2016, SJG's utility plant had a gross book value of $2.4 billion, which consists of utility plant assets along with projects for distribution, some of which are part of SJG's Accelerated Infrastructure Replacement Program (AIRP), as discussed in Note 10. As of December 31, 2016, the gross book value of SJI's nonutility property and equipment is $821.9 million, which consists of $652.8 million of solar assets, $124.2 million of cogeneration assets and $44.9 million of other property and equipment.

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 BPU approval. The composite annual rate for all depreciable utility property was approximately 2.2% in each of 2016, 2015 and 2014. 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, 2016, total accumulated deprecation for utility and nonutility property and equipment was $471.2 million and $151.1 million, respectively.

CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in SJG's last base rate proceeding. For SJG's accelerated infrastructure programs, SJG capitalizes interest on construction at a rate prescribed by the programs (see Note 10), and amounts are included in Utility Plant on the consolidated balance sheets. Marina and Midstream capitalize interest on capital projects in progress based on the actual cost of borrowed funds, and amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the statements of consolidated income.  The amount of interest capitalized by SJI for the years ended December 31, 2016, 2015 and 2014 was $6.6 million, $4.9 million and $4.6 million, respectively.

IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the years ended December 31, 2016, 2015 and 2014, no significant impairments were identified.

DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.”  We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause.

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 Accumulated Other Comprehensive Loss 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.

GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to 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 during the years ended December 31, 2016, 2015 and 2014. As of December 31, 2016 and 2015, $8.8 million and $8.9 million, respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment and Other Noncurrent Assets on the consolidated balance sheets.

TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of December 31, 2016 and 2015, SJI held 212,617 and 236,571 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI.

INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow-through method.

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.

IDENTIFIABLE INTANGIBLE ASSETS - Identifiable intangible assets were acquired as part of the acquisition of Energenic projects as discussed in Note 3 and are a part of the On-Site Energy Production segment. The primary identifiable intangible assets of the Company are customer relationships. The Company determines the useful lives of identifiable intangible assets after considering the specific facts and circumstances related to each intangible asset. Considerations may include the contractual term of any agreement related to the asset, the historical performance of the asset, the Company's long-term strategy for using the asset, any laws or other local regulations which could impact the useful life of the asset, and other economic factors, including competition and specific market conditions. Intangible assets that are deemed to have definite lives (finite-lived intangible assets) are amortized, primarily on a straight-line basis, over their useful lives, generally ranging from 2 to 20 years. The cost of identifiable intangible assets of $15.8 million and $21.6 million are included in Noncurrent Assets on the consolidated balance sheets as of December 31, 2016 and 2015, respectively. The decrease in intangible assets of $5.7 million was attributable to the finalization of the purchase price allocation (see Note 3), which resulted in an adjustment of $4.6 million, along with amortization expense recorded during 2016 of $1.1 million. No amortization was recorded on these assets during 2015.

GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects as discussed in Note 3 and is a part of the On-Site Energy Production segment. Goodwill represents the excess of the consideration paid 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. The Company performed its annual goodwill impairment test in the fourth quarter of 2016 using a qualitative analysis 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 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.The Company concluded based on the results of the annual testing performed that the carrying value of goodwill was not impaired as of December 31, 2016.

Goodwill of $4.8 million and $8.9 million is included in Noncurrent Assets on the consolidated balance sheets as of December 31, 2016 and 2015, respectively. The following table summarizes the changes in Goodwill for the year ended December 31, 2016 (in thousands):

	2016
Beginning Balance, January 1	$	8,880
Fair Value Adjustments During Measurement Period (See Note 3)	(4,042		)
Ending Balance, December 31	$	4,838

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 of 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. 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, is 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 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 to the new guidance using the modified retrospective approach.

In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results.

In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis, which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results.

In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's results of operations; however, balance sheet presentations were modified to conform to this guidance, as described under "Basis of Presentation" above.

Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40). This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's financial statement results.

In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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 adoption of this guidance will have on the Company's financial statement results.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which establishes a new lease accounting model for lessees. The new standard requires 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. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2018, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships. The amendments in this guidance clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-07, Investments- Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting, which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting, which simplifies various aspects of accounting for share-based payment arrangements. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. This standard is intended to provide guidance concerning the classification of certain cash receipts and cash payments in the statement of cash flows and to eliminate the diversity in practice related to such classifications. This standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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 adoption of this guidance will have on the Company's financial statement results.

In November 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash. This standard is intended to reduce diversity in practice in the classification and presentation of changes in restricted cash on the consolidated statement of cash flows. The ASU requires that the consolidated statement of cash flows explain the change in total cash and cash equivalents and amounts generally described as restricted cash or restricted cash equivalents when reconciling the beginning-of-period and end-of-period total amounts. The ASU also requires a reconciliation between the total of cash and equivalents and restricted cash presented on the consolidated statement of cash flows and the cash and cash equivalents balance presented on the consolidated balance sheets. ASU 2016-18 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have 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 adoption of this guidance will have on the Company's financial statement results.

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's financial statement results.

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STOCK-BASED COMPENSATION PLAN

12 Months Ended

Dec. 31, 2016

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

STOCK-BASED COMPENSATION PLAN

STOCK-BASED COMPENSATION PLAN:

On April 30, 2015, the shareholders of SJI approved the adoption of the Company's 2015 Omnibus Equity Compensation Plan (Plan), replacing the Amended and Restated 1997 Stock-Based Compensation Plan that had terminated on January 26, 2015. Under the 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, 2016, 2015 and 2014.   No stock appreciation rights have been issued under the plans. During the years ended December 31, 2016, 2015 and 2014, SJI granted 194,347, 158,929 and 136,526 restricted shares, respectively, to Officers and other key employees under the 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 units granted.

Beginning in 2015, SJI began granting time-based shares of restricted stock, one-third of which vests annually over a three-year period and is limited to 100% payout. Vesting of time-based grants is contingent upon SJI achieving a return on equity (ROE) of at least 7% during the initial year of the grant and meeting the service requirement. Provided that the 7% ROE requirement is met in the initial year, payout is solely contingent upon the service requirement being met in years two and three of the grant. In 2016 and 2015, Officers and other key employees were granted 58,304 and 47,678 shares of time-based restricted stock, respectively, which are included in the shares noted above.

Grants containing market-based performance targets use SJI's total shareholder return (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.

Through 2014, grants containing earnings-based targets were based on SJI's earnings growth rate per share (EGR) relative to a peer group to measure performance. In 2015, earnings-based performance targets included predefined EGR and ROE goals to measure performance. Beginning in 2016, performance targets include pre-defined compounded earnings annual growth rate (CEGR) for SJI. As EGR-based, ROE-based and CEGR-based grants are contingent upon performance and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant over the requisite three-year period of each award. The fair value is measured as the market price at the date of grant. The initial accruals of compensation expense are based on the estimated number of shares expected to vest, assuming the requisite service is rendered and probable outcome of the performance condition is achieved. That estimate is revised if subsequent information indicates that the actual number of shares is likely to differ from previous estimates. Compensation expense is ultimately adjusted based on the actual achievement of service and performance targets.

SJI granted 35,197, 26,338 and 23,220 restricted shares to Directors in 2016, 2015 and 2014, respectively.  Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.

The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2016, and the assumptions used to estimate the fair value of the awards:

	Grants	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	2015 - TSR	33,537	$	26.31	16.0	%	1.10	%
	2015 - EGR, ROE, Time	73,118	$	29.47	N/A		N/A
	2016 - TSR	66,101	$	22.53	18.1	%	1.31	%
	2016 - CEGR, Time	122,759	23.52		N/A		N/A
Directors -	2016	35,197	$	23.88	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-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 the years ended December 31 (in thousands):

	2016			2015			2014
Officers & Key Employees	$	3,051		$	1,128		$	1,260
Directors	841			769			633
Total Cost	3,892			1,897			1,893
Capitalized	(385		)	(216		)	(147		)
Net Expense	$	3,507		$	1,681		$	1,746

The table above reflects the reversal of approximately $0.1 million, $1.2 million and $1.1 million of previously recorded costs in 2016, 2015 and 2014, respectively. These reversals are associated with EPS-based grants for which performance goals were not met.

As of December 31, 2016, there was $4.0 million of total unrecognized compensation cost related to nonvested stock-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, excluding accrued dividend equivalents:

	Officers & Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2016	226,191		26,338		$	26.89
Granted	194,347		35,197		$	23.28
Vested*	(113,917	)	(26,338	)	$	25.69
Cancelled/Forfeited**	(11,106	)	—		$	25.11
Nonvested Shares Outstanding, December 31, 2016	295,515		35,197		$	24.96

*Based on performance information available at the filing of this Report, management expects to award 29,044 shares associated with the 2014 grants to Officers and other key employees in 2017.

** Represents shares forfeited as a result of separation of employment prior to the satisfaction of service conditions.

Performance targets during the three-year vesting periods were not attained for the 2012 or 2013 Officer and other key employee grants that vested at December 31, 2014 and 2015, respectively. As a result, no shares were awarded in 2015 or 2016 associated with those grants. However, the initial performance hurdle for the 2015 time-based grant was met. As a result, 13,247 shares were awarded to Officers and other key employees in 2016 at a market value of $0.3 million. Also, during the years ended December 31, 2016, 2015 and 2014, SJI granted 35,197, 26,338 and 23,220 shares to its Directors at a market value of $0.8 million, $0.8 million and $0.6 million, respectively. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the Plan. However, a change in control could result in such 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.

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AFFILIATIONS AND DISCONTINUED OPERATIONS

12 Months Ended

Dec. 31, 2016

Business Combinations [Abstract]

AFFILIATIONS AND DISCONTINUED OPERATIONS

AFFILIATIONS AND DISCONTINUED OPERATIONS:

AFFILIATIONS — The following affiliated entities are accounted for under the equity method:

Energenic – US, LLC (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.

On December 31, 2015, Energenic, Marina and its joint venture partner entered into two Equity Distribution and Purchase Agreements (the "Transaction"), pursuant to which Marina became the sole owner of eight of the Energenic projects ("Marina Projects") and its joint venture partner became the sole owner of seven other Energenic projects ("Partner Projects"). The Transaction has been accounted for as a distribution of member interests by Energenic to its owners and a business combination through the exchange of member interests in various projects between Marina and its joint venture partner. In connection with the exchange, the joint venture partner provided a $19.5 million note payable to Marina. The note and other existing obligations of the joint venture partner to Marina are included in Notes Receivable on the consolidated balance sheets, with approximately $1.5 million being included as a current asset as of December 31, 2016 as it is due within one year. This note is collateralized by security interests in various energy project assets owned by the joint venture partner, as well as personal guarantees from its principals.

As part of the transaction, each party is relieved of any guarantees related to the Projects in which it no longer has an ownership interest. 

The projects that are now wholly-owned by Marina are ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS.

Through December 31, 2015, Marina’s investment in Energenic was accounted for under the equity method of accounting. As such, Marina’s share of the equity value of the projects was included within Investment in Affiliates on the consolidated balance sheets and Marina’s share of the loss or earnings from the projects was included within Equity in (Loss) Earnings of Affiliated Companies on the statements of consolidated income for the years ended December 31, 2015 and 2014, respectively. As of December 31, 2015, the assets and liabilities of the projects that are now wholly-owned by Marina are consolidated into the consolidated balance sheets. Beginning in 2016, the respective results from operations and cash flows of the projects that are now wholly-owned by Marina are consolidated into the statements of consolidated income and cash flows, respectively. This transaction represents a non-cash investing and financing activity. The results of the acquired projects are included in the On-Site Energy Production segment.

The following table summarizes the final purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.0 million, which represents the fair value of the Company’s interest in the Partner Projects exchanged ($31.5 million) as well as the existing value of the Marina Projects immediately prior to the exchange ($14.5 million) (in thousands):

Current assets (excluding inventory)	$	7,804
Inventory	3,154
Note Receivable Received	19,504
Fixed Assets	46,460
Intangible Assets:
Identifiable Intangibles	16,950
Goodwill	4,838
Non-Current Assets	4,783
Current Liabilities	(8,196		)
Note Payable - Affiliate	(16,986		)
Long-Term Debt, including current portion	(21,642		)
Capital Lease Payable	(10,458		)
Other Non-Current Liabilities	(181		)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects	$	46,030

The pro forma impact of this transaction on the operations of the Company is not significant.

Potato Creek, LLC (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 Pipeline Company, LLC (PennEast) - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 100-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, with a target completion of late 2018.

The Company made net investments in unconsolidated affiliates of $7.5 million and $18.0 million in 2016 and 2015, respectively. During 2014, the Company provided net advances to unconsolidated affiliates of $2.4 million.  As of December 31, 2016 and 2015, the outstanding balance of Notes Receivable – Affiliate was $15.7 million and $16.4 million, respectively. As of December 31, 2016, 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, and the remaining $2.1 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, 2016, the Company had a net asset of approximately $28.9 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, 2016 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the aggregate amount of $44.6 million.

DISCONTINUED OPERATIONS - Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (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.

Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts):

	2016			2015			2014
Loss before Income Taxes:
Sand Mining	$	(205	)	$	(422	)	$	(620	)
Fuel Oil	(179		)	(338		)	(274		)
Income Tax Benefits	133			257			312
Loss from Discontinued Operations — Net	$	(251	)	$	(503	)	$	(582	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic and Diluted	$	—		$	(0.01	)	$	(0.01	)

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INCOME TAXES

12 Months Ended

Dec. 31, 2016

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES:

SJI files a consolidated federal income tax return. State income tax returns are filed on a separate company basis in states where SJI has operations and/or a requirement to file. 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 the following reasons (in thousands):

	2016			2015			2014
Tax at Statutory Rate	$	60,624		$	37,440		$	35,727
Increase (Decrease) Resulting from:
State Income Taxes	6,438			3,985			1,960
ESOP Dividend	(1,300		)	(1,298		)	(1,232		)
Amortization of Investment Tax Credits - Utility	—			(149		)	(211		)
AFUDC	(900		)	(1,109		)	(1,481		)
Investment and Other Tax Credits	(10,706		)	(37,503		)	(30,661		)
Other - Net	(5		)	(6		)	347
Income Taxes:
Continuing Operations	54,151			1,360			4,449
Discontinued Operations	(133		)	(257		)	(312		)
Total Income Tax Expense	$	54,018		$	1,103		$	4,137
The provision for Income Taxes is comprised of the following (in thousands):
	2016			2015			2014
Current:
Federal	$	—		$	—		$	(62	)
State	(1,638		)	(2,352		)	3,052
Total Current	(1,638		)	(2,352		)	2,990
Deferred:
Federal	44,246			(4,622		)	1,707
State	11,543			8,483			(37		)
Total Deferred	55,789			3,861			1,670
Investment Tax Credit - Utility	—			(149		)	(211		)
Income Taxes:
Continuing Operations	54,151			1,360			4,449
Discontinued Operations	(133		)	(257		)	(312		)
Total Income Tax Expense	$	54,018		$	1,103		$	4,137

For the year ended December 31, 2016, the Company's overall tax expense increased primarily due to a decrease in the investment tax credits available on renewable energy facilities at Marina, along with higher income before income taxes.

Investment Tax Credits attributable to SJG are deferred and amortized at the annual rate of 3.0%, which approximates the life of related assets.

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 at December 31 (in thousands):

	2016		2015
Deferred Tax Assets:
Net Operating Loss Carryforward	$	211,004	$	195,358
Investment and Other Tax Credits	213,946		200,491
Derivatives / Unrealized Gain	—		5,652
Deferred State Tax	28,833		24,833
Pension & Other Post Retirement Benefits	19,351		29,998
Deferred Revenues	7,669		4,924
Provision for Uncollectibles	5,231		4,200
Other	8,368		6,448
Total Deferred Tax Asset	$	494,402	$	471,904
Deferred Tax Liabilities:
Book versus Tax Basis of Property	$	732,535	$	675,521
Deferred Gas Costs - Net	2,052		3,998
Derivatives / Unrealized Loss	1,794		—
Environmental Remediation	32,885		19,207
Deferred Regulatory Costs	1,554		566
Budget Billing - Customer Accounts	3,347		830
Deferred Pension & Other Post Retirement Benefits	34,432		42,216
Conservation Incentive Program	11,846		1,132
Equity In Loss Of Affiliated Companies	3,092		9,111
Other	14,414		15,268
Total Deferred Tax Liability	$	837,951	$	767,849
Deferred Tax Liability - Net	$	343,549	$	295,945

As of December 31, 2016, SJI has the following federal and state net operating loss carryforwards (in thousands):

	Net Operating Loss Carryforwards
Expire in:	Federal		State
2031	$	163,572	$	45,866
2032	42,988		19,356
2033	67,496		34,940
2034	119,122		28,622
2035	70,992		9,860
2036	93,508		81,369
	$	557,678	$	220,013

As of December 31, 2016, SJI has the following investment tax credit carryforwards (in thousands):

Expire in:	Investment Tax Credit Carryforward
2030	$	11,628
2031	25,664
2032	32,071
2033	45,606
2034	37,699
2035	45,097
2036	11,659
	$	209,424

SJI has $1.2 million of federal alternative minimum tax credits which have no expiration date. SJI also has research and development credits of $3.3 million that will expire between 2031 and 2035. A valuation allowance is recorded when it is more likely than not that any of SJI's deferred tax assets will not be realized. SJI believes that it will generate sufficient future taxable income to realize the income tax benefits related to SJI's net deferred tax assets.

The total unrecognized tax benefits as of December 31, 2016, 2015, and 2014 were $1.4 million, $0.6 million, and $0.6 million, respectively, which excludes $0.7 million, of accrued interest and penalties for each period.

A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands):

	2016		2015		2014
Balance at January 1,	$	559	$	552	$	547
Increase as a result of tax positions taken in prior years	886		7		5
Balance at December 31,	$	1,445	$	559	$	552

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 2016, 2015 or 2014. 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 2013 forward and state income tax returns from 2008 forward are open and subject to examination.

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PREFERRED STOCK

12 Months Ended

Dec. 31, 2016

Equity [Abstract]

PREFERRED STOCK

PREFERRED STOCK:

REDEEMABLE CUMULATIVE PREFERRED STOCK - SJI has 2,500,000 authorized shares of Preference Stock, no par value, which has not been issued.

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COMMON STOCK

12 Months Ended

Dec. 31, 2016

Common Stock [Abstract]

COMMON STOCK

COMMON STOCK:

The following shares were issued and outstanding at December 31 (See Note 1):

	2016	2015	2014
Beginning of Year	70,965,622	68,334,860	65,430,084
New Issues During Year:
Dividend Reinvestment Plan	417,095	2,604,424	2,881,556
Stock-Based Compensation Plan	45,338	26,338	23,220
Public Equity Offering	8,050,000	—	—
End of Year	79,478,055	70,965,622	68,334,860

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, 2016 of approximately $207.5 million was recorded in Premium on Common Stock.

In May 2016, the Company issued and sold 8,050,000 shares of its common stock, par value $1.25 per share pursuant to a public offering, raising net proceeds of approximately $203.6 million. The net proceeds from this offering were or will be used for capital expenditures, primarily for regulated businesses, including infrastructure investments at its utility business.

EARNINGS PER COMMON SHARE (EPS) — 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 112,590, 195,139, and 150,062 shares for the years ended December 31, 2016, 2015 and 2014, respectively. These shares relate to SJI’s restricted stock as discussed in Note 2.

DIVIDENDS PER SHARE - Dividends per share were $1.07, $1.02 and $0.96 for the years ended December 31, 2016, 2015 and 2014, respectively.

DIVIDEND REINVESTMENT PLAN (DRP) — The Company offered a DRP which allowed participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases, prior to May 1, 2016. Shares of common stock offered by the DRP had been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $10.8 million and $63.2 million of equity capital through the DRP in 2016 and 2015, respectively. Effective May 1, 2016, SJI switched to purchasing shares on the open market to fund share purchases by DRP participants. SJI does not intend to issue any more new equity capital via the DRP in 2017.

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FINANCIAL INSTRUMENTS

12 Months Ended

Dec. 31, 2016

Financial Instruments, Owned, at Fair Value [Abstract]

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS:

RESTRICTED INVESTMENTS —Marina is required to maintain escrow accounts related to ongoing capital projects as well as unused loan proceeds pending approval of construction expenditures. As of December 31, 2016 and 2015, the escrowed funds, including interest earned, totaled $1.9 million and $3.4 million, respectively.

The Company maintains margin accounts with selected counterparties to support its 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, 2016 and 2015, the balances in these accounts totaled $11.7 million and $43.7 million, respectively.

As of December 31, 2015, in accordance with an outstanding loan agreement with a third party, ACB was required to maintain control accounts, which included a debt service reserve of $1.7 million. In January 2016, the remaining debt on the loan agreement was paid (see Note 14); accordingly, there was no such reserve as of December 31, 2016.

The carrying amounts of the Restricted Investments approximate their fair values at December 31, 2016 and 2015, which would be included in Level 1 of the fair value hierarchy (see Note 17).

INVESTMENT IN AFFILIATES - During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex.

In June 2014, the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. As of December 31, 2015, the Energenic subsidiaries were providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries had not been able to secure a permanent or long-term energy services agreement with the new owner.

In 2015, management of the Company and Energenic evaluated the carrying value of the investment in this project and a related note receivable. Based on the inability of the Energenic subsidiaries to secure a permanent or long-term energy services agreement, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge was included in Equity in Loss of Affiliated Companies for the year ended December 31, 2015 on the statements of consolidated income.

The central energy center and energy distribution system owned by the Energenic subsidiaries was financed in part by the issuance of bonds during 2011. These bonds were collateralized primarily by certain assets of the central energy center and revenue from the energy services agreement with the hotel, casino and entertainment complex. During 2015, due to the cessation of normal business operations of the complex and the inability of the Energenic subsidiaries to meet its obligations under the bonds, the trustee for the bondholders filed suit to foreclose on certain assets of the central energy center. In November 2015 during settlement discussions, the bondholders alleged, among other things, that they were entitled to recover from Energenic itself, any amounts owed under the bonds that were not covered by the collateral, including principal, interest and attorney’s fees. The bondholders’ assertion was based on inconsistent language in the bond documents. In January 2016, Energenic and certain subsidiaries reached a multi-party settlement with the bondholders. This agreement resolves all outstanding litigation and transfers ownership of the bondholders’ collateral to the owners of the entertainment complex. The Company's share of this settlement was $7.5 million, which was accrued by Energenic as of December 31, 2015 and paid in 2016. The Company entered into agreements with its insurance carrier and external legal advisors to recover, net of legal costs, approximately $7.0 million of costs associated with the bondholder settlement discussed above. The Company received $2.1 million in the second quarter of 2016, which is included in Other Income on the statements of consolidated income for the year ended December 31, 2016, and $5.3 million was received in the third quarter of 2016 and is included in Equity in Earnings of Affiliated Companies on the statements of consolidated income for the year ended December 31, 2016, as the loss recorded in the prior year was included in this line item on the statements of consolidated income for the year ended December 31, 2015.

As of December 31, 2016, the Company, through its investment in Energenic, had a remaining net asset of approximately $0.6 million included in Investment in Affiliates on the consolidated balance sheets related to cogeneration assets for this project. In addition, the Company had approximately $13.6 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from Energenic, which is secured by those cogeneration assets. This note is subject to a reimbursement agreement that secures reimbursement for the Company, 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 complex and will evaluate the carrying value of the investment and the note receivable as future events occur.

NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The note bore interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. In December 2015 and February 2016, the borrower exercised each option, respectively. In July 2016, the note was repaid in full, including interest.

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 $9.5 million and $12.9 million as of December 31, 2016 and 2015, 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 $0.9 million and $1.3 million as of December 31, 2016 and 2015, respectively.  The annual amortization to interest is not material to the Company’s consolidated financial statements.   The carrying amounts of these receivables approximate their fair value at December 31, 2016 and 2015, which would be included in Level 2 of the fair value hierarchy (see Note 17).

CREDIT RISK - As of December 31, 2016, approximately $9.3 million or 11.5% of current and noncurrent Derivatives–Energy Related Assets are transacted with three counterparties, all of which 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 financial instruments approximate their fair values at December 31, 2016 and 2015, except as noted below.

• For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJI 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, including current maturities, as of December 31, 2016 and 2015, were $1,080.8 million and $1,079.0 million, respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of December 31, 2016 and 2015, was $1,039.9 million and $1,026.9 million, respectively. The carrying amounts as of December 31, 2016 and 2015 are net of unamortized debt issuance costs of $7.6 million and $9.0 million, respectively (see Note 1).

OTHER FINANCIAL INSTRUMENTS - The carrying amounts of SJI's other financial instruments approximate their fair values at December 31, 2016 and 2015.

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SEGMENTS OF BUSINESS

12 Months Ended

Dec. 31, 2016

Segment Reporting [Abstract]

SEGMENTS OF BUSINESS

SEGMENTS OF BUSINESS:

SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. These segments are as follows:

• Gas utility operations (SJG) consist primarily of natural gas distribution to residential, commercial and industrial customers.

• Wholesale energy operations include the activities of SJRG and SJEX.

• SJE is involved in both retail gas and retail electric activities.

◦ Retail gas and other operations include natural gas acquisition and transportation service business lines.

◦ Retail electric operations 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. Included in this segment are the activities of the following significant entities: ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS. These entities became wholly-owned subsidiaries of Marina on December 31, 2015 (see Note 3).

• Appliance service operations includes SJESP, which services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

• 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. The activities of Midstream are a part of the Corporate and Services segment.

SJI groups its nonutility operations into two 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.  Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices.

Information about SJI’s operations in different reportable operating segments is presented below (in thousands):

	2016			2015			2014
Operating Revenues:
Gas Utility Operations	$	461,055		$	534,290		$	501,875
Energy Group:
Wholesale Energy Operations	220,707			129,098			77,048
Retail Gas and Other Operations	92,371			87,198			127,001
Retail Electric Operations	182,540			150,049			123,773
Subtotal Energy Group	495,618			366,345			327,822
Energy Services:
On-Site Energy Production	94,375			63,665			56,129
Appliance Service Operations	7,898			11,186			10,518
Subtotal Energy Services	102,273			74,851			66,647
Corporate & Services	35,147			31,156			30,174
Subtotal	1,094,093			1,006,642			926,518
Intersegment Sales	(57,593		)	(47,074		)	(39,522		)
Total Operating Revenues	$	1,036,500		$	959,568		$	886,996

	2016			2015			2014
Operating Income:
Gas Utility Operations	$	122,455		$	119,585		$	113,690
Energy Group:
Wholesale Energy Operations	41,667			35,024			9,493
Retail Gas and Other Operations	4,680			(3,218		)	479
Retail Electric Operations	7,007			1,042			(466		)
Subtotal Energy Group	53,354			32,848			9,506
Energy Services:
On-Site Energy Production	13,301			2,027			2,560
Appliance Service Operations	582			468			362
Subtotal Energy Services	13,883			2,495			2,922
Corporate and Services	(416		)	1,966			1,485
Total Operating Income	$	189,276		$	156,894		$	127,603
Depreciation and Amortization:
Gas Utility Operations	$	63,901		$	58,668		$	52,155
Energy Group:
Wholesale Energy Operations	484			435			168
Retail Gas and Other Operations	337			161			83
Subtotal Energy Group	821			596			251
Energy Services:
On-Site Energy Production	43,395			30,242			25,020
Appliance Service Operations	301			316			269
Subtotal Energy Services	43,696			30,558			25,289
Corporate and Services	1,400			1,220			816
Total Depreciation and Amortization	$	109,818		$	91,042		$	78,511
Interest Charges:
Gas Utility Operations	$	17,875		$	19,906		$	17,872
Energy Group:
Wholesale Energy Operations	—			441			371
Retail Gas and Other Operations	350			185			267
Subtotal Energy Group	350			626			638
Energy Services:
On-Site Energy Production	11,961			8,169			8,723
Corporate and Services	12,118			11,822			8,803
Subtotal	42,304			40,523			36,036
Intersegment Borrowings	(10,855		)	(8,901		)	(6,476		)
Total Interest Charges	$	31,449		$	31,622		$	29,560

	2016			2015			2014
Income Taxes:
Gas Utility Operations	$	39,366		$	36,945		$	34,895
Energy Group:
Wholesale Energy Operations	15,882			14,410			4,822
Retail Gas and Other Operations	2,118			(978		)	787
Retail Electric Operations	2,862			426			(190		)
Subtotal Energy Group	20,862			13,858			5,419
Energy Services:
On-Site Energy Production	(6,353		)	(49,225		)	(36,404		)
Appliance Service Operations	232			186			223
Subtotal Energy Services	(6,121		)	(49,039		)	(36,181		)
Corporate and Services	44			(404		)	316
Total Income Taxes	$	54,151		$	1,360		$	4,449
Property Additions:
Gas Utility Operations	$	228,275		$	218,260		$	201,737
Energy Group:
Wholesale Energy Operations	7			382			18
Retail Gas and Other Operations	1,642			2,053			1,421
Subtotal Energy Group	1,649			2,435			1,439
Energy Services:
On-Site Energy Production (1)	38,193			139,018			132,214
Appliance Service Operations	431			379			84
Subtotal Energy Services	38,624			139,397			132,298
Corporate and Services	1,141			1,902			3,995
Total Property Additions	$	269,689		$	361,994		$	339,469

(1) The property additions for On-Site Energy Production in 2016 and 2015 do not include the approximately $5.6 million and $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3.

	2016			2015
Identifiable Assets (See Note 1):
Gas Utility Operations	$	2,551,923		$	2,281,576
Energy Group:
Wholesale Energy Operations	233,019			231,660
Retail Gas and Other Operations	52,729			55,111
Retail Electric Operations	41,280			55,528
Subtotal Energy Group	327,028			342,299
Energy Services:
On-Site Energy Production	767,710			790,231
Appliance Service Operations	2,879			4,885
Subtotal Energy Services	770,589			795,116
Discontinued Operations	1,756			1,545
Corporate and Services	649,795			652,325
Intersegment Assets	(570,524		)	(600,928		)
Total Identifiable Assets	$	3,730,567		$	3,471,933

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LEASES

12 Months Ended

Dec. 31, 2016

Leases [Abstract]

LEASES

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, 2016 and 2015, the carrying costs of this property and equipment under operating lease was $75.9 million and $78.2 million, respectively (net of accumulated depreciation of $31.4 million and $28.5 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, 2016 for each of the next five years and in the aggregate are (in thousands):

Year ended December 31,
2017	$	5,396
2018	5,396
2019	5,396
2020	5,396
2021	5,396
Thereafter	29,230
Total minimum future rentals	56,210

Minimum future rentals do not include additional amounts to be received based on actual use of the leased property.

BCLE was considered to be the lessee of certain electric generating units and related facilities and equipment under a capital lease which was set to expire in October 2027. The interest rate related to the obligation was 6.8%, and the related facilities and equipment were being amortized over the useful life ranging from 7-39 years. As of December 31, 2015, the carrying costs of this property and equipment under capital lease was $4.1 million and was included in Nonutility Property and Equipment in the consolidated balance sheets. On December 31, 2016, BCLE terminated the lease and purchased the respective assets for $10.6 million. Total accumulated depreciation taken on this capital lease, prior to termination, was $0.2 million as of December 31, 2016; no depreciation was taken on this lease by Marina as of December 31, 2015.

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RATES AND REGULATORY ACTIONS

12 Months Ended

Dec. 31, 2016

Public Utilities, General Disclosures [Abstract]

RATES AND REGULATORY ACTIONS

RATES AND REGULATORY ACTIONS:

BASE RATES - SJG is subject to the rules and regulations of the BPU.  

In September 2014, the BPU granted SJG a base rate increase of $20.0 million, which was predicated, in part, upon a 7.10% rate of return on rate base that included a 9.75% return on common equity.  The $20.0 million includes approximately $7.5 million of revenue associated with previously approved Accelerated Infrastructure Replacement Program (AIRP) investments that were rolled into base rates. SJG was also permitted to recover certain regulatory assets and to reduce its composite depreciate rate from 2.4% to 2.1%. These changes became effective on October 1, 2014.

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. SJG expects the base rate case to be concluded during 2017 (see Note 19).

RATE MECHANISMS - SJG's tariff, a schedule detailing the terms, conditions and rate information applicable to its various types of natural gas service, as approved by the BPU, has several primary rate mechanisms as discussed in detail below:

Basic Gas Supply Service (BGSS) Clause - The BGSS price structure allows SJG to recover all prudently incurred gas costs. BGSS charges to customers can be either monthly or periodic (annual). Monthly BGSS charges are applicable to large use customers and are referred to as monthly because the rate changes on a monthly basis pursuant to a BPU-approved formula based on commodity market prices. Periodic BGSS charges are applicable to lower usage customers, which include all of SJG's residential customers, and are evaluated at least annually by the BPU. However, to some extent, more frequent rate changes to the periodic BGSS are allowed. SJG collects gas costs from customers on a forecasted basis and defers periodic over/under recoveries to the following BGSS year, which runs from October 1 through September 30. If SJG is in a net cumulative undercollected position, gas costs deferrals are reflected on the balance sheet as a regulatory asset. If SJG is in a net cumulative overcollected position, amounts due back to customers are reflected on the balance sheet as a regulatory liability. SJG pays interest on net overcollected BGSS balances at the rate of return on rate base utilized by the BPU to set rates in the last base rate proceeding.

Regulatory actions regarding the BGSS were as follows:

• January 2014 - SJG credited the accounts of its periodic BGSS customer with refunds totaling $11.2 million due to gas costs that were lower than projected.

• May 2014 - SJG filed its annual BGSS filing with the BPU requesting a $27.0 million, or a 9.3% increase in gas cost recoveries.

• September 2014 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $27.0 million increase in gas cost recoveries.

• June 2015 - SJG filed its annual BGSS filing with the BPU, requesting a $28.4 million decrease in gas cost recoveries.

• September 2015 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $28.4 million decrease in gas cost recoveries.

• 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.

Conservation Incentive Program (CIP) - The primary purpose of the CIP is to promote conservation efforts, without negatively impacting financial stability, and to base SJG's profit margin on the number of customers rather than the amount of natural gas distributed to customers.  Each CIP year begins October 1 and ends September 30 of the subsequent year. On a monthly basis during the CIP year, SJG records adjustments to earnings based on weather and customer usage factors, as incurred. Subsequent to each year, SJG 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.

Regulatory actions regarding the CIP were as follows:

• May 2014 - SJG made its annual CIP filing with the BPU requesting a revenue reduction of $21.8 million, which includes a $4.2 million increase in non-weather related revenues and a $26.0 million reduction in weather related revenues.

• September 2014 - The BPU issued an Order approving, on a provisional basis, the 2014-2015 CIP rates filed in May 2014, effective October 1 2014.

• June 2015 - SJG filed its annual CIP filing with the BPU, requesting a decrease in revenues of $11.3 million, which includes a $8.8 million decrease in non-weather related revenues and a $2.5 million decrease in weather related revenues.

• September 2015 - The BPU issued an Order approving, on a provisional basis, the 2015-2016 CIP rates filed in June 2015, effective October 1, 2015.

• 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.

Accelerated Infrastructure Replacement Program (AIRP) - In February 2013, the BPU issued an Order approving 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. Pursuant to the Order, AIRP investments are to be reviewed and included in rate base in future base rate proceedings.

Regulatory actions regarding AIRP were as follows:

• September 2014 - The BPU approved SJG’s base rate case, which included a $7.5 million increase in revenues associated with the roll in of $69.9 million of AIRP investments, inclusive of $3.2 million of AFUDC, into base rates.

• 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, 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.

Storm Hardening and Reliability Program (SHARP) - In September 2013, SJG filed with the BPU an asset hardening program pursuant to which SJG will invest approximately $280.0 million over seven years to replace low pressure distribution mains and services with high pressure mains and services in coastal areas that are susceptible to flooding during major storm events.

Regulatory actions regarding SHARP were as follows:

• August 2014 - The BPU approved the SHARP, authorizing SJG to invest $103.5 million over three years for system hardening on barrier islands.  SJG will earn a return on these investments as they are made and will reflect the investments in base rates through annual rate adjustments.

• April 2015 - SJG filed a petition seeking a base rate adjustment to increase annual revenues by approximately $4.0 million to reflect approximately $36.6 million of SHARP investments made from July 2014 through June 2015.

• September 2015 - The BPU approved SJG’s request to increase annual revenues from base rates by $4.0 million, effective October 1, 2015.

• 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.

Energy Efficiency Tracker (EET) - Under this program, SJG was permitted to invest $17.0 million over two years in energy efficiency measures to be installed in customer homes and businesses. SJG also recovered incremental operating and maintenance expenses and earn a return of, and return on, program investments. In June 2013, the BPU authorized SJG to continue to offer Energy Efficiency Programs (EEPs) through June 2015 with an approved budget of $24.0 million. In August 2015, the BPU approved a two-year extension of SJG’s EEPs through August 31, 2017, with a program budget of $36.3 million.

Regulatory actions regarding the EET/EEP were as follows:

• May 2014 - SJG filed its annual EET rate adjustment petition requesting a $1.4 million increase in revenues to recover the costs of, and the allowed return on, prior investments associated with energy efficiency programs.

• September 2014 - The BPU approved a revenue increase of $2.2 million associated with the 2012-2013 annual EET rate adjustment filing, with rates effective October 1, 2014.

• January 2015 - SJG filed a petition with the BPU seeking to continue offering energy efficiency programs through June 2018 with a proposed budget of $56.0 million and with the same rate recovery mechanism that exists for its current EEPs.

• June 2015, SJG filed its annual EET rate adjustment petition, requesting a $7.6 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with EEPs.

• August 2015, the BPU approved a two-year extension of SJG's EEPs through August 31, 2017, with a program budget of $36.3 million. The BPU’s approval permitted SJG to adjust its EET rate, effective September 1, 2015, to increase annual revenues by $2.6 million, to recover projected costs and the allowed return on the first year of its investments in the EEP extension.

• 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”) through December 31, 2018, allowing SJG to spend the remainder of its existing BPU approved budget over the extended term. The BPU approved this extension in January 2017.

Societal Benefits Clause (SBC) - The SBC allows SJG to recover costs related to several BPU-mandated programs. Within the SBC are a Remediation Adjustment Clause (RAC), a New Jersey Clean Energy Program (NJCEP) and a Universal Service Fund (USF) program.

Regulatory actions regarding the SBC, with the exception of USF, which requires separate regulatory filings, were as follows:

• July 2014 - SJG made its annual 2014-2015 SBC filing requesting a $25.7 million decrease in SBC revenues. The BPU approved this filing in May 2015.

• July 2015 - SJG made its annual 2015-2016 SBC filing, requesting a $5.0 million decrease in SBC revenues. The BPU approved this filing in April 2016.

• July 2016 - SJG made its annual 2016-2017 SBC filing, requesting a $16.0 million increase in SBC revenues. This petition is currently pending.

Remediation Adjustment Clause (RAC) - The RAC recovers environmental remediation costs of 12 former gas manufacturing plants (see Note 15). The BPU allows SJG to recover such costs over seven-year amortization periods. The net between the amounts actually spent and amounts recovered from customers is recorded as a regulatory asset, "Environmental Remediation Cost Expended - Net." RAC activity affects revenue and cash flows but does not directly affect earnings because of the cost recovery over seven-year amortization periods. As of December 31, 2016 and 2015, SJG reflected the unamortized remediation costs of $72.0 million and $42.0 million, respectively, on the consolidated balance sheets under Regulatory Assets (see Note 11). Since implementing the RAC in 1992, SJG has recovered $112.7 million through rates.

Clean Energy Program Clause (CLEP) - A component of the SBC, the CLEP recovers costs associated with state mandated NJCEP as it relates to SJG's energy efficiency and renewable energy programs. In June 2013, the BPU approved a NJCEP funding level of $345.0 million through June 2014, of which SJG was responsible for $14.5 million. In June 2014, the BPU approved a NJCEP funding level of $345.0 million through June 2015, of which SJG was responsible for $14.5 million. In June 2015, the BPU approved a NJCEP funding level of $345.0 million through June 2016, of which SJG was responsible for $14.6 million.  In June of 2016, the BPU approved a NJCEP funding level of $345.0 million through June 2017, of which SJG was responsible for $14.6 million.

CLEP 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.

Universal Service Fund (USF) - The USF is a statewide program through which funds for the USF and Lifeline Credit and Tenants Assistance Programs are collected from customers of all New Jersey electric and gas utilities. USF adjustments affect cash flows but do not directly affect revenue or earnings as related costs are deferred and recovered through rates on an on-going basis.

Separate regulatory actions regarding the USF were as follows:

• June 2014 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to increase the statewide gas revenues by $19.9 million. This proposal was designed to increase SJG’s annual USF revenue by $2.6 million.

• September 2014 - The BPU approved the statewide budget of $71.8 million for all the State’s gas utilities.  SJG's portion of the total is approximately $7.9 million, which increased rates effective October 1, 2014, resulting in a $2.6 million increase to its USF recoveries.

• June 2015 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to decrease the statewide gas revenues by $46.4 million. This proposal was designed to decrease SJG’s annual USF revenue by $3.4 million.

• September 2015 - The BPU approved the statewide budget of $46.4 million for all the State’s gas utilities.  SJG's portion of the total is approximately $5.2 million, which decreased rates effective October 1, 2015, resulting in a $3.4 million decrease to its USF recoveries.

• 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.

Other Regulatory Matters-

Unbundling - This allows all natural gas consumers to select their natural gas commodity supplier. As of December 31, 2016, 33,467 of SJG's customers were purchasing their gas commodity from someone other than 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 utility 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 recovers 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 2014 base rate case, it was permitted to recover previously deferred pipeline integrity costs incurred from October 2010 through June 2014.  In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in the next base rate proceeding, subject to review by the BPU.  As of December 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 11).

Filings and petitions described above are still pending, unless otherwise indicated.

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REGULATORY ASSETS & REGULATORY LIABILITIES

12 Months Ended

Dec. 31, 2016

Regulatory Assets and Liabilities Disclosure [Abstract]

REGULATORY ASSETS & REGULATORY LIABILITIES

REGULATORY ASSETS & REGULATORY LIABILITIES:

The discussion under Note 10, Rates and Regulatory Actions, is integral to the following explanations of specific regulatory assets and liabilities.

Regulatory Assets consisted of the following items (in thousands):

	December 31, 2016		December 31, 2015
Environmental Remediation Costs:
Expended - Net	$	71,997	$	42,032
Liability for Future Expenditures	153,047		123,194
Deferred Asset Retirement Obligation Costs	43,014		42,430
Deferred Pension and Other Postretirement Benefit Costs	85,693		79,779
Deferred Gas Costs - Net	—		2,701
Conservation Incentive Program Receivable	27,567		2,624
Deferred Interest Rate Contracts	7,365		7,631
Energy Efficiency Tracker	219		496
Pipeline Supplier Service Charges	2,122		3,776
Pipeline Integrity Cost	4,810		4,596
AFUDC - Equity Related Deferrals	12,434		11,423
Other Regulatory Assets	2,478		2,752
Total Regulatory Assets	$	410,746	$	323,434

Except where noted below, all regulatory assets are or will be recovered through utility rate charges, as detailed in the following discussion. SJG is currently permitted to recover interest on 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 - SJG has two regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or its predecessors previously operated gas manufacturing plants. 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 SJG 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.  SJG 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" and "Deferred Credits and Other Noncurrent Liabilities." The BPU allows SJG to recover the deferred costs over seven-year periods after they are spent. The increase from December 31, 2015 is a result of expenditures made during 2016 and an increase in the expected future expenditures for remediation activities, primarily due to an increase in the scope of the remediation at a site related to additional contamination being discovered.

Deferred Asset Retirement Obligation (ARO) Costs - This regulatory asset resulted from the recording of ARO and additional utility plant, primarily related to a legal obligation SJG has for certain safety requirements upon the retirement of its gas distribution and transmission system. SJG recovers asset retirement costs through rates charged to customers. All related accumulated accretion and depreciation amounts for these ARO represent timing differences in the recognition of retirement costs that SJG is currently recovering in rates and, as such, SJG is deferring such differences as regulatory assets.

Deferred Pension and Other Postretirement Benefit Costs - The BPU authorized SJG to recover costs related to postretirement benefits under the accrual method of accounting consistent with GAAP. SJG's regulatory asset represents the recognition of the underfunded positions of SJG'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 Note 12).

Deferred Gas Costs - Net- Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability (see Note 10). Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval (see Note 16).

Conservation Incentive Program Receivable - The impact of the CIP is recorded as an adjustment to earnings as incurred, while cash recovery under the CIP generally occurs during the subsequent CIP year (see Note 10).

Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 16.

Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program.

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 10).

Pipeline Integrity Cost - As part of SJG's September 2014 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2014. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in SJG's next base rate proceeding, subject to review by the BPU (see Note 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 balance is being amortized over the life of the associated utility plant.

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.

Regulatory Liabilities consisted of the following items (in thousands):

	December 31, 2016		December 31, 2015
Excess Plant Removal Costs	$	28,226	$	32,644
Deferred Revenue - Net	17,800		—
Societal Benefit Costs Payable	3,095		10,197
Total Regulatory Liabilities	$	49,121	$	42,841

Excess Plant Removal Costs- Represents amounts accrued in excess of actual utility plant removal costs incurred to date.  As part of SJG's September 2014 base rate increase, SJG is required to amortize approximately $1.1 million of this balance to depreciation expense each year.

Deferred Revenue - Net - The BGSS changed from a $2.7 million regulatory asset at December 31, 2015 to a $17.8 million regulatory liability at December 31, 2016, primarily due to the gas costs recovered from customers exceeding the actual cost of the commodity. See previous discussion under "Deferred Gas Costs - Net" above.

Societal Benefit Costs Payable - This regulatory liability primarily represents cumulative costs less recoveries under the USF and CLEP programs (see Note 10).

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PENSION AND OTHER POSTRETIREMENT BENEFITS

12 Months Ended

Dec. 31, 2016

Compensation and Retirement Disclosure [Abstract]

PENSION AND OTHER POSTRETIREMENT BENEFITS

PENSION AND OTHER POSTRETIREMENT BENEFITS:

SJI has several defined benefit pension plans and other postretirement benefit plans. Approximately 38.2% of the Company's current, full-time, regular employees will be entitled to annuity payments upon retirement. Participation in the Company's qualified defined benefit pension plans was closed to new employees beginning in 2003; however, employees who are not eligible for these pension plans are eligible to receive an enhanced version of SJI's defined contribution plan. Certain SJI officers also participate in a non-funded supplemental executive retirement plan (SERP), a non-qualified defined benefit pension plan. The other postretirement benefit plans provide health care and life insurance benefits to some retirees.

Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):

	Pension Benefits
	2016			2015			2014
Service Cost	$	4,843		$	5,337		$	4,510
Interest Cost	12,125			11,168			10,735
Expected Return on Plan Assets	(13,508		)	(14,789		)	(13,491		)
Amortizations:
Prior Service Cost	212			212			175
Actuarial Loss	9,394			10,608			5,716
Net Periodic Benefit Cost	13,066			12,536			7,645
Capitalized Benefit Costs	(4,645		)	(4,805		)	(3,047		)
Deferred Benefit Costs	(645		)	(1,007		)	—
Total Net Periodic Benefit Expense	$	7,776		$	6,724		$	4,598

	Other Postretirement Benefits
	2016			2015			2014
Service Cost	$	851		$	1,116		$	891
Interest Cost	2,615			2,973			2,852
Expected Return on Plan Assets	(3,104		)	(2,993		)	(2,603		)
Amortizations:
Prior Service (Credits) Cost	(344		)	608			152
Actuarial Loss	1,109			1,342			974
Net Periodic Benefit Cost	1,127			3,046			2,266
Capitalized Benefit Costs	(277		)	(1,043		)	(722		)
Deferred Benefit Costs	—			(256		)	—
Total Net Periodic Benefit Expense	$	850		$	1,747		$	1,544

Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to the deferral of incremental expenses associated with the adoption of new mortality tables in 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case.

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 SJG recovers all prudently incurred pension and postretirement benefit costs from its ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this requirement are reported as regulatory assets (see Note 11).

Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands):

	Regulatory Assets						Accumulated Other Comprehensive Loss  (pre-tax)
	Pension Benefits			Other Postretirement Benefits			Pension Benefits			Other Postretirement Benefits
Balance at January 1, 2015	$	71,177		$	27,863		$	39,468		$	6,755
Amounts Arising during the Period:
Net Actuarial (Loss)/Gain	(463		)	(3,155		)	59			(2,285		)
Prior Service Cost				(499		)				(106		)
Amounts Amortized to Net Periodic Costs:
Net Actuarial Loss	(6,079		)	(1,107		)	(4,452		)	(221		)
Prior Service Cost	(203		)	(7,755		)	(9		)	(2,081		)
Balance at December 31, 2015	64,432			15,347			35,066			2,062
Amounts Arising during the Period:
Net Actuarial Gain	9,706			2,584			8,370			829
Prior Service Credit	—			257			—			84
Amounts Amortized to Net Periodic Costs:
Net Actuarial Loss	(5,485		)	(945		)	(3,838		)	(154		)
Prior Service Cost	(203		)	—			(8		)	—
Balance at December 31, 2016	$	68,450		$	17,243		$	39,590		$	2,821

The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2017 are as follows (in thousands): 

	Pension Benefits		Other Postretirement Benefits
Prior Service Cost/(Credit)	$	127	$	(257	)
Net Actuarial Loss	$	6,202	$	1,040

The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2017 are as follows (in thousands):

	Pension Benefits		Other Postretirement  Benefits
Prior Service Cost/(Credit)	$	5	$	(87	)
Net Actuarial Loss	$	3,943	$	207

A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands): 

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	$	254,195		$	265,434		$	57,430		$	75,592
Service Cost	4,843			5,337			851			1,116
Interest Cost	12,125			11,168			2,615			2,973
Actuarial Loss (Gain)	18,254			(17,349		)	3,121			(8,591		)
Retiree Contributions	—			—			81			700
Plan Amendments	—			—			—			(9,899		)
Benefits Paid	(11,129		)	(10,395		)	(3,748		)	(4,461		)
Benefit Obligation at End of Year	$	278,288		$	254,195		$	60,350		$	57,430
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	$	184,824		$	180,523		$	47,759		$	43,222
Actual Return on Plan Assets	13,569			(2,321		)	2,784			(423		)
Employer Contributions	2,278			17,017			3,656			8,721
Retiree Contributions	—			—			81			700
Benefits Paid	(11,129		)	(10,395		)	(3,748		)	(4,461		)
Fair Value of Plan Assets at End of Year	$	189,542		$	184,824		$	50,532		$	47,759
Funded Status at End of Year:	$	(88,746	)	$	(69,371	)	$	(9,818	)	$	(9,671	)
Amounts Related to Unconsolidated Affiliate	326			204			540			509
Accrued Net Benefit Cost at End of Year	$	(88,420	)	$	(69,167	)	$	(9,278	)	$	(9,162	)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$	(2,463	)	$	(2,261	)	$	—		$	—
Noncurrent Liabilities	(85,957		)	(66,906		)	(9,278		)	(9,162		)
Net Amount Recognized at End of Year	$	(88,420	)	$	(69,167	)	$	(9,278	)	$	(9,162	)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	$	538		$	741		$	(3,032	)	$	(3,289	)
Net Actuarial Loss	67,912			63,691			20,275			18,636
	$	68,450		$	64,432		$	17,243		$	15,347
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	$	69		$	77		$	(989	)	$	(1,074	)
Net Actuarial Loss	39,521			34,989			3,810			3,136
	$	39,590		$	35,066		$	2,821		$	2,062

The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of SJI's qualified employee pension plans were $224.3 million and $208.3 million, respectively, as of December 31, 2016; and $207.7 million and $191.9 million, respectively, as of December 31, 2015.  The ABO of these plans exceeded the value of the plan assets as of December 31, 2016 and 2015.  The value of these assets were $189.5 million and $184.8 million as of December 31, 2016 and 2015, respectively, and can be seen in the table above. The PBO and ABO for SJI's non-funded SERP were $53.9 million and $51.9 million, respectively, as of December 31, 2016; and $46.5 million and $45.0 million, respectively, as of December 31, 2015. The SERP obligation is reflected in the tables above and has no assets.

The weighted-average assumptions used to determine benefit obligations at December 31 were:

	Pension Benefits				Other Postretirement Benefits
	2016		2015		2016		2015
Discount Rate	4.30	%	4.83	%	4.13	%	4.73	%
Rate of Compensation Increase	3.50	%	3.50	%	3.50	%	3.50	%

The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were:

	Pension Benefits						Other Postretirement Benefits
	2016		2015		2014		2016		2015		2014
Discount Rate	4.83	%	4.25	%	5.09	%	4.73	%	4.20	%	4.91	%
Expected Long-Term Return on Plan Assets	7.50	%	7.75	%	7.75	%	6.50	%	6.25	%	6.25	%
Rate of Compensation Increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%

In 2014, the Society of Actuaries (SOA) released new mortality tables (RP-2014 base table with MP-2014 generational projection scale), which indicated that the average life expectancy of both active and retired plan participants had increased. Obligations as of December 31, 2014, disclosed herein reflect the use of those new 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, 2016 and 2015, disclosed herein, reflect the use of the updated 2015 tables. While the adoption of the new tables impacts liabilities significantly as of December 31of the year of adoption, the impact on expense did not occur until the subsequent year.

The discount rates used to determine the benefit obligations at December 31, 2016 and 2015, 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'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. 

The retiree medical plan changed effective January 1, 2016. Retirees are provided a fixed contribution to a health reimbursement account, allowing them to obtain coverage from health-care exchanges, rather than utilizing the Company provided health-care plan. Since the health-care benefits are now a fixed dollar amount under the new plan and will not increase in the future, the plan no longer has health care trend assumptions as of December 31, 2015. As a result, assumed health care cost trend rates no longer have a significant effect on the amounts reported for SJI's postretirement health care plans.

PLAN ASSETS - The Company'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 has implemented this diversification strategy primarily with commingled common/collective trust funds.  The target allocations for pension plan assets are 28-48 percent U.S. equity securities, 13-25 percent international equity securities, 32-42 percent fixed income investments, and 0-7 percent to all other types of investments.  Equity securities include investments in commingled common/collective trust funds as well as large-cap and mid-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.  We 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.

SJI evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2016.  Types of concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, and individual fund.  As of December 31, 2016, there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in SJI's pension and other postretirement benefit plan assets.

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 17, which will serve as the basis for presentation throughout the remainder of this Note.

The fair values of SJI's pension plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands): 

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2016
Cash / Cash Equivalents:
Cash	$	63	$	63	$	—	$	—
Common/Collective Trust Funds (a)	460		—		460		—
STIF-Type Instrument (b)	1,431		—		1,431		—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	51,902		—		51,902		—
Common/Collective Trust Funds - International (a)	33,096		—		33,096		—
U.S. Large-Cap (c)	17,792		17,792		—		—
U.S. Mid-Cap (c)	2,479		2,479		—		—
International (c)	3,340		3,340		—		—
Fixed Income:
Common/Collective Trust Funds (a)	54,970		—		54,970		—
Guaranteed Insurance Contract (d)	9,714		—		—		9,714
Other types of investments:
Private Equity Fund (f)	5,100		—		—		5,100
Common/Collective Trust Fund - Real Estate (g)	9,195		—		—		9,195
Total	$	189,542	$	23,674	$	141,859	$	24,009

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2015
Cash / Cash Equivalents:
Cash	$	35	$	35	$	—	$	—
Common/Collective Trust Funds (a)	858		—		858		—
STIF-Type Instrument (b)	1,360		—		1,360		—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	52,058		—		52,058		—
Common/Collective Trust Funds - International (a)	33,236		—		33,236		—
U.S. Large-Cap (c)	14,305		14,305		—		—
U.S. Mid-Cap (c)	3,407		3,407		—		—
U.S. Small-Cap (c)	260		260		—		—
International (c)	1,695		1,695		—		—
Fixed Income:
Common/Collective Trust Funds (a)	50,664		—		50,664		—
Guaranteed Insurance Contract (d)	9,960		—		—		9,960
Hedge Funds (e)	4,159		—		—		4,159
Other types of investments:
Private Equity Fund (f)	4,312		—		—		4,312
Common/Collective Trust Fund - Real Estate (g)	8,515		—		—		8,515
Total	$	184,824	$	19,702	$	138,176	$	26,946

(a) 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 markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.

(b) 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.

(c) 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.

(d) 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.

(e) This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments.

(f) This category represents a limited partnership/commingled trust 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 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments.  Fund investments are illiquid and resale is restricted.  These funds are classified as Level 3 investments.

(g) 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.  Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments.

Fair Value Measurement Using Significant

Unobservable Inputs (Level 3)

(In thousands)

	Guaranteed						Private
	Insurance			Hedge			Equity			Real
	Contract			Funds			Funds			Estate		Total
Balance at January 1, 2015	$	10,912		$	4,331		$	3,616		$	7,476	$	26,335
Actual return on plan assets:
Relating to assets still held at the reporting date	(106		)	(172		)	(302		)	1,039		459
Relating to assets sold during the period	25			—			429			—		454
Purchases, Sales and Settlements	(871		)	—			569			—		(302		)
Balance at December 31, 2015	9,960			4,159			4,312			8,515		26,946
Actual return on plan assets:
Relating to assets still held at the reporting date	541			(67		)	(140		)	680		1,014
Relating to assets sold during the period	14			—			245			—		259
Purchases, Sales and Settlements	(801		)	(4,092		)	683			—		(4,210		)
Balance at December 31, 2016	$	9,714		$	—		$	5,100		$	9,195	$	24,009

As with the pension plan assets, the Company'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 has 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 30-43 percent U.S. equity securities, 20-30 percent international equity securities, and 32-42 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 SJI's other postretirement benefit plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands):

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2016:
Cash	$	—	$	—	$	—	$	—
Equity Securities:
Common/Collective Trust Funds - U.S. (a)	$	14,878	$	—	$	14,878	$	—
Common/Collective Trust Funds - International (a)	8,674		—		8,674		—
Fixed Income:
Common/Collective Trust Funds - Bonds (a)	13,537		—		13,537		—
Other Types of Investments:
Company Owned Life Insurance (c)	13,443		—		13,443		—
Total	$	50,532	$	—	$	50,532	$	—
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)	$	13,522	$	—	$	13,522	$	—
Common/Collective Trust Funds - International (a)	8,313		—		8,313		—
Mutual Fund - U.S. (b)	1,309		1,309		—		—
Mutual Funds - International (b)	983		983		—		—
Fixed Income:
Common/Collective Trust Funds - Bonds (a)	13,187		—		13,187		—
Mutual Funds - Bonds (b)	1,441		1,441		—		—
Other Types of Investments:
Mutual Funds - REITS (b)	152		152		—		—
Company Owned Life Insurance (c)	8,826		—		8,826		—
Total	$	47,759	$	3,911	$	43,848	$	—

(a) 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 markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.

(b) 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.

(c) This category represents Company-owned life insurance policies with a nationally known life insurance company. The value of these policies is backed by a series of common/collective trust funds held by the insurance carrier similar to category (a) above. Holdings in these insurance policies are classified as Level 2 investments.

FUTURE BENEFIT PAYMENTS - The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following years (in thousands):

	Pension Benefits		Other Postretirement Benefits
2017	$	12,141	$	4,399
2018	$	12,583	$	4,316
2019	$	13,529	$	4,403
2020	$	14,056	$	4,514
2021	$	14,757	$	4,511
2022 - 2025	$	86,727	$	21,308

CONTRIBUTIONS - SJI contributed $15.0 million to the pension plans in 2015, with no pension contribution made in 2016 or 2014. Payments related to the unfunded SERP plan in 2016, 2015 and 2014 were $2.3 million, $2.0 million and $1.5 million, respectively. SERP payments are expected to approximate $2.5 million in 2017. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to its other postretirement benefit plans’ trusts, less costs incurred directly by SJG.

DEFINED CONTRIBUTION PLAN - SJI offers an Employees' Retirement Savings Plan (Savings Plan) to eligible employees.  For employees eligible for participation in SJI's defined benefit pension plan, SJI matches 50% of participants' contributions up to 6% of base compensation. For employees who are not eligible for participation in SJI's defined benefit pension plans, SJI matches 50% of participants' contributions up to 8% of base compensation. Employees not eligible for the pension plans also receive a year-end contribution of $1,500, if 10 or fewer years of service, or $2,000, if more than 10 years of service. The amount expensed and contributed for the matching provision of the Savings Plan approximated $2.3 million, $2.1 million and $2.0 million for the years ended December 31, 2016, 2015 and 2014, respectively.

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LINES OF CREDIT

12 Months Ended

Dec. 31, 2016

Line of Credit Facility [Abstract]

LINES OF CREDIT

LINES OF CREDIT:

Credit facilities and available liquidity as of December 31, 2016 were as follows (in thousands):

Company	Total Facility		Usage			Available Liquidity		Expiration Date
SJG:
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 SJG	210,000		105,100			104,900
SJI:
Revolving Credit Facility	450,000		196,600		(B)	253,400		Various	(C)
Total SJI	450,000		196,600			253,400
Total	$	660,000	$	301,700		$	358,300

(A) Includes letters of credit outstanding in the amount of $0.8 million.

(B) Includes letters of credit outstanding in the amount of $4.8 million.

(C) In September 2016, the Company entered into an unsecured $50.0 million, 364-day revolving credit agreement. The agreement matures September 2017, at which time the principal and any accrued but unpaid interest must be paid. At the annual request of the Company, but on not more than two occasions, the credit agreement may be extended for an additional period of 364 days. The 364-day revolving facility bears interest at a variable base rate or a variable London Interbank Offered Rate (“LIBOR”), at the Company’s election.

The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.47%, 1.13% and 0.83% at December 31, 2016, 2015 and 2014, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $321.9 million and $335.0 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $467.7 million and $471.1 million, respectively.

The SJI and SJG facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1, measured at the end of each fiscal quarter.

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.

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LONG-TERM DEBT

12 Months Ended

Dec. 31, 2016

Debt Disclosure [Abstract]

LONG-TERM DEBT

LONG-TERM DEBT:

Outstanding Long-Term Debt at December 31 consisted of the following:

			2016			2015
Long-Term Debt (A):
South Jersey Gas Company:
First Mortgage Bonds: (B)
5.437%		Series due 2016 (C)	$	—		$	10,000
4.6%		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 Bonds at variable rates due 2036 (J)			24,900			24,900
SJG Term Facility (K)			200,000			139,000
Marina Energy LLC:  (L)
Series A 2001 Bonds at variable rates due 2031			20,000			20,000
Series B 2001 Bonds at variable rates due 2021			25,000			25,000
Series A 2006 Bonds at variable rates due 2036			16,400			16,400
South Jersey Industries:
2.71%		Series B 2012 Notes due 2017 (M)	16,000			16,000
3.05%		Series due 2019	60,000			60,000
3.05%		Series due 2019	30,000			30,000
3.05%		Series due 2019	50,000			50,000
3.46%		Series C 2012 Notes due 2022	35,000			35,000
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
ACB Energy Partners, LLC:
7.60	%	Loan & Security Agreement (P)	—			12,735
Other Energy Project Debt (Q):
4.83	%	ACLE	—			3,551
4.83	%	SCLE	—			1,738
4.83	%	SXLE	—			3,433
Total Long-Term Debt Outstanding (R)			$	1,047,482		$	1,035,848
Less Current Maturities			(231,909		)	(29,454		)
Total Long-Term Debt (R)			$	815,573		$	1,006,394

(A) Long-term debt maturities for the succeeding five years are as follows (in thousands): 2017: $231,909; 2018: $38,909; 2019: $258,909; 2020: $67,909; and 2021: $52,909.

(B) The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. In January 2017, the First Mortgage was amended and restated in its entirety (see Note 19).

(C) In July 2016, SJG retired $17.0 million of 4.60% Medium Term Notes (MTN's) at maturity. In August 2016, SJG retired $10.0 million of 5.437% MTN's at maturity.

(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.

(I) SJG has $50.0 million of 4.01% MTN's with several due dates, as follows: $8.0 million each due November 2018 and 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) These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2016 was 0.74%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August 2018. These bonds contain no financial covenants.

(K) SJG had a $200.0 million multiple-draw term facility offered by a syndicate of banks which was set to expire in June 2017. This facility bore interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of December 31, 2015, SJG had borrowed an aggregate $139.0 million under this facility at an average interest rate of 1.17% and the proceeds were used to pay down short-term debt. In January 2016, SJG issued an additional $61.0 million of long-term debt at an average interest rate of 1.41% under this facility. As such, 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 it was due within one year. In January 2017, this term facility was paid in full (see Note 19).

(L) Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2016 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.72%, 0.73% and 0.72% respectively. The interest rate on all but $46.1 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026.  These bonds contain no financial covenants.  Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March 2018.

(M) As of December 31, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017, are classified in current portion of long-term debt on the consolidated balance sheets. SJI plans to pay off this debt at maturity.

(N) At December 31, 2016, the floating rate on these Senior Notes was 2.32%.

(O) In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2016 was 1.79%.

(P) ACB had a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million. Under the LSA, ACB paid principal and interest (at a fixed rate of 7.60%) in equal quarterly installments that began in February 2011 and was scheduled to run through February 2021. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In January 2016, the Company paid $12.7 million to retire outstanding debt.

(Q) ACLE, SCLE and SXLE (the "Other Energy Projects") had long-term debt agreements with a third party to borrow up to $10.0 million. Under the debt agreements, the Other Energy Projects paid principal and interest (at a fixed rate of 4.83%) in equal installments that began December 2013 and was scheduled to run through December 2020. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the outstanding debt of $8.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In August 2016, the Company paid an aggregate $8.3 million to retire outstanding long-term debt for the Other Energy Projects.

(R) Total Long-Term Debt in the table above does not include unamortized debt issuance costs of $7.6 million and $9.0 million for the years ended December 31, 2016 and 2015, respectively, which were reclassified to Long-Term Debt on the consolidated balance sheets to conform to ASU 2015-03 (see Note 1).

In December 2015, SJG filed a petition with the BPU to issue up to $400.0 million of long term debt securities in various forms including MTN's and unsecured debt, with maturities of more than 12 months, over the next three years. This petition was approved in March 2016.

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COMMITMENTS AND CONTINGENCIES

12 Months Ended

Dec. 31, 2016

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES:

GAS SUPPLY CONTRACTS - In the normal course of business, SJG and SJRG 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. SJRG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services is approximately $0.5 million per month. SJG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services averages approximately $5.6 million per month and is recovered on a current basis through the BGSS.  SJRG has also committed to purchase a minimum of 745,000 dts/d and up to 940,000 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index based prices.

PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary.

The Company is currently involved in a pricing dispute related to two long-term gas supply contracts whereby the Company had sued the supplier to recover amounts that were improperly invoiced. Subsequently, the supplier countersued the Company claiming it is owed an amount which we extrapolate to be $14.9 million from SJG, plus interest, and $40.2 million from SJRG, plus interest, through December 31, 2016. We believe any monies received or paid associated with the SJG claims would reflect gas costs that would be recovered from SJG's customers through adjusted rates.

The Company is also involved in a dispute related to a three-year capacity management contract with a counterparty whereby the Company is the manager. The counterparty is claiming that it is owed approximately $13.3 million, plus interest, from SJRG under a sharing credit within the contract.

Liabilities related to these claims are accrued when the amount or range of amounts of probable settlement costs or other charges for these claims can be reasonably estimated. The Company has accrued approximately $3.1 million and $3.2 million related to all claims in the aggregate as of December 31, 2016 and 2015, respectively. Although the Company does not presently believe that these matters will have a material adverse effect on its business, given the inherent uncertainties in such situations, the Company can provide no assurance regarding the outcome of litigation.

COLLECTIVE BARGAINING AGREEMENTS— Unionized personnel represent approximately 45.0% of our workforce at December 31, 2016. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76.  SJG and SJESP employees represented by the IBEW operate under collective bargaining agreements that run through February 2018. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017.

GUARANTEES - As of December 31, 2016, 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 and for Marina's construction and operating activities. As of December 31, 2016, these guarantees support future firm commitments of SJI's consolidated subsidiaries and $125.4 million of the Accounts Payable already recorded on SJI's consolidated balance sheet.

As of December 31, 2016, SJI had issued $6.0 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

STANDBY LETTERS OF CREDIT — As of December 31, 2016, SJI provided $4.8 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 $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. The Company also provided $87.5 million of additional letters of credit under separate facilities outside of the revolving credit facilities to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.

ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage.

SJI successfully entered into settlements with all of its historic comprehensive general liability carriers regarding the environmental remediation expenditures at the SJG sites. Also, SJG had purchased a Cleanup Cost Cap Insurance Policy limiting the amount of remediation expenditures that SJG was required to make at 11 of its sites. This policy provided coverage up to $50.0 million, which was exhausted in 2012.

Since the early 1980s, SJI accrued environmental remediation costs of $437.1 million, of which $282.1 million was spent as of December 31, 2016.

The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands):

	2016			2015
Beginning of Year	$	126,623		$	128,172
Accruals	60,713			19,489
Expenditures	(32,323		)	(21,038		)
End of Year	$	155,013		$	126,623

The balances are segregated between current and noncurrent on the consolidated balance sheets under the captions Current Liabilities and Deferred Credits and Other Noncurrent Liabilities.

Management estimates that undiscounted future costs to clean up SJG's sites will range from $153.0 million to $257.1 million. Six of SJG's 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. SJG recorded the lower end of this range 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. 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 SJG'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 continued implementation of the approved remedy, 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 is being developed for proposal to the regulatory authority. Steps remaining to remediate the site include selection of a final remedy, 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 - Remedial investigation activities are complete at this site and a final remedy has been approved by the regulatory authority.  Steps remaining to remediate the site include installation of a sub-surface containment unit, post remediation groundwater monitoring, and issuance of a Response Action Outcome.

Site 5 -The remedial action to address impacted soil at the site is ongoing. Steps remaining include long-term groundwater monitoring and issuance of a Response Action Outcome.

Site 6 - Remedial investigation activities have been completed at this site and a final site remedy is being developed for proposal to the regulatory authority. Steps remaining to remediate the site include selection of a final remedy, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy and issuance of a Response Action Outcome.

With Morie's sale in 1996, EMI assumed responsibility for environmental liabilities currently estimated between $1.3 million and $2.1 million. The information available on these sites is sufficient only to establish a range of probable liability and no point within the range is more likely than any other. Therefore, EMI has accrued the lower end of the range. 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 future remediation of five sites where fuel oil operations existed years ago to range from $0.7 million to $1.3 million. The lower end of this range has been recorded under Current Liabilities and Deferred Credits and Other Noncurrent Liabilities as of December 31, 2016.

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DERIVATIVE INSTRUMENTS

12 Months Ended

Dec. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS:

Certain SJI subsidiaries 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. The Company uses 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, 2016, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 67.9 MMdts of expected future purchases of natural gas, 62.1 MMdts of expected future sales of natural gas, 2.3 MMmwh of expected future purchases of electricity and 1.7 MMmwh of expected future sales of electricity.  In addition to these derivative contracts, the Company has basis and index related purchase and sales contracts totaling 141.6 MMdts.  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. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.

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 gas operations of SJE transact commodities on a physical basis and typically does not directly enter into positions that financially settle. SJRG performs this risk management function for SJE and enters into the types of financial transactions noted above. 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.

The Company 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 have 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 for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously recorded in Accumulated Other Comprehensive Loss (AOCL) on the consolidated balance sheets, are being recorded into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.

As of December 31, 2016, SJI's active interest rate swaps were as follows:

Notional Amount		Fixed Interest Rate	Start Date	Maturity	Type of Debt	Obligor
$	14,500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	330,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	12,500,000	3.530%	12/1/2006	2/1/2036	Tax-exempt	SJG
$	12,500,000	3.430%	12/1/2006	2/1/2036	Tax-exempt	SJG

The unrealized gains and losses on interest rate derivatives that are not designated as cash flow hedges are included in Interest Charges. 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):

Derivatives not designated as hedging instruments under GAAP	2016				2015
	Assets		Liabilities		Assets		Liabilities
Energy-related commodity contracts:
Derivatives – Energy Related – Current	$	72,391	$	60,082	$	83,093	$	90,708
Derivatives – Energy Related – Non-Current	8,502		4,540		16,238		21,697
Interest rate contracts:
Derivatives - Other - Current	—		681		—		—
Derivatives - Other - Non-Current	—		9,349		—		10,943
Total derivatives not designated as hedging instruments under GAAP	80,893		74,652		99,331		123,348
Total Derivatives	$	80,893	$	74,652	$	99,331	$	123,348

The Company enters into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. The Company presents derivatives at gross fair values on the consolidated balance sheets. As of December 31, 2016 and2015, information related to these offsetting arrangements were as follows (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	$	80,893		$	—	$	80,893		$	(38,809	)	(A)	$	(3,474	)	$	38,610
Derivatives - Energy Related Liabilities	$	(64,622	)	$	—	$	(64,622	)	$	38,809		(B)	$	—		$	(25,813	)
Derivatives - Other	$	(10,030	)	$	—	$	(10,030	)	$	—			$	—		$	(10,030	)

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	$	99,331		$	—	$	99,331		$	(35,491	)	(A)	$	—	$	63,840
Derivatives - Energy Related Liabilities	$	(112,405	)	$	—	$	(112,405	)	$	35,491		(B)	$	23,045	$	(53,869	)
Derivatives - Other	$	(10,943	)	$	—	$	(10,943	)	$	—			$	—	$	(10,943	)

(A) The balances at December 31, 2016 and 2015 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at December 31, 2016 and 2015 were related to derivative assets which can be net settled against derivative liabilities.

The effect of derivative instruments on the statements of consolidated income and comprehensive income for the year ended December 31 is as follows (in thousands):

Derivatives in Cash Flow Hedging Relationships	2016			2015			2014
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	—		$	—
Losses reclassified from AOCL into income (a)	$	(333	)	$	(551	)	$	(419	)
Losses recognized in income on ineffective portion (a)	$	—		$	—		$	—

(a) Included in Interest Charges

Derivatives Not Designated as Hedging Instruments under GAAP	2016		2015		2014
Gains (losses) on energy-related commodity contracts (a)	$	26,935	$	8,401	$	(6,592	)
Gains (losses) on interest rate contracts (b)	647		96		(467		)
Total	$	27,582	$	8,497	$	(7,059	)

(a)  Included in Operating Revenues - Nonutility

(b)  Included in Interest Charges

Net realized (losses) gains associated with SJG’s energy-related financial commodity contracts of $(3.0) million, $(9.1) million and $1.7 million for the years ended 2016, 2015 and 2014, respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy-related financial commodity contracts are deferred in Regulatory Assets or Liabilities, as applicable, and there is no impact on earnings.

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, 2016, is $9.6 million.  If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2016, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $8.1 million after offsetting asset positions with the same counterparties under master netting arrangements.

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES

12 Months Ended

Dec. 31, 2016

Fair Value Disclosures [Abstract]

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES:

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	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	32	$	32	$	—	$	—
Derivatives – Energy Related Assets (B)	80,893		33,994		11,814		35,085
	$	80,925	$	34,026	$	11,814	$	35,085
Liabilities
Derivatives – Energy Related Liabilities (B)	$	64,622	$	16,502	$	22,070	$	26,050
Derivatives – Other (C)	10,030		—		10,030		—
	$	74,652	$	16,502	$	32,100	$	26,050

As of December 31, 2015	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	14,810	$	2,925	$	11,885	$	—
Derivatives – Energy Related Assets (B)	99,331		16,006		24,730		58,595
	$	114,141	$	18,931	$	36,615	$	58,595
Liabilities
Derivatives – Energy Related Liabilities (B)	$	112,405	$	42,170	$	11,008	$	59,227
Derivatives – Other (C)	10,943		—		10,943		—
	$	123,348	$	42,170	$	21,951	$	59,227

(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 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, except for ranges):

Type	Fair Value at December 31, 2016				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	23,301	$	18,109	Discounted Cash Flow	Forward price (per dt)	$1.03 - $11.33 [$2.71]	(A)
Forward Contract - Electric	$	11,784	$	7,941	Discounted Cash Flow	Fixed electric load profile (on-peak)	21.43% - 100.00% [55.14%]	(B)
						Fixed electric load profile (off-peak)	0.00% - 78.57% [44.86%]	(B)

Type	Fair Value at December 31, 2015				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	29,459	$	31,733	Discounted Cash Flow	Forward price (per dt)	$(0.77) - $10.00 [$2.15]	(A)
Forward Contract - Electric	$	29,136	$	27,494	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.47% - 100.00% [56.20%]	(B)
						Fixed electric load profile (off-peak)	0.00% - 91.53% [43.80%]	(B)

(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, 2016 and 2015, using significant unobservable inputs (Level 3), are as follows (in thousands):

	Year Ended December 31, 2016
Balance at January 1, 2016	$	(632	)
Other changes in fair value from continuing and new contracts, net	5,657
Transfers in to/(out of) of Level 3 (A)	4,116
Settlements	(106		)
Balance at December 31, 2016	$	9,035

	Year Ended December 31, 2015
Balance at January 1, 2015	$	(5,608	)
Other changes in fair value from continuing and new contracts, net	(5,069		)
Transfers in to/(out of) of Level 3 (A)	7,402
Settlements	2,643
Balance at December 31, 2015	$	(632	)

(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.  During the years ended December 31, 2016 and 2015, $4.1 million and $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management.

Total gains for 2016 included in earnings for the year ended December 31, 2016 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, 2016, are $5.7 million.  These gains are included in Operating Revenues-Nonutility on the statements of consolidated income.

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ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL)

12 Months Ended

Dec. 31, 2016

Equity [Abstract]

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL)

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL):

The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2016 (in thousands):

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Total
Balance at January 1, 2016 (a)	$	(22,145	)	$	(2,129	)	$	(128	)	$	(97	)	$	(24,499	)
Other comprehensive income before reclassifications	(5,617		)	—			323			—			(5,294		)
Amounts reclassified from AOCL (b)	2,420			197			(205		)	—			2,412
Net current period other comprehensive income	(3,197		)	197			118			—			(2,882		)
Balance at December 31, 2016 (a)	$	(25,342	)	$	(1,932	)	$	(10	)	$	(97	)	$	(27,381	)

(a) Determined using a combined average statutory tax rate of 40%.

(b) See table below.

The following table provides details about reclassifications out of AOCL for the year ended December 31, 2016 (in thousands):

	Amounts Reclassified from AOCL			Affected Line Item in the Statements of Consolidated Income
	For the Year Ended December 31, 2016
Actuarial Loss on Postretirement Benefits	$	4,001		Operating Expenses: Operations
Income Taxes	(1,581		)	Income Taxes (a)
	$	2,420
Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	333		Interest Charges
Income Taxes	(136		)	Income Taxes (a)
	$	197
Unrealized Gain on Available-for-Sale Securities	$	(342	)	Other Income
Income Taxes	137			Income Taxes (a)
	$	(205	)
Losses from reclassifications for the period net of tax	$	2,412

(a) Determined using a combined average statutory tax rate of 40%.

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SUBSEQUENT EVENTS

12 Months Ended

Dec. 31, 2016

Subsequent Events [Abstract]

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS:

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 (see Note 14). The New Mortgage 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.

In January 2017, SJG issued $200.0 million aggregate principal amount of MTN's, Series E, 2017, due January 2047, with principal payments beginning in 2025. The MTN's bear interest at an annual rate of 3.0% payable semiannually. Proceeds were used to pay down the $200.0 million multiple-draw term facility which was set to expire in June 2017.

In January 2017, SJG entered into an unsecured, $200.0 million 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 million on January 31, 2017. All loans under the Credit Agreement become due in January 2019.     

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. SJG expects the base rate case to be concluded during 2017.

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Quarterly Financial Data (Unaudited)

12 Months Ended

Dec. 31, 2016

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Data (Unaudited)

Quarterly Financial Data (Unaudited)

(Summarized quarterly results of SJI's operations, in thousands except for per share amounts)

	2016 Quarter Ended												2015 Quarter Ended
	March 31			June 30			Sept. 30			Dec. 31			March 31			June 30			Sept. 30			Dec. 31
Operating Revenues	$	333,035		$	154,402		$	219,082		$	329,981		$	382,952		$	177,710		$	141,062		$	257,844
Expenses:
Cost of Sales - (Excluding depreciation)	152,975			98,340			142,988			186,684			241,707			90,945			99,124			127,566
Operations and Maintenance Including Fixed Charges	73,042			71,034			69,410			77,858			71,279			62,634			63,867			71,148
Income Taxes	39,267			(7,189		)	2,807			19,266			16,613			(3,279		)	(10,968		)	(1,006		)
Energy and Other Taxes	1,925			1,243			1,449			1,725			2,196			1,265			1,231			1,334
Total Expenses	267,209			163,428			216,654			285,533			331,795			151,565			153,254			199,042
Other Income and Expense	2,361			4,228			7,236			1,560			2,696			(12,804		)	(340		)	(7,854		)
Income (Loss) from Continuing Operations	68,187			(4,798		)	9,664			46,008			53,853			13,341			(12,532		)	50,948
Loss from Discontinued Operations  -  (Net of tax benefit)	(118		)	(29		)	(29		)	(75		)	(276		)	(74		)	(91		)	(62		)
Net Income (Loss)	$	68,069		$	(4,827	)	$	9,635		$	45,933		$	53,577		$	13,267		$	(12,623	)	$	50,886
Basic Earnings Per Common Share:
Continuing Operations	$	0.96		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Discontinued Operations	—			—			—			—			—			—			—			—
Basic Earnings Per Common Share	$	0.96		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Average Shares of Common Stock Outstanding - Basic	71,127			75,298			79,478			79,478			68,397			68,467			68,607			69,460
Diluted Earnings Per Common Share:
Continuing Operations	$	0.95		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Discontinued Operations	—			—			—			—			—			—			—			—
Diluted Earnings Per Common Share	$	0.95		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Average Shares of Common Stock Outstanding - Diluted	71,416			75,298			79,635			79,643			68,618			68,653			68,607			69,646

The sum of the quarters for basic and diluted earnings per common share for 2016 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 to the consolidated financial statements). The sum of the quarters for basic and diluted earnings per common share for 2015 does not equal the year's total due to rounding.

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. See Note 1 to the consolidated financial statements.

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.

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Schedule I

12 Months Ended

Dec. 31, 2016

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Schedule I

SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF INCOME

(In Thousands)

	2016			2015			2014
Management Service Fee Revenues	$	25,463		$	20,990		$	21,118
Operating Expenses:
Operations	23,852			17,979			18,183
Depreciation	377			406			439
Energy and Other Taxes	1,033			806			813
Total Operating Expenses	25,262			19,191			19,435
Operating Income	201			1,799			1,683
Other Income:
Equity in Earnings of Subsidiaries	119,061			105,610			97,628
Other	11,953			10,145			7,283
Total Other Income	131,014			115,755			104,911
Interest Charges	12,148			11,822			8,803
Income Taxes	6			122			163
Income from Continuing Operations	119,061			105,610			97,628
Equity in Undistributed Earnings of Discontinued Operations	(251		)	(503		)	(582		)
Net Income	$	118,810		$	105,107		$	97,046

SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(In Thousands)

	2016			2015			2014
Net Income	$	118,810		$	105,107		$	97,046
Other Comprehensive Income (Loss) - Net of Tax*
Postretirement Liability Adjustment	(3,197		)	5,518			(9,160		)
Unrealized Gain (Loss) on Available-for-Sale Securities	118			(53		)	(472		)
Unrealized Gain on Derivatives - Other	197			294			134
Total Other Comprehensive (Loss) Income - Net of Tax*	(2,882		)	5,759			(9,498		)
Comprehensive Income	$	115,928		$	110,866		$	87,548

*  Determined using a combined average statutory tax rate of 40%.

SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF RETAINED EARNINGS

(In Thousands)

	2016			2015			2014
Retained Earnings - Beginning	$	474,167		$	439,218		$	406,041
Net Income	118,810			105,107			97,046
	592,977			544,325			503,087
Dividends Declared - Common Stock	(82,380		)	(70,158		)	(63,869		)
Retained Earnings - Ending	$	510,597		$	474,167		$	439,218

SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED STATEMENTS OF CASH FLOWS

FOR THE TWELVE MONTHS ENDED DECEMBER 31,

(In Thousands)

	2016			2015			2014
CASH PROVIDED BY OPERATING ACTIVITIES	$	20,120		$	38,593		$	22,244
CASH FLOWS FROM INVESTING ACTIVITIES:
Net Repayments from (Advances to) Associated Companies	32,300			(118,802		)	(104,979		)
Capital Expenditures	(345		)	(150		)	(1,610		)
Proceeds from Sale of Property, Plant & Equipment	—			—			27
Purchase of Company Owned Life Insurance	(2,398		)	(2,328		)	(1,250		)
Investment in Affiliate	(65,000		)	—			(25,000		)
Net Cash Used in Investing Activities	(35,443		)	(121,280		)	(132,812		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt	—			50,000			240,000
Principal Repayments of Long Term Debt	—			(114,000		)	—
Payments for Issuance of Long Term Debt	(84		)	(55		)	(1,558		)
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(105,500		)	153,000			(144,100		)
Dividends on Common Stock	(82,380		)	(70,158		)	(63,869		)
Proceeds from Sale of Common Stock	214,426			63,192			80,680
Net Cash Provided by Financing Activities	26,462			81,979			111,153
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	11,139			(708		)	585
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	1,708			2,416			1,831
CASH AND CASH EQUIVALENTS AT END OF YEAR	$	12,847		$	1,708		$	2,416

SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.

CONDENSED BALANCE SHEETS (In Thousands)

	2016			2015
Assets
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost	$	2,685		$	2,468
Accumulated Depreciation	(2,026		)	(1,768		)
Property, Plant and Equipment - Net	659			700
Investments:
Investments in Subsidiaries	1,233,856			1,051,675
Available-for-Sale Securities	32			3,860
Total Investments	1,233,888			1,055,535
Current Assets:
Cash and Cash Equivalents	12,847			1,708
Receivable from Associated Companies	550,227			582,406
Accounts Receivable	49			49
Other	—			2,859
Total Current Assets	563,123			587,022
Other Noncurrent Assets (See Note 1)	44,974			38,168
Total Assets	$	1,842,644		$	1,681,425
Capitalization and Liabilities
Equity:
Common Stock SJI
Par Value $1.25 a share
Authorized - 120,000,000 shares
Outstanding Shares - 79,478,055 (2016) and 70,965,622 (2015)	$	99,347		$	88,707
Premium on Common Stock	706,943			499,460
Treasury Stock (at par)	(266		)	(296		)
Accumulated Other Comprehensive Loss	(27,381		)	(24,499		)
Retained Earnings	510,597			474,167
Total Equity	1,289,240			1,037,539
Long-Term Debt (See Note 1)	323,971			339,665
Current Liabilities:
Notes Payable - Banks	191,800			297,300
Current Portion of Long-Term Debt	16,000			—
Payable to Associated Companies	382			262
Accounts Payable	211			425
Other Current Liabilities	7,707			3,579
Total Current Liabilities	216,100			301,566
Other Noncurrent Liabilities	13,333			2,655
Total Capitalization and Liabilities	$	1,842,644		$	1,681,425

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 the prior period's condensed balance sheets to conform to the current period presentation. The unamortized debt issuance costs previously included in "Other Noncurrent Assets" on the condensed balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described under "New Accounting Pronouncements" in Note 1 of the consolidated financial statements.

No dividends were received from subsidiaries in 2016. Dividends received from subsidiaries amounted to $40.8 million and $18.2 million in 2015 and 2014, respectively.

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Schedule II - Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2016

Valuation and Qualifying Accounts [Abstract]

Schedule II - Valuation and Qualifying Accounts

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		Charged to Other Accounts - Describe (a)			Deductions - Describe (b)		Balance at End of Period
Provision for Uncollectible
Accounts for the Year Ended
December 31, 2016	$	10,252	$	6,907	$	(47	)	$	4,368	$	12,744
Provision for Uncollectible
Accounts for the Year Ended
December 31, 2015	$	7,910	$	14,730	$	(79	)	$	12,309	$	10,252
Provision for Uncollectible
Accounts for the Year Ended
December 31, 2014	$	5,854	$	9,519	$	(102	)	$	7,361	$	7,910

(a) Recoveries of accounts previously written off and minor adjustments.

(b) Uncollectible accounts written off.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

12 Months Ended

Dec. 31, 2016

Accounting Policies [Abstract]

GENERAL

GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries:

▪ South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey.

▪ South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial, industrial and residential customers.

▪ South Jersey Resources Group, LLC (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.

▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include:

• ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey.

• AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey.

• MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey.

▪ South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

• SJI Midstream, LLC invests in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.

BASIS OF PRESENTATION

BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position, operating results and cash flows at the dates and for the periods presented.

RECLASSIFICATIONS

Certain reclassifications have been made to the prior period's consolidated balance sheets, as well as the prior period's long-term debt carrying value and the prior period's segment disclosures in Notes 7 and 8, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the consolidated balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described below under "New Accounting Pronouncements." This reclassification caused the prior periods long-term debt carrying value in Note 7 to be adjusted, along with the prior periods unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 8 to be removed.

EQUITY INVESTMENTS

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 the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. 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. We include 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.

ESTIMATES AND ASSUMPTIONS

ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (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, and revenue recognition.

REGULATION

REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980 -”Regulated Operations.”  In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities.

OPERATING REVENUES

OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy-related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. SJRG presents revenues and expenses related to its energy trading activities on a net basis in operating revenues. This net presentation has no effect on operating income or net income. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers.

REVENUE AND THROUGHPUT-BASED TAXES

REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses.

ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLETIBLE ACCOUNTS

ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLECTIBLE ACCOUNTS - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts.

NATURAL GAS IN STORAGE

NATURAL GAS IN STORAGE – Natural Gas in Storage is reflected at average cost on the consolidated balance sheets, and represents natural gas that will be utilized in the ordinary course of business.

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.

PROPERTY, PLANT AND EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account. As of December 31, 2016, SJG's utility plant had a gross book value of $2.4 billion, which consists of utility plant assets along with projects for distribution, some of which are part of SJG's Accelerated Infrastructure Replacement Program (AIRP), as discussed in Note 10.

DEPRECIATION

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 BPU approval. The composite annual rate for all depreciable utility property was approximately 2.2% in each of 2016, 2015 and 2014. 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.

CAPITALIZED INTEREST

CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in SJG's last base rate proceeding. For SJG's accelerated infrastructure programs, SJG capitalizes interest on construction at a rate prescribed by the programs (see Note 10), and amounts are included in Utility Plant on the consolidated balance sheets. Marina and Midstream capitalize interest on capital projects in progress based on the actual cost of borrowed funds, and amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the statements of consolidated income.

IMPAIRMENT OF LONG-LIVED ASSETS

IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable.

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.”  We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause.

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 Accumulated Other Comprehensive Loss 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.

GAS EXPLORATION AND DEVELOPMENT

GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to 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.

TREASURY STOCK

TREASURY STOCK – SJI uses the par value method of accounting for treasury stock.

INCOME TAXES

INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow-through method.

CASH AND CASH EQUIVALENTS

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.

IDENTIFIABLE INTANGIBLE ASSETS

IDENTIFIABLE INTANGIBLE ASSETS - Identifiable intangible assets were acquired as part of the acquisition of Energenic projects as discussed in Note 3 and are a part of the On-Site Energy Production segment. The primary identifiable intangible assets of the Company are customer relationships. The Company determines the useful lives of identifiable intangible assets after considering the specific facts and circumstances related to each intangible asset. Considerations may include the contractual term of any agreement related to the asset, the historical performance of the asset, the Company's long-term strategy for using the asset, any laws or other local regulations which could impact the useful life of the asset, and other economic factors, including competition and specific market conditions. Intangible assets that are deemed to have definite lives (finite-lived intangible assets) are amortized, primarily on a straight-line basis, over their useful lives, generally ranging from 2 to 20 years.

GOODWILL

GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects as discussed in Note 3 and is a part of the On-Site Energy Production segment. Goodwill represents the excess of the consideration paid 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.

NEW ACCOUNTING PRONOUNCEMENTS

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 of 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. 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, is 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 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 to the new guidance using the modified retrospective approach.

In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results.

In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis, which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results.

In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's results of operations; however, balance sheet presentations were modified to conform to this guidance, as described under "Basis of Presentation" above.

Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40). This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's financial statement results.

In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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 adoption of this guidance will have on the Company's financial statement results.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which establishes a new lease accounting model for lessees. The new standard requires 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. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2018, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships. The amendments in this guidance clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-07, Investments- Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting, which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting, which simplifies various aspects of accounting for share-based payment arrangements. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. This standard is intended to provide guidance concerning the classification of certain cash receipts and cash payments in the statement of cash flows and to eliminate the diversity in practice related to such classifications. This standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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 adoption of this guidance will have on the Company's financial statement results.

In November 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash. This standard is intended to reduce diversity in practice in the classification and presentation of changes in restricted cash on the consolidated statement of cash flows. The ASU requires that the consolidated statement of cash flows explain the change in total cash and cash equivalents and amounts generally described as restricted cash or restricted cash equivalents when reconciling the beginning-of-period and end-of-period total amounts. The ASU also requires a reconciliation between the total of cash and equivalents and restricted cash presented on the consolidated statement of cash flows and the cash and cash equivalents balance presented on the consolidated balance sheets. ASU 2016-18 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have 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 adoption of this guidance will have on the Company's financial statement results.

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's financial statement results.

FAIR VALUE

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.

(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 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.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

12 Months Ended

Dec. 31, 2016

Accounting Policies [Abstract]

Asset retirement obligation activity

ARO activity was as follows (in thousands):

	2016			2015
AROs as of January 1,	$	57,943		$	42,502
Accretion	1,937			1,675
Additions	1,098			802
Settlements	(1,551		)	(1,110		)
Revisions in Estimated Cash Flows (A)	—			14,074
ARO's as of December 31,	$	59,427		$	57,943

(A) The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

Summary of changes in goodwill

The following table summarizes the changes in Goodwill for the year ended December 31, 2016 (in thousands):

	2016
Beginning Balance, January 1	$	8,880
Fair Value Adjustments During Measurement Period (See Note 3)	(4,042		)
Ending Balance, December 31	$	4,838

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STOCK-BASED COMPENSATION PLAN (Tables)

12 Months Ended

Dec. 31, 2016

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Summary of the nonvested restricted stock awards outstanding and the assumptions used to estimate the fair value of the awards

The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2016, and the assumptions used to estimate the fair value of the awards:

	Grants	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	2015 - TSR	33,537	$	26.31	16.0	%	1.10	%
	2015 - EGR, ROE, Time	73,118	$	29.47	N/A		N/A
	2016 - TSR	66,101	$	22.53	18.1	%	1.31	%
	2016 - CEGR, Time	122,759	23.52		N/A		N/A
Directors -	2016	35,197	$	23.88	N/A		N/A

Summary of the total stock-based compensation cost for the period

The following table summarizes the total stock-based compensation cost for the years ended December 31 (in thousands):

	2016			2015			2014
Officers & Key Employees	$	3,051		$	1,128		$	1,260
Directors	841			769			633
Total Cost	3,892			1,897			1,893
Capitalized	(385		)	(216		)	(147		)
Net Expense	$	3,507		$	1,681		$	1,746

Summary of information regarding restricted stock award activity during the period excluding accrued dividend equivalents

The following table summarizes information regarding restricted stock award activity during 2016, excluding accrued dividend equivalents:

	Officers & Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2016	226,191		26,338		$	26.89
Granted	194,347		35,197		$	23.28
Vested*	(113,917	)	(26,338	)	$	25.69
Cancelled/Forfeited**	(11,106	)	—		$	25.11
Nonvested Shares Outstanding, December 31, 2016	295,515		35,197		$	24.96

*Based on performance information available at the filing of this Report, management expects to award 29,044 shares associated with the 2014 grants to Officers and other key employees in 2017.

** Represents shares forfeited as a result of separation of employment prior to the satisfaction of service conditions.

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AFFILIATIONS AND DISCONTINUED OPERATIONS (Tables)

12 Months Ended

Dec. 31, 2016

Business Combinations [Abstract]

Schedule of the fair value of the assets acquired and the liabilities assumed

The following table summarizes the final purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.0 million, which represents the fair value of the Company’s interest in the Partner Projects exchanged ($31.5 million) as well as the existing value of the Marina Projects immediately prior to the exchange ($14.5 million) (in thousands):

Current assets (excluding inventory)	$	7,804
Inventory	3,154
Note Receivable Received	19,504
Fixed Assets	46,460
Intangible Assets:
Identifiable Intangibles	16,950
Goodwill	4,838
Non-Current Assets	4,783
Current Liabilities	(8,196		)
Note Payable - Affiliate	(16,986		)
Long-Term Debt, including current portion	(21,642		)
Capital Lease Payable	(10,458		)
Other Non-Current Liabilities	(181		)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects	$	46,030

Summarized operating results of the discontinued operations

Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts):

	2016			2015			2014
Loss before Income Taxes:
Sand Mining	$	(205	)	$	(422	)	$	(620	)
Fuel Oil	(179		)	(338		)	(274		)
Income Tax Benefits	133			257			312
Loss from Discontinued Operations — Net	$	(251	)	$	(503	)	$	(582	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic and Diluted	$	—		$	(0.01	)	$	(0.01	)

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INCOME TAXES (Tables)

12 Months Ended

Dec. 31, 2016

Income Tax Disclosure [Abstract]

Schedule of components of income tax expense (benefit) and effective income tax rate reconciliation

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 the following reasons (in thousands):

	2016			2015			2014
Tax at Statutory Rate	$	60,624		$	37,440		$	35,727
Increase (Decrease) Resulting from:
State Income Taxes	6,438			3,985			1,960
ESOP Dividend	(1,300		)	(1,298		)	(1,232		)
Amortization of Investment Tax Credits - Utility	—			(149		)	(211		)
AFUDC	(900		)	(1,109		)	(1,481		)
Investment and Other Tax Credits	(10,706		)	(37,503		)	(30,661		)
Other - Net	(5		)	(6		)	347
Income Taxes:
Continuing Operations	54,151			1,360			4,449
Discontinued Operations	(133		)	(257		)	(312		)
Total Income Tax Expense	$	54,018		$	1,103		$	4,137
The provision for Income Taxes is comprised of the following (in thousands):
	2016			2015			2014
Current:
Federal	$	—		$	—		$	(62	)
State	(1,638		)	(2,352		)	3,052
Total Current	(1,638		)	(2,352		)	2,990
Deferred:
Federal	44,246			(4,622		)	1,707
State	11,543			8,483			(37		)
Total Deferred	55,789			3,861			1,670
Investment Tax Credit - Utility	—			(149		)	(211		)
Income Taxes:
Continuing Operations	54,151			1,360			4,449
Discontinued Operations	(133		)	(257		)	(312		)
Total Income Tax Expense	$	54,018		$	1,103		$	4,137

Schedule of deferred tax assets and liabilities

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 at December 31 (in thousands):

	2016		2015
Deferred Tax Assets:
Net Operating Loss Carryforward	$	211,004	$	195,358
Investment and Other Tax Credits	213,946		200,491
Derivatives / Unrealized Gain	—		5,652
Deferred State Tax	28,833		24,833
Pension & Other Post Retirement Benefits	19,351		29,998
Deferred Revenues	7,669		4,924
Provision for Uncollectibles	5,231		4,200
Other	8,368		6,448
Total Deferred Tax Asset	$	494,402	$	471,904
Deferred Tax Liabilities:
Book versus Tax Basis of Property	$	732,535	$	675,521
Deferred Gas Costs - Net	2,052		3,998
Derivatives / Unrealized Loss	1,794		—
Environmental Remediation	32,885		19,207
Deferred Regulatory Costs	1,554		566
Budget Billing - Customer Accounts	3,347		830
Deferred Pension & Other Post Retirement Benefits	34,432		42,216
Conservation Incentive Program	11,846		1,132
Equity In Loss Of Affiliated Companies	3,092		9,111
Other	14,414		15,268
Total Deferred Tax Liability	$	837,951	$	767,849
Deferred Tax Liability - Net	$	343,549	$	295,945

Summary of operating loss carryforward

As of December 31, 2016, SJI has the following federal and state net operating loss carryforwards (in thousands):

	Net Operating Loss Carryforwards
Expire in:	Federal		State
2031	$	163,572	$	45,866
2032	42,988		19,356
2033	67,496		34,940
2034	119,122		28,622
2035	70,992		9,860
2036	93,508		81,369
	$	557,678	$	220,013

Summary of tax credit carryforwards

As of December 31, 2016, SJI has the following investment tax credit carryforwards (in thousands):

Expire in:	Investment Tax Credit Carryforward
2030	$	11,628
2031	25,664
2032	32,071
2033	45,606
2034	37,699
2035	45,097
2036	11,659
	$	209,424

Reconciliation of unrecognized tax benefits

A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands):

	2016		2015		2014
Balance at January 1,	$	559	$	552	$	547
Increase as a result of tax positions taken in prior years	886		7		5
Balance at December 31,	$	1,445	$	559	$	552

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COMMON STOCK (Tables)

12 Months Ended

Dec. 31, 2016

Common Stock [Abstract]

Common stock shares issued and outstanding

The following shares were issued and outstanding at December 31 (See Note 1):

	2016	2015	2014
Beginning of Year	70,965,622	68,334,860	65,430,084
New Issues During Year:
Dividend Reinvestment Plan	417,095	2,604,424	2,881,556
Stock-Based Compensation Plan	45,338	26,338	23,220
Public Equity Offering	8,050,000	—	—
End of Year	79,478,055	70,965,622	68,334,860

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SEGMENTS OF BUSINESS (Tables)

12 Months Ended

Dec. 31, 2016

Segment Reporting [Abstract]

Segments of Business

Information about SJI’s operations in different reportable operating segments is presented below (in thousands):

	2016			2015			2014
Operating Revenues:
Gas Utility Operations	$	461,055		$	534,290		$	501,875
Energy Group:
Wholesale Energy Operations	220,707			129,098			77,048
Retail Gas and Other Operations	92,371			87,198			127,001
Retail Electric Operations	182,540			150,049			123,773
Subtotal Energy Group	495,618			366,345			327,822
Energy Services:
On-Site Energy Production	94,375			63,665			56,129
Appliance Service Operations	7,898			11,186			10,518
Subtotal Energy Services	102,273			74,851			66,647
Corporate & Services	35,147			31,156			30,174
Subtotal	1,094,093			1,006,642			926,518
Intersegment Sales	(57,593		)	(47,074		)	(39,522		)
Total Operating Revenues	$	1,036,500		$	959,568		$	886,996

	2016			2015			2014
Operating Income:
Gas Utility Operations	$	122,455		$	119,585		$	113,690
Energy Group:
Wholesale Energy Operations	41,667			35,024			9,493
Retail Gas and Other Operations	4,680			(3,218		)	479
Retail Electric Operations	7,007			1,042			(466		)
Subtotal Energy Group	53,354			32,848			9,506
Energy Services:
On-Site Energy Production	13,301			2,027			2,560
Appliance Service Operations	582			468			362
Subtotal Energy Services	13,883			2,495			2,922
Corporate and Services	(416		)	1,966			1,485
Total Operating Income	$	189,276		$	156,894		$	127,603
Depreciation and Amortization:
Gas Utility Operations	$	63,901		$	58,668		$	52,155
Energy Group:
Wholesale Energy Operations	484			435			168
Retail Gas and Other Operations	337			161			83
Subtotal Energy Group	821			596			251
Energy Services:
On-Site Energy Production	43,395			30,242			25,020
Appliance Service Operations	301			316			269
Subtotal Energy Services	43,696			30,558			25,289
Corporate and Services	1,400			1,220			816
Total Depreciation and Amortization	$	109,818		$	91,042		$	78,511
Interest Charges:
Gas Utility Operations	$	17,875		$	19,906		$	17,872
Energy Group:
Wholesale Energy Operations	—			441			371
Retail Gas and Other Operations	350			185			267
Subtotal Energy Group	350			626			638
Energy Services:
On-Site Energy Production	11,961			8,169			8,723
Corporate and Services	12,118			11,822			8,803
Subtotal	42,304			40,523			36,036
Intersegment Borrowings	(10,855		)	(8,901		)	(6,476		)
Total Interest Charges	$	31,449		$	31,622		$	29,560

	2016			2015			2014
Income Taxes:
Gas Utility Operations	$	39,366		$	36,945		$	34,895
Energy Group:
Wholesale Energy Operations	15,882			14,410			4,822
Retail Gas and Other Operations	2,118			(978		)	787
Retail Electric Operations	2,862			426			(190		)
Subtotal Energy Group	20,862			13,858			5,419
Energy Services:
On-Site Energy Production	(6,353		)	(49,225		)	(36,404		)
Appliance Service Operations	232			186			223
Subtotal Energy Services	(6,121		)	(49,039		)	(36,181		)
Corporate and Services	44			(404		)	316
Total Income Taxes	$	54,151		$	1,360		$	4,449
Property Additions:
Gas Utility Operations	$	228,275		$	218,260		$	201,737
Energy Group:
Wholesale Energy Operations	7			382			18
Retail Gas and Other Operations	1,642			2,053			1,421
Subtotal Energy Group	1,649			2,435			1,439
Energy Services:
On-Site Energy Production (1)	38,193			139,018			132,214
Appliance Service Operations	431			379			84
Subtotal Energy Services	38,624			139,397			132,298
Corporate and Services	1,141			1,902			3,995
Total Property Additions	$	269,689		$	361,994		$	339,469

(1) The property additions for On-Site Energy Production in 2016 and 2015 do not include the approximately $5.6 million and $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3.

	2016			2015
Identifiable Assets (See Note 1):
Gas Utility Operations	$	2,551,923		$	2,281,576
Energy Group:
Wholesale Energy Operations	233,019			231,660
Retail Gas and Other Operations	52,729			55,111
Retail Electric Operations	41,280			55,528
Subtotal Energy Group	327,028			342,299
Energy Services:
On-Site Energy Production	767,710			790,231
Appliance Service Operations	2,879			4,885
Subtotal Energy Services	770,589			795,116
Discontinued Operations	1,756			1,545
Corporate and Services	649,795			652,325
Intersegment Assets	(570,524		)	(600,928		)
Total Identifiable Assets	$	3,730,567		$	3,471,933

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LEASES (Tables)

12 Months Ended

Dec. 31, 2016

Leases [Abstract]

Schedule of minimum future rental receivables on operating lease

Minimum future rentals to be received on this operating lease of property and equipment as of December 31, 2016 for each of the next five years and in the aggregate are (in thousands):

Year ended December 31,
2017	$	5,396
2018	5,396
2019	5,396
2020	5,396
2021	5,396
Thereafter	29,230
Total minimum future rentals	56,210

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REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)

12 Months Ended

Dec. 31, 2016

Regulatory Assets and Liabilities Disclosure [Abstract]

Schedule of Regulatory Assets

Regulatory Assets consisted of the following items (in thousands):

	December 31, 2016		December 31, 2015
Environmental Remediation Costs:
Expended - Net	$	71,997	$	42,032
Liability for Future Expenditures	153,047		123,194
Deferred Asset Retirement Obligation Costs	43,014		42,430
Deferred Pension and Other Postretirement Benefit Costs	85,693		79,779
Deferred Gas Costs - Net	—		2,701
Conservation Incentive Program Receivable	27,567		2,624
Deferred Interest Rate Contracts	7,365		7,631
Energy Efficiency Tracker	219		496
Pipeline Supplier Service Charges	2,122		3,776
Pipeline Integrity Cost	4,810		4,596
AFUDC - Equity Related Deferrals	12,434		11,423
Other Regulatory Assets	2,478		2,752
Total Regulatory Assets	$	410,746	$	323,434

Schedule of Regulatory Liabilities

Regulatory Liabilities consisted of the following items (in thousands):

	December 31, 2016		December 31, 2015
Excess Plant Removal Costs	$	28,226	$	32,644
Deferred Revenue - Net	17,800		—
Societal Benefit Costs Payable	3,095		10,197
Total Regulatory Liabilities	$	49,121	$	42,841

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PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)

12 Months Ended

Dec. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Periodic Benefit Costs

Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):

	Pension Benefits
	2016			2015			2014
Service Cost	$	4,843		$	5,337		$	4,510
Interest Cost	12,125			11,168			10,735
Expected Return on Plan Assets	(13,508		)	(14,789		)	(13,491		)
Amortizations:
Prior Service Cost	212			212			175
Actuarial Loss	9,394			10,608			5,716
Net Periodic Benefit Cost	13,066			12,536			7,645
Capitalized Benefit Costs	(4,645		)	(4,805		)	(3,047		)
Deferred Benefit Costs	(645		)	(1,007		)	—
Total Net Periodic Benefit Expense	$	7,776		$	6,724		$	4,598

	Other Postretirement Benefits
	2016			2015			2014
Service Cost	$	851		$	1,116		$	891
Interest Cost	2,615			2,973			2,852
Expected Return on Plan Assets	(3,104		)	(2,993		)	(2,603		)
Amortizations:
Prior Service (Credits) Cost	(344		)	608			152
Actuarial Loss	1,109			1,342			974
Net Periodic Benefit Cost	1,127			3,046			2,266
Capitalized Benefit Costs	(277		)	(1,043		)	(722		)
Deferred Benefit Costs	—			(256		)	—
Total Net Periodic Benefit Expense	$	850		$	1,747		$	1,544

Activity Within Regulatory Assets and Accumulated Other Comprehensive Income (Loss)

Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands):

	Regulatory Assets						Accumulated Other Comprehensive Loss  (pre-tax)
	Pension Benefits			Other Postretirement Benefits			Pension Benefits			Other Postretirement Benefits
Balance at January 1, 2015	$	71,177		$	27,863		$	39,468		$	6,755
Amounts Arising during the Period:
Net Actuarial (Loss)/Gain	(463		)	(3,155		)	59			(2,285		)
Prior Service Cost				(499		)				(106		)
Amounts Amortized to Net Periodic Costs:
Net Actuarial Loss	(6,079		)	(1,107		)	(4,452		)	(221		)
Prior Service Cost	(203		)	(7,755		)	(9		)	(2,081		)
Balance at December 31, 2015	64,432			15,347			35,066			2,062
Amounts Arising during the Period:
Net Actuarial Gain	9,706			2,584			8,370			829
Prior Service Credit	—			257			—			84
Amounts Amortized to Net Periodic Costs:
Net Actuarial Loss	(5,485		)	(945		)	(3,838		)	(154		)
Prior Service Cost	(203		)	—			(8		)	—
Balance at December 31, 2016	$	68,450		$	17,243		$	39,590		$	2,821

Estimated Costs That Will be Amortized from Regulatory Assets into Net Periodic Costs

The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2017 are as follows (in thousands): 

	Pension Benefits		Other Postretirement Benefits
Prior Service Cost/(Credit)	$	127	$	(257	)
Net Actuarial Loss	$	6,202	$	1,040

Estimated Costs That Will be Amortized from Accumulated Other Comprehensive Income (Loss) into Net Periodic Benefit Costs

The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2017 are as follows (in thousands):

	Pension Benefits		Other Postretirement  Benefits
Prior Service Cost/(Credit)	$	5	$	(87	)
Net Actuarial Loss	$	3,943	$	207

Reconciliation of the Plans' Benefit Obligations, Fair Value of Plan Assets and Funded Status

A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands): 

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	$	254,195		$	265,434		$	57,430		$	75,592
Service Cost	4,843			5,337			851			1,116
Interest Cost	12,125			11,168			2,615			2,973
Actuarial Loss (Gain)	18,254			(17,349		)	3,121			(8,591		)
Retiree Contributions	—			—			81			700
Plan Amendments	—			—			—			(9,899		)
Benefits Paid	(11,129		)	(10,395		)	(3,748		)	(4,461		)
Benefit Obligation at End of Year	$	278,288		$	254,195		$	60,350		$	57,430
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	$	184,824		$	180,523		$	47,759		$	43,222
Actual Return on Plan Assets	13,569			(2,321		)	2,784			(423		)
Employer Contributions	2,278			17,017			3,656			8,721
Retiree Contributions	—			—			81			700
Benefits Paid	(11,129		)	(10,395		)	(3,748		)	(4,461		)
Fair Value of Plan Assets at End of Year	$	189,542		$	184,824		$	50,532		$	47,759
Funded Status at End of Year:	$	(88,746	)	$	(69,371	)	$	(9,818	)	$	(9,671	)
Amounts Related to Unconsolidated Affiliate	326			204			540			509
Accrued Net Benefit Cost at End of Year	$	(88,420	)	$	(69,167	)	$	(9,278	)	$	(9,162	)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$	(2,463	)	$	(2,261	)	$	—		$	—
Noncurrent Liabilities	(85,957		)	(66,906		)	(9,278		)	(9,162		)
Net Amount Recognized at End of Year	$	(88,420	)	$	(69,167	)	$	(9,278	)	$	(9,162	)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	$	538		$	741		$	(3,032	)	$	(3,289	)
Net Actuarial Loss	67,912			63,691			20,275			18,636
	$	68,450		$	64,432		$	17,243		$	15,347
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	$	69		$	77		$	(989	)	$	(1,074	)
Net Actuarial Loss	39,521			34,989			3,810			3,136
	$	39,590		$	35,066		$	2,821		$	2,062

Schedule of Weighted-Average Assumptions Used

The weighted-average assumptions used to determine benefit obligations at December 31 were:

	Pension Benefits				Other Postretirement Benefits
	2016		2015		2016		2015
Discount Rate	4.30	%	4.83	%	4.13	%	4.73	%
Rate of Compensation Increase	3.50	%	3.50	%	3.50	%	3.50	%

The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were:

	Pension Benefits						Other Postretirement Benefits
	2016		2015		2014		2016		2015		2014
Discount Rate	4.83	%	4.25	%	5.09	%	4.73	%	4.20	%	4.91	%
Expected Long-Term Return on Plan Assets	7.50	%	7.75	%	7.75	%	6.50	%	6.25	%	6.25	%
Rate of Compensation Increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%

Fair Value of Plan Assets

The fair values of SJI's pension plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands): 

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2016
Cash / Cash Equivalents:
Cash	$	63	$	63	$	—	$	—
Common/Collective Trust Funds (a)	460		—		460		—
STIF-Type Instrument (b)	1,431		—		1,431		—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	51,902		—		51,902		—
Common/Collective Trust Funds - International (a)	33,096		—		33,096		—
U.S. Large-Cap (c)	17,792		17,792		—		—
U.S. Mid-Cap (c)	2,479		2,479		—		—
International (c)	3,340		3,340		—		—
Fixed Income:
Common/Collective Trust Funds (a)	54,970		—		54,970		—
Guaranteed Insurance Contract (d)	9,714		—		—		9,714
Other types of investments:
Private Equity Fund (f)	5,100		—		—		5,100
Common/Collective Trust Fund - Real Estate (g)	9,195		—		—		9,195
Total	$	189,542	$	23,674	$	141,859	$	24,009

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2015
Cash / Cash Equivalents:
Cash	$	35	$	35	$	—	$	—
Common/Collective Trust Funds (a)	858		—		858		—
STIF-Type Instrument (b)	1,360		—		1,360		—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	52,058		—		52,058		—
Common/Collective Trust Funds - International (a)	33,236		—		33,236		—
U.S. Large-Cap (c)	14,305		14,305		—		—
U.S. Mid-Cap (c)	3,407		3,407		—		—
U.S. Small-Cap (c)	260		260		—		—
International (c)	1,695		1,695		—		—
Fixed Income:
Common/Collective Trust Funds (a)	50,664		—		50,664		—
Guaranteed Insurance Contract (d)	9,960		—		—		9,960
Hedge Funds (e)	4,159		—		—		4,159
Other types of investments:
Private Equity Fund (f)	4,312		—		—		4,312
Common/Collective Trust Fund - Real Estate (g)	8,515		—		—		8,515
Total	$	184,824	$	19,702	$	138,176	$	26,946

(a) 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 markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.

(b) 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.

(c) 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.

(d) 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.

(e) This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments.

(f) This category represents a limited partnership/commingled trust 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 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments.  Fund investments are illiquid and resale is restricted.  These funds are classified as Level 3 investments.

(g) 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.  Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments.

The fair values of SJI's other postretirement benefit plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands):

Asset Category	Total		Level 1		Level 2		Level 3
As of December 31, 2016:
Cash	$	—	$	—	$	—	$	—
Equity Securities:
Common/Collective Trust Funds - U.S. (a)	$	14,878	$	—	$	14,878	$	—
Common/Collective Trust Funds - International (a)	8,674		—		8,674		—
Fixed Income:
Common/Collective Trust Funds - Bonds (a)	13,537		—		13,537		—
Other Types of Investments:
Company Owned Life Insurance (c)	13,443		—		13,443		—
Total	$	50,532	$	—	$	50,532	$	—
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)	$	13,522	$	—	$	13,522	$	—
Common/Collective Trust Funds - International (a)	8,313		—		8,313		—
Mutual Fund - U.S. (b)	1,309		1,309		—		—
Mutual Funds - International (b)	983		983		—		—
Fixed Income:
Common/Collective Trust Funds - Bonds (a)	13,187		—		13,187		—
Mutual Funds - Bonds (b)	1,441		1,441		—		—
Other Types of Investments:
Mutual Funds - REITS (b)	152		152		—		—
Company Owned Life Insurance (c)	8,826		—		8,826		—
Total	$	47,759	$	3,911	$	43,848	$	—

(a) 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 markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.

(b) 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.

(c) This category represents Company-owned life insurance policies with a nationally known life insurance company. The value of these policies is backed by a series of common/collective trust funds held by the insurance carrier similar to category (a) above. Holdings in these insurance policies are classified as Level 2 investments.

Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets

	Guaranteed						Private
	Insurance			Hedge			Equity			Real
	Contract			Funds			Funds			Estate		Total
Balance at January 1, 2015	$	10,912		$	4,331		$	3,616		$	7,476	$	26,335
Actual return on plan assets:
Relating to assets still held at the reporting date	(106		)	(172		)	(302		)	1,039		459
Relating to assets sold during the period	25			—			429			—		454
Purchases, Sales and Settlements	(871		)	—			569			—		(302		)
Balance at December 31, 2015	9,960			4,159			4,312			8,515		26,946
Actual return on plan assets:
Relating to assets still held at the reporting date	541			(67		)	(140		)	680		1,014
Relating to assets sold during the period	14			—			245			—		259
Purchases, Sales and Settlements	(801		)	(4,092		)	683			—		(4,210		)
Balance at December 31, 2016	$	9,714		$	—		$	5,100		$	9,195	$	24,009

Schedule of Future Benefit Payments

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following years (in thousands):

	Pension Benefits		Other Postretirement Benefits
2017	$	12,141	$	4,399
2018	$	12,583	$	4,316
2019	$	13,529	$	4,403
2020	$	14,056	$	4,514
2021	$	14,757	$	4,511
2022 - 2025	$	86,727	$	21,308

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LINES OF CREDIT (Tables)

12 Months Ended

Dec. 31, 2016

Line of Credit Facility [Abstract]

Summary of Credit Facilities and Available Liquidity

Credit facilities and available liquidity as of December 31, 2016 were as follows (in thousands):

Company	Total Facility		Usage			Available Liquidity		Expiration Date
SJG:
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 SJG	210,000		105,100			104,900
SJI:
Revolving Credit Facility	450,000		196,600		(B)	253,400		Various	(C)
Total SJI	450,000		196,600			253,400
Total	$	660,000	$	301,700		$	358,300

(A) Includes letters of credit outstanding in the amount of $0.8 million.

(B) Includes letters of credit outstanding in the amount of $4.8 million.

(C) In September 2016, the Company entered into an unsecured $50.0 million, 364-day revolving credit agreement. The agreement matures September 2017, at which time the principal and any accrued but unpaid interest must be paid. At the annual request of the Company, but on not more than two occasions, the credit agreement may be extended for an additional period of 364 days. The 364-day revolving facility bears interest at a variable base rate or a variable London Interbank Offered Rate (“LIBOR”), at the Company’s election.

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LONG-TERM DEBT (Tables)

12 Months Ended

Dec. 31, 2016

Debt Disclosure [Abstract]

Schedule of Long-term Debt

Outstanding Long-Term Debt at December 31 consisted of the following:

			2016			2015
Long-Term Debt (A):
South Jersey Gas Company:
First Mortgage Bonds: (B)
5.437%		Series due 2016 (C)	$	—		$	10,000
4.6%		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 Bonds at variable rates due 2036 (J)			24,900			24,900
SJG Term Facility (K)			200,000			139,000
Marina Energy LLC:  (L)
Series A 2001 Bonds at variable rates due 2031			20,000			20,000
Series B 2001 Bonds at variable rates due 2021			25,000			25,000
Series A 2006 Bonds at variable rates due 2036			16,400			16,400
South Jersey Industries:
2.71%		Series B 2012 Notes due 2017 (M)	16,000			16,000
3.05%		Series due 2019	60,000			60,000
3.05%		Series due 2019	30,000			30,000
3.05%		Series due 2019	50,000			50,000
3.46%		Series C 2012 Notes due 2022	35,000			35,000
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
ACB Energy Partners, LLC:
7.60	%	Loan & Security Agreement (P)	—			12,735
Other Energy Project Debt (Q):
4.83	%	ACLE	—			3,551
4.83	%	SCLE	—			1,738
4.83	%	SXLE	—			3,433
Total Long-Term Debt Outstanding (R)			$	1,047,482		$	1,035,848
Less Current Maturities			(231,909		)	(29,454		)
Total Long-Term Debt (R)			$	815,573		$	1,006,394

(A) Long-term debt maturities for the succeeding five years are as follows (in thousands): 2017: $231,909; 2018: $38,909; 2019: $258,909; 2020: $67,909; and 2021: $52,909.

(B) The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. In January 2017, the First Mortgage was amended and restated in its entirety (see Note 19).

(C) In July 2016, SJG retired $17.0 million of 4.60% Medium Term Notes (MTN's) at maturity. In August 2016, SJG retired $10.0 million of 5.437% MTN's at maturity.

(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.

(I) SJG has $50.0 million of 4.01% MTN's with several due dates, as follows: $8.0 million each due November 2018 and 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) These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2016 was 0.74%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August 2018. These bonds contain no financial covenants.

(K) SJG had a $200.0 million multiple-draw term facility offered by a syndicate of banks which was set to expire in June 2017. This facility bore interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of December 31, 2015, SJG had borrowed an aggregate $139.0 million under this facility at an average interest rate of 1.17% and the proceeds were used to pay down short-term debt. In January 2016, SJG issued an additional $61.0 million of long-term debt at an average interest rate of 1.41% under this facility. As such, 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 it was due within one year. In January 2017, this term facility was paid in full (see Note 19).

(L) Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2016 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.72%, 0.73% and 0.72% respectively. The interest rate on all but $46.1 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026.  These bonds contain no financial covenants.  Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March 2018.

(M) As of December 31, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017, are classified in current portion of long-term debt on the consolidated balance sheets. SJI plans to pay off this debt at maturity.

(N) At December 31, 2016, the floating rate on these Senior Notes was 2.32%.

(O) In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2016 was 1.79%.

(P) ACB had a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million. Under the LSA, ACB paid principal and interest (at a fixed rate of 7.60%) in equal quarterly installments that began in February 2011 and was scheduled to run through February 2021. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In January 2016, the Company paid $12.7 million to retire outstanding debt.

(Q) ACLE, SCLE and SXLE (the "Other Energy Projects") had long-term debt agreements with a third party to borrow up to $10.0 million. Under the debt agreements, the Other Energy Projects paid principal and interest (at a fixed rate of 4.83%) in equal installments that began December 2013 and was scheduled to run through December 2020. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the outstanding debt of $8.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In August 2016, the Company paid an aggregate $8.3 million to retire outstanding long-term debt for the Other Energy Projects.

(R) Total Long-Term Debt in the table above does not include unamortized debt issuance costs of $7.6 million and $9.0 million for the years ended December 31, 2016 and 2015, respectively, which were reclassified to Long-Term Debt on the consolidated balance sheets to conform to ASU 2015-03 (see Note 1).

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COMMITMENTS AND CONTINGENCIES (Tables)

12 Months Ended

Dec. 31, 2016

Commitments and Contingencies Disclosure [Abstract]

Schedule of Environmental Loss Contingencies

The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands):

	2016			2015
Beginning of Year	$	126,623		$	128,172
Accruals	60,713			19,489
Expenditures	(32,323		)	(21,038		)
End of Year	$	155,013		$	126,623

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DERIVATIVE INSTRUMENTS (Tables)

12 Months Ended

Dec. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Summary of Interest Rate Swaps

As of December 31, 2016, SJI's active interest rate swaps were as follows:

Notional Amount		Fixed Interest Rate	Start Date	Maturity	Type of Debt	Obligor
$	14,500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	330,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	12,500,000	3.530%	12/1/2006	2/1/2036	Tax-exempt	SJG
$	12,500,000	3.430%	12/1/2006	2/1/2036	Tax-exempt	SJG

Fair Value of Derivative Instruments

The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands):

Derivatives not designated as hedging instruments under GAAP	2016				2015
	Assets		Liabilities		Assets		Liabilities
Energy-related commodity contracts:
Derivatives – Energy Related – Current	$	72,391	$	60,082	$	83,093	$	90,708
Derivatives – Energy Related – Non-Current	8,502		4,540		16,238		21,697
Interest rate contracts:
Derivatives - Other - Current	—		681		—		—
Derivatives - Other - Non-Current	—		9,349		—		10,943
Total derivatives not designated as hedging instruments under GAAP	80,893		74,652		99,331		123,348
Total Derivatives	$	80,893	$	74,652	$	99,331	$	123,348

Offsetting Arrangements

As of December 31, 2016 and2015, information related to these offsetting arrangements were as follows (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	$	80,893		$	—	$	80,893		$	(38,809	)	(A)	$	(3,474	)	$	38,610
Derivatives - Energy Related Liabilities	$	(64,622	)	$	—	$	(64,622	)	$	38,809		(B)	$	—		$	(25,813	)
Derivatives - Other	$	(10,030	)	$	—	$	(10,030	)	$	—			$	—		$	(10,030	)

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	$	99,331		$	—	$	99,331		$	(35,491	)	(A)	$	—	$	63,840
Derivatives - Energy Related Liabilities	$	(112,405	)	$	—	$	(112,405	)	$	35,491		(B)	$	23,045	$	(53,869	)
Derivatives - Other	$	(10,943	)	$	—	$	(10,943	)	$	—			$	—	$	(10,943	)

(A) The balances at December 31, 2016 and 2015 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at December 31, 2016 and 2015 were related to derivative assets which can be net settled against derivative liabilities.

Effect of Derivatives on Income

The effect of derivative instruments on the statements of consolidated income and comprehensive income for the year ended December 31 is as follows (in thousands):

Derivatives in Cash Flow Hedging Relationships	2016			2015			2014
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	—		$	—
Losses reclassified from AOCL into income (a)	$	(333	)	$	(551	)	$	(419	)
Losses recognized in income on ineffective portion (a)	$	—		$	—		$	—

(a) Included in Interest Charges

Derivatives Not Designated as Hedging Instruments under GAAP	2016		2015		2014
Gains (losses) on energy-related commodity contracts (a)	$	26,935	$	8,401	$	(6,592	)
Gains (losses) on interest rate contracts (b)	647		96		(467		)
Total	$	27,582	$	8,497	$	(7,059	)

(a)  Included in Operating Revenues - Nonutility

(b)  Included in Interest Charges

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)

12 Months Ended

Dec. 31, 2016

Fair Value Disclosures [Abstract]

Summary of Financial Assets and Liabilities

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	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	32	$	32	$	—	$	—
Derivatives – Energy Related Assets (B)	80,893		33,994		11,814		35,085
	$	80,925	$	34,026	$	11,814	$	35,085
Liabilities
Derivatives – Energy Related Liabilities (B)	$	64,622	$	16,502	$	22,070	$	26,050
Derivatives – Other (C)	10,030		—		10,030		—
	$	74,652	$	16,502	$	32,100	$	26,050

As of December 31, 2015	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	14,810	$	2,925	$	11,885	$	—
Derivatives – Energy Related Assets (B)	99,331		16,006		24,730		58,595
	$	114,141	$	18,931	$	36,615	$	58,595
Liabilities
Derivatives – Energy Related Liabilities (B)	$	112,405	$	42,170	$	11,008	$	59,227
Derivatives – Other (C)	10,943		—		10,943		—
	$	123,348	$	42,170	$	21,951	$	59,227

(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 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.

Quantitative Information Regarding Significant Unobservable Inputs

The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands, except for ranges):

Type	Fair Value at December 31, 2016				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	23,301	$	18,109	Discounted Cash Flow	Forward price (per dt)	$1.03 - $11.33 [$2.71]	(A)
Forward Contract - Electric	$	11,784	$	7,941	Discounted Cash Flow	Fixed electric load profile (on-peak)	21.43% - 100.00% [55.14%]	(B)
						Fixed electric load profile (off-peak)	0.00% - 78.57% [44.86%]	(B)

Type	Fair Value at December 31, 2015				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	29,459	$	31,733	Discounted Cash Flow	Forward price (per dt)	$(0.77) - $10.00 [$2.15]	(A)
Forward Contract - Electric	$	29,136	$	27,494	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.47% - 100.00% [56.20%]	(B)
						Fixed electric load profile (off-peak)	0.00% - 91.53% [43.80%]	(B)

(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.

Changes in Measurements Using Significant Unobservable Inputs

The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2016 and 2015, using significant unobservable inputs (Level 3), are as follows (in thousands):

	Year Ended December 31, 2016
Balance at January 1, 2016	$	(632	)
Other changes in fair value from continuing and new contracts, net	5,657
Transfers in to/(out of) of Level 3 (A)	4,116
Settlements	(106		)
Balance at December 31, 2016	$	9,035

	Year Ended December 31, 2015
Balance at January 1, 2015	$	(5,608	)
Other changes in fair value from continuing and new contracts, net	(5,069		)
Transfers in to/(out of) of Level 3 (A)	7,402
Settlements	2,643
Balance at December 31, 2015	$	(632	)

(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.  During the years ended December 31, 2016 and 2015, $4.1 million and $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management.

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ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) (Tables)

12 Months Ended

Dec. 31, 2016

Equity [Abstract]

Summary of Changes

The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2016 (in thousands):

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Total
Balance at January 1, 2016 (a)	$	(22,145	)	$	(2,129	)	$	(128	)	$	(97	)	$	(24,499	)
Other comprehensive income before reclassifications	(5,617		)	—			323			—			(5,294		)
Amounts reclassified from AOCL (b)	2,420			197			(205		)	—			2,412
Net current period other comprehensive income	(3,197		)	197			118			—			(2,882		)
Balance at December 31, 2016 (a)	$	(25,342	)	$	(1,932	)	$	(10	)	$	(97	)	$	(27,381	)

(a) Determined using a combined average statutory tax rate of 40%.

(b) See table below.

The following table provides details about reclassifications out of AOCL for the year ended December 31, 2016 (in thousands):

	Amounts Reclassified from AOCL			Affected Line Item in the Statements of Consolidated Income
	For the Year Ended December 31, 2016
Actuarial Loss on Postretirement Benefits	$	4,001		Operating Expenses: Operations
Income Taxes	(1,581		)	Income Taxes (a)
	$	2,420
Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	333		Interest Charges
Income Taxes	(136		)	Income Taxes (a)
	$	197
Unrealized Gain on Available-for-Sale Securities	$	(342	)	Other Income
Income Taxes	137			Income Taxes (a)
	$	(205	)
Losses from reclassifications for the period net of tax	$	2,412

(a) Determined using a combined average statutory tax rate of 40%.

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Quarterly Financial Data (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2016

Quarterly Financial Information Disclosure [Abstract]

Summary of Quarterly Results

	2016 Quarter Ended												2015 Quarter Ended
	March 31			June 30			Sept. 30			Dec. 31			March 31			June 30			Sept. 30			Dec. 31
Operating Revenues	$	333,035		$	154,402		$	219,082		$	329,981		$	382,952		$	177,710		$	141,062		$	257,844
Expenses:
Cost of Sales - (Excluding depreciation)	152,975			98,340			142,988			186,684			241,707			90,945			99,124			127,566
Operations and Maintenance Including Fixed Charges	73,042			71,034			69,410			77,858			71,279			62,634			63,867			71,148
Income Taxes	39,267			(7,189		)	2,807			19,266			16,613			(3,279		)	(10,968		)	(1,006		)
Energy and Other Taxes	1,925			1,243			1,449			1,725			2,196			1,265			1,231			1,334
Total Expenses	267,209			163,428			216,654			285,533			331,795			151,565			153,254			199,042
Other Income and Expense	2,361			4,228			7,236			1,560			2,696			(12,804		)	(340		)	(7,854		)
Income (Loss) from Continuing Operations	68,187			(4,798		)	9,664			46,008			53,853			13,341			(12,532		)	50,948
Loss from Discontinued Operations  -  (Net of tax benefit)	(118		)	(29		)	(29		)	(75		)	(276		)	(74		)	(91		)	(62		)
Net Income (Loss)	$	68,069		$	(4,827	)	$	9,635		$	45,933		$	53,577		$	13,267		$	(12,623	)	$	50,886
Basic Earnings Per Common Share:
Continuing Operations	$	0.96		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Discontinued Operations	—			—			—			—			—			—			—			—
Basic Earnings Per Common Share	$	0.96		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Average Shares of Common Stock Outstanding - Basic	71,127			75,298			79,478			79,478			68,397			68,467			68,607			69,460
Diluted Earnings Per Common Share:
Continuing Operations	$	0.95		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Discontinued Operations	—			—			—			—			—			—			—			—
Diluted Earnings Per Common Share	$	0.95		$	(0.06	)	$	0.12		$	0.58		$	0.79		$	0.19		$	(0.18	)	$	0.73
Average Shares of Common Stock Outstanding - Diluted	71,416			75,298			79,635			79,643			68,618			68,653			68,607			69,646

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)			3 Months Ended	12 Months Ended
	May 08, 2015	Feb. 26, 2015 shares	Jun. 30, 2015 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 31, 2016 USD ($) county mi shares	Dec. 31, 2015 USD ($) shares	Feb. 25, 2015 shares
Accounting Policies [Abstract]
Number of counties in which entity operates | county							7
Length of natural gas pipeline (in miles) | mi							100
Common stock, authorized (in shares) | shares		120,000,000					120,000,000	120,000,000	60,000,000
Stock split, conversion ratio	2	2
Public Utilities Assessment (PUA) included in utility revenue and energy and other taxes				$ 1,100,000	$ 1,200,000	$ 1,100,000
Composite annual rate for all depreciable utility property				2.20%	2.20%	2.20%
Useful life				50 years
Interest capitalized				$ 6,600,000	$ 4,900,000	$ 4,600,000
Impairment of nonutility property and equipment and other noncurrent assets				0	0	0
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization							$ 8,800,000	$ 8,900,000
Treasury stock held (in shares) | shares							212,617	236,571
Schedule of Equity Method Investments [Line Items]
Impairment losses				0		0
Gross book value of utility plant							$ 2,424,134,000	$ 2,211,239,000
Book value of nonutility property and equipment							821,942,000	785,646,000
Accumulated depreciation for utility property and equipment							471,222,000	440,473,000
Accumulated depreciation for nonutility property and equipment							151,084,000	108,307,000
Intangible assets							15,820,000	21,553,000
Increase (decrease) in intangible assets				(5,700,000)
Increase (decrease) adjustment related to purchase price allocations				(4,600,000)
Amortization expense				1,100,000	0
Goodwill				8,880,000	8,880,000		4,838,000	8,880,000
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs (beginning balance)				57,943,000	42,502,000
Accretion				1,937,000	1,675,000
Additions				1,098,000	802,000
Settlements				(1,551,000)	(1,110,000)
Revisions in Estimated Cash Flows				0	14,074,000
AROs (ending balance)				59,427,000	57,943,000	$ 42,502,000
Goodwill [Roll Forward]
Beginning Balance				8,880,000
Fair Value Adjustments During Measurement Period (See Note 3)				(4,042,000)
Ending Balance				4,838,000	8,880,000
Noncurrent Assets
Schedule of Equity Method Investments [Line Items]
Intangible assets							15,800,000	21,600,000
Goodwill				8,900,000	8,900,000		4,800,000	$ 8,900,000
Goodwill [Roll Forward]
Beginning Balance				8,900,000
Ending Balance				$ 4,800,000	8,900,000
Minimum
Schedule of Equity Method Investments [Line Items]
Useful life of intangible assets				2 years
Maximum
Schedule of Equity Method Investments [Line Items]
Useful life of intangible assets				20 years
Energenic
Schedule of Equity Method Investments [Line Items]
Impairment losses			$ 7,700,000		$ 7,700,000
Solar assets
Schedule of Equity Method Investments [Line Items]
Book value of nonutility property and equipment							652,800,000
Cogeneration assets
Schedule of Equity Method Investments [Line Items]
Book value of nonutility property and equipment							124,200,000
Other property and equipment
Schedule of Equity Method Investments [Line Items]
Book value of nonutility property and equipment							$ 44,900,000

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STOCK-BASED COMPENSATION PLAN (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Fair Value Per Share (in USD per share)	$ 26.89	$ 26.89		$ 24.96	$ 26.89
Expected volatility, measurement period	3 years
Service period of shares	3 years
Net Expense	$ 3,507	$ 1,681	$ 1,746
Capitalized	$ (385)	$ (216)	(147)
Unrecognized compensation cost of awards granted under the plan				$ 4,000
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	1 year 8 months 12 days
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)	$ 26.89
Granted (in USD per share)	23.28
Vested (in USD per share)	25.69
Cancelled/Forfeited (in USD per share)	25.11
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 24.96	$ 26.89
Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ 3,892	$ 1,897	1,893
EPS | Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ (100)	$ (1,200)	$ (1,100)
Officers and other key employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	194,347	158,929	136,526
Actual amount of shares that ultimately vest of the original share units granted, minimum	0.00%
Actual amount of shares that ultimately vest of the original share units granted, maximum	200.00%
Shares Outstanding (in shares)	226,191	226,191		295,515	226,191
Number of shares awarded during the period (in shares)	13,247	0	0
Market value of shares awarded (in shares)	$ 300
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	226,191
Granted (in shares)	194,347	158,929	136,526
Vested (in shares)	(113,917)
Cancelled/Forfeited (in shares)	(11,106)
Nonvested Shares Outstanding, ending balance (in shares)	295,515	226,191
Expected number of shares to be awarded (in shares)				29,044
Officers and other key employees | Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ 3,051	$ 1,128	$ 1,260
Officers and other key employees | 2015 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	33,537	33,537			33,537
Fair Value Per Share (in USD per share)	$ 26.31	$ 26.31			$ 26.31
Expected Volatility		16.00%
Risk-Free Interest Rate		1.10%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	33,537
Nonvested Shares Outstanding, ending balance (in shares)		33,537
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)	$ 26.31
Nonvested Shares Outstanding, ending balance (in USD per share)		$ 26.31
Officers and other key employees | 2015 - EGR, ROE, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	73,118	73,118			73,118
Fair Value Per Share (in USD per share)	$ 29.47	$ 29.47			$ 29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	73,118
Nonvested Shares Outstanding, ending balance (in shares)		73,118
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)	$ 29.47
Nonvested Shares Outstanding, ending balance (in USD per share)		$ 29.47
Officers and other key employees | 2016 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	66,101			66,101
Fair Value Per Share (in USD per share)	$ 22.53			$ 22.53
Expected Volatility	18.10%
Risk-Free Interest Rate	1.31%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	66,101
Weighted Average Fair Value
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 22.53
Officers and other key employees | 2016 - CEGR, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	122,759			122,759
Fair Value Per Share (in USD per share)	$ 23.52			$ 23.52
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	122,759
Weighted Average Fair Value
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 23.52
Directors
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	35,197
Vesting period of shares	12 months
Shares Outstanding (in shares)	26,338	26,338		35,197	26,338
Market value of shares awarded (in shares)	$ 800	$ 800	600
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	26,338
Granted (in shares)	35,197
Vested (in shares)	(26,338)
Cancelled/Forfeited (in shares)	0
Nonvested Shares Outstanding, ending balance (in shares)	35,197	26,338
Directors | Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ 841	$ 769	$ 633
Directors | 2016
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	35,197			35,197
Fair Value Per Share (in USD per share)	$ 23.88			$ 23.88
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	35,197
Weighted Average Fair Value
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 23.88
2015 Omnibus Equity Compensation Plan
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of options granted (in shares)	0	0	0
Number of options outstanding (in shares)			0	0	0
Performance-based restricted shares
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Return on equity award threshold		7.00%
Performance-based restricted shares | Officers and other key employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares	3 years
Stock appreciation rights
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	0	0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)	0	0	0
Restricted stock
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Return on equity award threshold	7.00%
Restricted stock | Officers and other key employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	58,304	47,678
Vesting period of shares		3 years
Payout limit, percentage		100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)	58,304	47,678
Restricted stock | Directors
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	35,197	26,338	23,220
Percent of shares granted that generally vest				100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)	35,197	26,338	23,220
Restricted stock | Tranche Two
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Service period of shares		2 years
Restricted stock | Tranche Three
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Service period of shares		3 years
Performance shares | 2012 and 2013 Grants
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares	3 years

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AFFILIATIONS AND DISCONTINUED OPERATIONS - AFFILIATIONS (Details) $ in Thousands		12 Months Ended
	Dec. 31, 2015 USD ($) investment agreement	Dec. 31, 2016 USD ($) mi	Dec. 31, 2015 USD ($) investment agreement	Dec. 31, 2014 USD ($)	Dec. 31, 2011
Affiliations [Abstract]
Notes receivable from affiliate	$ 16,400	$ 15,700	$ 16,400
Notes receivable from affiliate, current	3,134	$ 2,461	3,134
Length of natural gas pipeline (in miles) | mi		100
Net investments in unconsolidated affiliates		$ 7,500	18,000	$ 2,400
Notes receivable secured by property, plant, and equipment of affiliates		$ 13,600
Interest accrual on secured notes receivable		7.50%
Unsecured notes receivable		$ 2,100
Net asset - included in investment in affiliates and other noncurrent liabilities		28,900
Combined equity contributions and the notes receivable - affiliate		44,600
Equity Method Investment, Summarized Financial Information [Abstract]
Goodwill	$ 8,880	$ 4,838	$ 8,880
Energenic
Affiliations [Abstract]
Equity interest					50.00%
Potato Creek
Affiliations [Abstract]
Equity interest		30.00%
PennEast
Affiliations [Abstract]
Length of natural gas pipeline (in miles) | mi		100
Marina Energy LLC | Energenic
Affiliations [Abstract]
Equity interest				50.00%
Number of distribution and purchase agreements | agreement	2		2
Number of investments owned | investment	8		8
Notes receivable from affiliate	$ 19,500		$ 19,500
Notes receivable from affiliate, current		$ 1,500
Percentage of fair value of assets acquired and liabilities assumed	100.00%		100.00%
Consideration received	$ 46,000
Fair value of the interest in Partner Projects exchanged	14,500
Equity Method Investment, Summarized Financial Information [Abstract]
Current assets (excluding inventory)	7,804		$ 7,804
Inventory	3,154		3,154
Note Receivable Received	19,504		19,504
Fixed Assets	46,460		46,460
Identifiable Intangibles	16,950		16,950
Goodwill	4,838		4,838
Noncurrent assets	4,783		4,783
Current liabilities	(8,196)		(8,196)
Note Payable - Affiliate	(16,986)		(16,986)
Long-Term Debt, including current portion	(21,642)		(21,642)
Capital Lease Payable	(10,458)		(10,458)
Other Non-Current Liabilities	(181)		(181)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects	$ 46,030		$ 46,030
Marina Energy LLC | Energenic | Co-venturer
Affiliations [Abstract]
Number of investments owned | investment	7		7
Fair value of the interest in Partner Projects exchanged	$ 31,500
Midstream | PennEast
Affiliations [Abstract]
Equity interest		20.00%

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AFFILIATIONS AND DISCONTINUED OPERATIONS - OPERATING RESULTS OF DISCONTINUED OPERATIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Loss before Income Taxes: [Abstract]
Income Tax Benefits									$ 133	$ 257	$ 312
Loss from Discontinued Operations - (Net of tax benefit)	$ (75)	$ (29)	$ (29)	$ (118)	$ (62)	$ (91)	$ (74)	$ (276)	$ (251)	$ (503)	$ (582)
Earnings Per Common Share from Discontinued Operations - Net
Basic and Diluted (in USD per share)									$ 0.00	$ (0.01)	$ (0.01)
Sand Mining
Loss before Income Taxes: [Abstract]
Loss before Income Taxes									$ (205)	$ (422)	$ (620)
Fuel Oil
Loss before Income Taxes: [Abstract]
Loss before Income Taxes									$ (179)	$ (338)	$ (274)

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INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Tax at Statutory Rate									$ 60,624	$ 37,440	$ 35,727
Increase (Decrease) Resulting from:
State Income Taxes									6,438	3,985	1,960
ESOP Dividend									(1,300)	(1,298)	(1,232)
Amortization of Investment Tax Credits - Utility									0	(149)	(211)
AFUDC									(900)	(1,109)	(1,481)
Investment and Other Tax Credits									(10,706)	(37,503)	(30,661)
Other - Net									(5)	(6)	347
Income Taxes: Continuing Operations	$ 19,266	$ 2,807	$ (7,189)	$ 39,267	$ (1,006)	$ (10,968)	$ (3,279)	$ 16,613	54,151	1,360	4,449
Income Taxes: Discontinued Operations									(133)	(257)	(312)
Total Income Tax Expense									54,018	1,103	4,137
Current:
Federal									0	0	(62)
State									(1,638)	(2,352)	3,052
Total Current									(1,638)	(2,352)	2,990
Deferred:
Federal									44,246	(4,622)	1,707
State									11,543	8,483	(37)
Total Deferred									55,789	3,861	1,670
Investment Tax Credit - Utility									0	(149)	(211)
Income Taxes: Continuing Operations	19,266	$ 2,807	$ (7,189)	39,267	(1,006)	$ (10,968)	$ (3,279)	16,613	54,151	1,360	4,449
Income Taxes: Discontinued Operations									$ (133)	(257)	(312)
Annual amortization rate of investment tax credits									3.00%
Deferred Tax Assets:
Net Operating Loss Carryforward												$ 211,004	$ 195,358
Investment and Other Tax Credits												213,946	200,491
Derivatives / Unrealized Gain												0	5,652
Deferred State Tax												28,833	24,833
Pension & Other Post Retirement Benefits												19,351	29,998
Deferred Revenues												7,669	4,924
Provision for Uncollectibles												5,231	4,200
Other												8,368	6,448
Total Deferred Tax Asset												494,402	471,904
Deferred Tax Liabilities:
Book versus Tax Basis of Property												732,535	675,521
Deferred Gas Costs - Net												2,052	3,998
Derivatives / Unrealized Loss												1,794	0
Environmental Remediation												32,885	19,207
Deferred Regulatory Costs												1,554	566
Budget Billing - Customer Accounts												3,347	830
Deferred Pension & Other Post Retirement Benefits												34,432	42,216
Conservation Incentive Program												11,846	1,132
Equity In Loss Of Affiliated Companies												3,092	9,111
Other												14,414	15,268
Total Deferred Tax Liability												837,951	767,849
Deferred Tax Liability - Net												343,549	295,945
Research and development credits												3,300
Unrecognized tax benefits	1,445			559	559			552	$ 559	552	547	1,445	559	$ 552
Accrued interest and penalties on unrecognized tax benefits												700	$ 700	$ 700
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance (beginning)				$ 559				$ 552	559	552	547
Increase as a result of tax positions taken in prior years									886	7	5
Balance (ending)	$ 1,445				$ 559				$ 1,445	$ 559	$ 552
Federal
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												557,678
Investment Tax Credit Carryforward												209,424
Alternative minimum tax credits												1,200
Federal | 2030
Deferred Tax Liabilities:
Investment Tax Credit Carryforward												11,628
Federal | 2031
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												163,572
Investment Tax Credit Carryforward												25,664
Federal | 2032
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												42,988
Investment Tax Credit Carryforward												32,071
Federal | 2033
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												67,496
Investment Tax Credit Carryforward												45,606
Federal | 2034
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												119,122
Investment Tax Credit Carryforward												37,699
Federal | 2035
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												70,992
Investment Tax Credit Carryforward												45,097
Federal | 2036
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												93,508
Investment Tax Credit Carryforward												11,659
State
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												220,013
State | 2031
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												45,866
State | 2032
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												19,356
State | 2033
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												34,940
State | 2034
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												28,622
State | 2035
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												9,860
State | 2036
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												$ 81,369

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PREFERRED STOCK (Details)	Dec. 31, 2016 shares
Equity [Abstract]
Number of authorized shares of Preference Stock (in shares)	2,500,000

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COMMON STOCK (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	May 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning of Year (in shares)		70,965,622	68,334,860	65,430,084
New Issues During Year:
Dividend Reinvestment Plan (in shares)		417,095	2,604,424	2,881,556
Stock-Based Compensation Plan (in shares)		45,338	26,338	23,220
Public Equity Offering (in shares)	8,050,000	8,050,000	0	0
End of Year (in shares)		79,478,055	70,965,622	68,334,860
Par value of common stock (in USD per share)	$ 1.25	$ 1.25	$ 1.25
Net excess over par value recorded in premium on common stock		$ 207,500
Proceeds from issuance of common stock	$ 203,600	$ 214,426	$ 63,192	$ 80,680
Incremental shares included in diluted earnings per share (in shares)		112,590	195,139	150,062
Dividend per share (in USD per share)		$ 1.07	$ 1.02	$ 0.96
Equity capital raised through Dividend Reinvestment Plan		$ 10,800

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FINANCIAL INSTRUMENTS (Details)	1 Months Ended	3 Months Ended			12 Months Ended
	Jun. 30, 2015 USD ($) term	Sep. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($) term	Dec. 31, 2016 USD ($) counterparty	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 31, 2011
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity investment impairments					$ 0		$ 0
Investment in Affiliate					$ 28,906,000	$ 16,983,000
Number of counterparties | counterparty					3
Carrying amount of long-term debt, including current maturities					$ 1,047,482,000	1,035,848,000
Unamortized debt issuance costs					7,600,000	9,000,000
Derivatives-Energy Related Assets | Supplier concentration risk
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current and noncurrent derivatives					$ 9,300,000
Percentage of current and noncurrent derivatives					11.50%
Atlantic City Note Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Amount of advance	$ 10,000,000			$ 10,000,000
Interest rate of advance	1.00%
Term of loans	6 months
Number of additional terms | term	2			2
Extension term	3 months
Energenic
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest								50.00%
Contract term								20 years
Equity investment impairments				$ 7,700,000		7,700,000
Share of settlement					$ 7,500,000
Associated costs					7,000,000
Investment in Affiliate					600,000
Notes receivable due from Affiliate					$ 13,600,000
Energenic | Other Income
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds received			$ 2,100,000
Energenic | Equity in Earnings of Affiliated Companies
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds received		$ 5,300,000
Marina Energy LLC | Energenic
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest							50.00%
ACB Energy Partners, LLC
Accounts, Notes, Loans and Financing Receivable [Line Items]
Debt service reserve						1,700,000
South Jersey Gas Company | Minimum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Term of loans					5 years
South Jersey Gas Company | Maximum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Term of loans					10 years
Level 1
Accounts, Notes, Loans and Financing Receivable [Line Items]
Margin accounts with selected counterparties to support risk management activities					$ 11,700,000	43,700,000
Level 1 | Marina Energy LLC
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held in escrow					1,900,000	3,400,000
Level 2
Accounts, Notes, Loans and Financing Receivable [Line Items]
Fair value of long-term debt, including current maturities					1,080,800,000	1,079,000,000
Carrying amount of long-term debt, including current maturities					1,039,900,000	1,026,900,000
Level 2 | South Jersey Gas Company | Financing receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Long-term receivables, net of unamortized discount					9,500,000	12,900,000
Imputed interest on long term receivables					$ 900,000	$ 1,300,000

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SEGMENTS OF BUSINESS (Details) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Mar. 31, 2016 USD ($)	Dec. 31, 2015 USD ($) investment	Sep. 30, 2015 USD ($)	Jun. 30, 2015 USD ($)	Mar. 31, 2015 USD ($)	Dec. 31, 2016 USD ($) category	Dec. 31, 2015 USD ($) investment	Dec. 31, 2014 USD ($)
Segment Reporting Information [Line Items]
Operating Revenues	$ 329,981	$ 219,082	$ 154,402	$ 333,035	$ 257,844	$ 141,062	$ 177,710	$ 382,952	$ 1,036,500	$ 959,568	$ 886,996
Operating Income (Loss)									189,276	156,894	127,603
Depreciation and Amortization									109,818	91,042	78,511
Interest Charges									31,449	31,622	29,560
Income Taxes	19,266	$ 2,807	$ (7,189)	$ 39,267	(1,006)	$ (10,968)	$ (3,279)	$ 16,613	54,151	1,360	4,449
Property Additions									269,689	361,994	339,469
Identifiable Assets	3,730,567				$ 3,471,933				3,730,567	3,471,933
Marina Energy LLC | Energenic
Segment Reporting Information [Line Items]
Property, Plant and Equipment obtained through acquisition									$ 5,600	$ 40,900
Number of acquired projects (in investments) | investment					8					8
Energy Group and Energy Services
Segment Reporting Information [Line Items]
Number of Operating Segments | category									2
Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues									$ 1,094,093	$ 1,006,642	926,518
Interest Charges									42,304	40,523	36,036
Operating Segments | Gas Utility Operations
Segment Reporting Information [Line Items]
Operating Revenues									461,055	534,290	501,875
Operating Income (Loss)									122,455	119,585	113,690
Depreciation and Amortization									63,901	58,668	52,155
Interest Charges									17,875	19,906	17,872
Income Taxes									39,366	36,945	34,895
Property Additions									228,275	218,260	201,737
Identifiable Assets	2,551,923				$ 2,281,576				2,551,923	2,281,576
Operating Segments | Energy Group
Segment Reporting Information [Line Items]
Operating Revenues									495,618	366,345	327,822
Operating Income (Loss)									53,354	32,848	9,506
Depreciation and Amortization									821	596	251
Interest Charges									350	626	638
Income Taxes									20,862	13,858	5,419
Property Additions									1,649	2,435	1,439
Identifiable Assets	327,028				342,299				327,028	342,299
Operating Segments | Energy Group | Wholesale Energy Operations
Segment Reporting Information [Line Items]
Operating Revenues									220,707	129,098	77,048
Operating Income (Loss)									41,667	35,024	9,493
Depreciation and Amortization									484	435	168
Interest Charges									0	441	371
Income Taxes									15,882	14,410	4,822
Property Additions									7	382	18
Identifiable Assets	233,019				231,660				233,019	231,660
Operating Segments | Energy Group | Retail Gas and Other Operations
Segment Reporting Information [Line Items]
Operating Revenues									92,371	87,198	127,001
Operating Income (Loss)									4,680	(3,218)	479
Depreciation and Amortization									337	161	83
Interest Charges									350	185	267
Income Taxes									2,118	(978)	787
Property Additions									1,642	2,053	1,421
Identifiable Assets	52,729				55,111				52,729	55,111
Operating Segments | Energy Group | Retail Electric Operations
Segment Reporting Information [Line Items]
Operating Revenues									182,540	150,049	123,773
Operating Income (Loss)									7,007	1,042	(466)
Income Taxes									2,862	426	(190)
Identifiable Assets	41,280				55,528				41,280	55,528
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Operating Revenues									102,273	74,851	66,647
Operating Income (Loss)									13,883	2,495	2,922
Depreciation and Amortization									43,696	30,558	25,289
Income Taxes									(6,121)	(49,039)	(36,181)
Property Additions									38,624	139,397	132,298
Identifiable Assets	770,589				795,116				770,589	795,116
Operating Segments | Energy Services | On-Site Energy Production
Segment Reporting Information [Line Items]
Operating Revenues									94,375	63,665	56,129
Operating Income (Loss)									13,301	2,027	2,560
Depreciation and Amortization									43,395	30,242	25,020
Interest Charges									11,961	8,169	8,723
Income Taxes									(6,353)	(49,225)	(36,404)
Property Additions									38,193	139,018	132,214
Identifiable Assets	767,710				790,231				767,710	790,231
Operating Segments | Energy Services | Appliance Service Operations
Segment Reporting Information [Line Items]
Operating Revenues									7,898	11,186	10,518
Operating Income (Loss)									582	468	362
Depreciation and Amortization									301	316	269
Income Taxes									232	186	223
Property Additions									431	379	84
Identifiable Assets	2,879				4,885				2,879	4,885
Operating Segments | Corporate & Services
Segment Reporting Information [Line Items]
Operating Revenues									35,147	31,156	30,174
Operating Income (Loss)									(416)	1,966	1,485
Depreciation and Amortization									1,400	1,220	816
Interest Charges									12,118	11,822	8,803
Income Taxes									44	(404)	316
Property Additions									1,141	1,902	3,995
Identifiable Assets	649,795				652,325				649,795	652,325
Intersegment
Segment Reporting Information [Line Items]
Operating Revenues									(57,593)	(47,074)	(39,522)
Interest Charges									(10,855)	(8,901)	$ (6,476)
Identifiable Assets	(570,524)				(600,928)				(570,524)	(600,928)
Discontinued Operations
Segment Reporting Information [Line Items]
Identifiable Assets	$ 1,756				$ 1,545				$ 1,756	$ 1,545

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LEASES - OPERATING (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Operating Leases, Future Minimum Payments Receivable [Abstract]
2017	$ 5,396
2018	5,396
2019	5,396
2020	5,396
2021	5,396
Thereafter	29,230
Total minimum future rentals	56,210
Thermal energy generating property and equipment
Property Subject to or Available for Operating Lease, Net [Abstract]
Property and equipment under operating lease	75,900	$ 78,200
Accumulated depreciation of property and equipment under operating lease	$ 31,400	$ 28,500

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LEASES - CAPITAL (Details) - USD ($) $ in Thousands		12 Months Ended
	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015
Capital Leased Assets [Line Items]
Useful life		50 years
Accumulated depreciation on capital lease	$ 471,222	$ 471,222	$ 440,473
Facilities and equipment
Capital Leased Assets [Line Items]
Interest rate		6.80%
Carrying costs of the capital lease			4,100
Purchase price of respective assets	10,600
Accumulated depreciation on capital lease	$ 200	$ 200	$ 0
Minimum | Facilities and equipment
Capital Leased Assets [Line Items]
Useful life		7 years
Maximum | Facilities and equipment
Capital Leased Assets [Line Items]
Useful life		39 years

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RATES AND REGULATORY ACTIONS (Details) $ in Thousands				1 Months Ended																		12 Months Ended			61 Months Ended	300 Months Ended
	Oct. 01, 2016 USD ($)	Feb. 29, 2016 USD ($)	Oct. 01, 2014	Oct. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)	Jul. 31, 2016 USD ($)	Jun. 30, 2016 USD ($)	Apr. 30, 2016 USD ($)	Feb. 29, 2016 USD ($)	Aug. 31, 2015 USD ($)	Jul. 31, 2015 USD ($)	Jun. 30, 2015 USD ($)	Apr. 30, 2015 USD ($)	Jan. 31, 2015 USD ($)	Sep. 30, 2014 USD ($)	Aug. 31, 2014 USD ($)	Jul. 31, 2014 USD ($)	May 31, 2014 USD ($)	Sep. 30, 2013 USD ($)	Feb. 28, 2013 USD ($)	Jan. 31, 2009 USD ($)	Dec. 31, 2016 USD ($) site customer	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Sep. 30, 2014 USD ($)	Dec. 31, 2016 USD ($) site customer	Jan. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Sep. 30, 2015 USD ($)	Jun. 30, 2014 USD ($)	Jan. 31, 2014 USD ($)	Jun. 30, 2013 USD ($)
Schedule of Capitalization [Line Items]
Approved base rate increase															$ 20,000
Rate of return on base rate															7.10%
Return on common equity															9.75%
Composite depreciation rate			2.10%																						2.40%
Amount of AIRP																				$ 141,200
Term of AIRP																				4 years
Annual investment amount of AIRP																				$ 35,300
Investment amount of SHARP																$ 103,500			$ 280,000					$ 36,600
Term of SHARP																3 years			7 years
Number of sites for environmental cleanup (in sites) | site																						12				12
Regulatory assets																						$ 410,746				$ 410,746		$ 323,434
Number of customers purchasing energy commodity from another entity | customer																						33,467				33,467
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							$ (800)
Approved request for revenue increase (decrease)		$ (7,900)							$ (7,900)
Regulatory assets																						$ 219				$ 219		496
Environmental Remediation Costs: Expended - Net
Schedule of Capitalization [Line Items]
Regulatory assets																						71,997				71,997		42,032
Deferred pipeline integrity costs
Schedule of Capitalization [Line Items]
Regulatory assets																						4,000				4,000		2,700
New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Approved requested rate increase (decrease)				$ 11,000
Roll of AIRP investments into base rates																						80,200
Approved budget					$ 56,000
South Jersey Gas Company | Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Approved requested rate increase (decrease)				(1,600)
South Jersey Gas Company | Storm Hardening and Reliability Program | Building
Schedule of Capitalization [Line Items]
Investments during the period																							$ 33,700
South Jersey Gas Company | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Authorized replacement investments (up to)				$ 302,500
Approved budget					5,600
Increase (decrease) in Universal Service Fund recoveries	$ 1,100
South Jersey Gas Company | New Jersey Board of Public Utilities | Storm Hardening and Reliability Program
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates								$ 4,300
Approved requested rate increase (decrease)					3,900
Accelerated Infrastructure Replacement Program
Schedule of Capitalization [Line Items]
Approved base rate increase															$ 7,500
Requested increase (decrease) in rates									13,000
Amount of AIRP									$ 500,000
Investments to be rolled to base rate															69,900										$ 69,900
Extension period of AIRP, requested and then received		7 years		5 years
Basic Gas Supply Service
Schedule of Capitalization [Line Items]
Bill credits																															$ 11,200
Percent of increase (decrease) in regulatory costs not yet approved																		9.30%
Amount of increase (decrease) in regulatory costs approved															27,000										27,000				$ (28,400)
Requested increase (decrease) in rates												$ (28,400)						$ 27,000
Basic Gas Supply Service | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Approved requested rate increase (decrease)					$ (47,100)
Basic Gas Supply Service | South Jersey Gas Company
Schedule of Capitalization [Line Items]
Bill credits																						$ 10,000				$ 10,000	$ 20,000
Basic Gas Supply Service | South Jersey Gas Company | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							(47,100)
Conservation Incentive Program
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							46,500					(11,300)						(21,800)
Conservation Incentive Program | Non-weather
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							9,900					(8,800)						4,200
Conservation Incentive Program | Weather
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							36,600					(2,500)						(26,000)
Allowance for Funds Used Under Construction
Schedule of Capitalization [Line Items]
Approved base rate increase				$ 5,700											3,200
Storm Hardening and Reliability Program
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs approved																													4,000
Requested increase (decrease) in rates													$ 4,000
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs approved										$ 2,600					2,200										2,200
Requested increase (decrease) in rates												(7,600)		$ 56,000				$ 1,400
Period of program																					2 years
Extension period										2 years
Amount of regulatory costs available for recovery										$ 36,300											$ 17,000
Energy Efficiency Tracker | South Jersey Gas Company
Schedule of Capitalization [Line Items]
Amount of regulatory costs available for recovery																																$ 24,000
Societal Benefits Clause
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates						$ 16,000					$ (5,000)						$ (25,700)
Remediation Adjustment Clause
Schedule of Capitalization [Line Items]
Number of sites for environmental cleanup (in sites) | site																						12				12
Amortization period																						7 years
Regulated costs recovered																										$ 112,700
Remediation Adjustment Clause | Environmental Remediation Costs: Expended - Net
Schedule of Capitalization [Line Items]
Regulatory assets																						$ 72,000				$ 72,000		$ 42,000
New Jersey Clean Energy Program
Schedule of Capitalization [Line Items]
Amount of statewide funding approved							345,000					345,000											345,000	345,000						$ 345,000		345,000
Regulatory costs entity is expensing							14,600					14,600											14,600	14,600						14,500		$ 14,500
Universal Service Fund
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs approved															7,900										7,900				5,200
Amount of statewide funding approved															71,800										71,800				46,400
Amount of statewide costs proposed							56,000					(46,400)											56,000	(46,400)						19,900
Amount of proposed impact of annual costs							$ 1,100					$ (3,400)											$ 1,100	$ (3,400)					$ (3,400)	$ 2,600
Amount of increase (decrease) in annual impact approved															$ 2,600										$ 2,600

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REGULATORY ASSETS & REGULATORY LIABILITIES - ASSETS (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016 USD ($) site asset	Dec. 31, 2015 USD ($)
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 410,746	$ 323,434
Number regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or their predecessors previously operated gas manufacturing plants (in regulatory assets) | asset	2
Number of sites where SJG or their predecessors previously operated gas manufacturing plants (in sites) | site	12
Environmental Remediation Costs: Expended - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 71,997	42,032
Environmental Restoration Costs: Liability for Future Expenditures
Regulatory Assets [Line Items]
Total Regulatory Assets	153,047	123,194
Deferred Asset Retirement Obligation Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	43,014	42,430
Deferred Pension and Other Postretirement Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	85,693	79,779
Deferred Gas Costs - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	0	2,701
Conservation Incentive Program Receivable
Regulatory Assets [Line Items]
Total Regulatory Assets	27,567	2,624
Deferred Interest Rate Contracts
Regulatory Assets [Line Items]
Total Regulatory Assets	7,365	7,631
Energy Efficiency Tracker
Regulatory Assets [Line Items]
Total Regulatory Assets	219	496
Pipeline Supplier Service Charges
Regulatory Assets [Line Items]
Total Regulatory Assets	2,122	3,776
Pipeline Integrity Cost
Regulatory Assets [Line Items]
Total Regulatory Assets	4,810	4,596
AFUDC - Equity Related Deferrals
Regulatory Assets [Line Items]
Total Regulatory Assets	12,434	11,423
Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 2,478	$ 2,752
Environmental restoration costs
Regulatory Assets [Line Items]
Regulatory costs, original recovery period of expenditures	7 years
Allowance for Funds Used Under Construction, Equity Related Deferrals, settlement
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 1,000
Regulatory costs, original recovery period of expenditures	3 years

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REGULATORY ASSETS & REGULATORY LIABILITIES - LIABILITIES (Details) - USD ($) $ in Thousands	1 Months Ended
	Sep. 30, 2014	Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		$ 49,121	$ 42,841
Regulatory assets		410,746	323,434
Deferred Revenue - Net
Regulatory Liabilities [Line Items]
Regulatory assets			2,701
Excess Plant Removal Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		28,226	32,644
Annual amortization reflected in depreciation expense	$ 1,100
Deferred Revenue - Net
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		17,800	0
Societal Benefit Costs Payable
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		$ 3,095	$ 10,197

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PENSION AND OTHER POSTRETIREMENT BENEFITS - NET PERIODIC BENEFIT COST (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Percentage of employees entitled to annuity payments upon retirement	38.20%
Pension Benefits
Net periodic benefit cost [Abstract]
Service Cost	$ 4,843	$ 5,337	$ 4,510
Interest Cost	12,125	11,168	10,735
Expected Return on Plan Assets	(13,508)	(14,789)	(13,491)
Amortizations:
Prior Service (Credits) Cost	212	212	175
Actuarial Loss	9,394	10,608	5,716
Net Periodic Benefit Cost	13,066	12,536	7,645
Capitalized Benefit Costs	(4,645)	(4,805)	(3,047)
Deferred Benefit Costs	(645)	(1,007)	0
Total Net Periodic Benefit Expense	7,776	6,724	4,598
Other Postretirement Benefits
Net periodic benefit cost [Abstract]
Service Cost	851	1,116	891
Interest Cost	2,615	2,973	2,852
Expected Return on Plan Assets	(3,104)	(2,993)	(2,603)
Amortizations:
Prior Service (Credits) Cost	(344)	608	152
Actuarial Loss	1,109	1,342	974
Net Periodic Benefit Cost	1,127	3,046	2,266
Capitalized Benefit Costs	(277)	(1,043)	(722)
Deferred Benefit Costs	0	(256)	0
Total Net Periodic Benefit Expense	$ 850	$ 1,747	$ 1,544

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PENSION AND OTHER POSTRETIREMENT BENEFITS - DETAILS OF ACTIVITY WITHIN THE REGULATORY ASSET AND ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Pension Benefits
Regulatory Assets
Beginning Balance	$ 64,432	$ 71,177
Amounts Arising during the Period: Net Actuarial (Loss) Gain	9,706	(463)
Amounts Arising during the Period: Prior Service Credit	0
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(5,485)	(6,079)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	(203)	(203)
Ending Balance	68,450	64,432
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	35,066	39,468
Amounts Arising during the Period: Net Actuarial (Loss) Gain	8,370	59
Amounts Arising during the Period: Prior Service Credit	0
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(3,838)	(4,452)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	(8)	(9)
Ending Balance	39,590	35,066
Other Postretirement Benefits
Regulatory Assets
Beginning Balance	15,347	27,863
Amounts Arising during the Period: Net Actuarial (Loss) Gain	2,584	(3,155)
Amounts Arising during the Period: Prior Service Credit	257	(499)
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(945)	(1,107)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	0	(7,755)
Ending Balance	17,243	15,347
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	2,062	6,755
Amounts Arising during the Period: Net Actuarial (Loss) Gain	829	(2,285)
Amounts Arising during the Period: Prior Service Credit	84	(106)
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(154)	(221)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	0	(2,081)
Ending Balance	$ 2,821	$ 2,062

XML

PENSION AND OTHER POSTRETIREMENT BENEFITS - ESTIMATED COSTS THAT WILL BE AMORTIZED (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016 USD ($)
Pension Benefits
Regulatory Assets into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	$ 127
Net Actuarial Loss	6,202
Accumulated Other Comprehensive Income (Loss) into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	5
Net Actuarial Loss	3,943
Other Postretirement Benefits
Regulatory Assets into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	(257)
Net Actuarial Loss	1,040
Accumulated Other Comprehensive Income (Loss) into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	(87)
Net Actuarial Loss	$ 207

XML

PENSION AND OTHER POSTRETIREMENT BENEFITS - RECONCILIATIONS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$ (2,463)	$ (2,261)
Noncurrent Liabilities	(95,235)	(76,068)
Pension Benefits
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	254,195	265,434
Service Cost	4,843	5,337	$ 4,510
Interest Cost	12,125	11,168	10,735
Actuarial Loss (Gain)	18,254	(17,349)
Retiree Contributions	0	0
Plan Amendments	0	0
Benefits Paid	(11,129)	(10,395)
Benefit Obligation at End of Year	278,288	254,195	265,434
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	184,824	180,523
Actual Return on Plan Assets	13,569	(2,321)
Employer Contributions	2,278	17,017
Retiree Contributions	0	0
Benefits Paid	(11,129)	(10,395)
Fair Value of Plan Assets at End of Year	189,542	184,824	180,523
Funded Status at End of Year	(88,746)	(69,371)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	(2,463)	(2,261)
Noncurrent Liabilities	(85,957)	(66,906)
Net Amount Recognized at End of Year	(88,420)	(69,167)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	538	741
Net Actuarial Loss	67,912	63,691
Amount Recognized in Regulatory Assets	68,450	64,432	71,177
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	69	77
Net Actuarial Loss	39,521	34,989
Amount Recognized in Accumulated Other Comprehensive Loss	39,590	35,066	39,468
Projected benefit obligation	224,300	207,700
Accumulated benefit obligation	208,300	191,900
Pension Benefits | Amounts Related to Unconsolidated Affiliate
Change in Plan Assets:
Funded Status at End of Year	326	204
Pension Benefits | Accrued Net Benefit Cost at End of Year
Change in Plan Assets:
Funded Status at End of Year	(88,420)	(69,167)
Other Postretirement Benefits
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	57,430	75,592
Service Cost	851	1,116	891
Interest Cost	2,615	2,973	2,852
Actuarial Loss (Gain)	3,121	(8,591)
Retiree Contributions	81	700
Plan Amendments	0	(9,899)
Benefits Paid	(3,748)	(4,461)
Benefit Obligation at End of Year	60,350	57,430	75,592
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	47,759	43,222
Actual Return on Plan Assets	2,784	(423)
Employer Contributions	3,656	8,721
Retiree Contributions	81	700
Benefits Paid	(3,748)	(4,461)
Fair Value of Plan Assets at End of Year	50,532	47,759	43,222
Funded Status at End of Year	(9,818)	(9,671)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	0	0
Noncurrent Liabilities	(9,278)	(9,162)
Net Amount Recognized at End of Year	(9,278)	(9,162)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	(3,032)	(3,289)
Net Actuarial Loss	20,275	18,636
Amount Recognized in Regulatory Assets	17,243	15,347	27,863
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	(989)	(1,074)
Net Actuarial Loss	3,810	3,136
Amount Recognized in Accumulated Other Comprehensive Loss	2,821	2,062	6,755
Other Postretirement Benefits | Amounts Related to Unconsolidated Affiliate
Change in Plan Assets:
Funded Status at End of Year	540	509
Other Postretirement Benefits | Accrued Net Benefit Cost at End of Year
Change in Plan Assets:
Funded Status at End of Year	(9,278)	(9,162)
Supplemental Employee Retirement Plan
Change in Plan Assets:
Employer Contributions	2,300	2,000	$ 1,500
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Projected benefit obligation	53,900	46,500
Accumulated benefit obligation	$ 51,900	$ 45,000

XML

PENSION AND OTHER POSTRETIREMENT BENEFITS - WEIGHTED-AVERAGE ASSUMPTIONS (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount Rate	4.30%	4.83%
Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount Rate	4.83%	4.25%	5.09%
Expected Long-Term Return on Plan Assets	7.50%	7.75%	7.75%
Rate of Compensation Increase	3.50%	3.50%	3.50%
Other Postretirement Benefits
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount Rate	4.13%	4.73%
Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount Rate	4.73%	4.20%	4.91%
Expected Long-Term Return on Plan Assets	6.50%	6.25%	6.25%
Rate of Compensation Increase	3.50%	3.50%	3.50%

XML

PENSION AND OTHER POSTRETIREMENT BENEFITS - PLAN ASSETS (Details) - Pension Benefits	12 Months Ended
	Dec. 31, 2016 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Required capitalization for plan asset allocation (less than)	$ 250,000,000.0
Required capitalization for plan asset allocation, small cap (as low as)	$ 50,000,000.0
U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	28.00%
Target allocation percentage of assets, equity securities, range maximum	48.00%
International equity securities
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	13.00%
Target allocation percentage of assets, equity securities, range maximum	25.00%
Fixed income securities
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	32.00%
Target allocation percentage of assets, equity securities, range maximum	42.00%
Other investments
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	0.00%
Target allocation percentage of assets, equity securities, range maximum	7.00%

XML

PENSION AND OTHER POSTRETIREMENT BENEFITS - FAIR VALUE OF PLAN ASSETS (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2016 USD ($) category
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 184,824	$ 180,523	$ 189,542
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	184,824	180,523
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	$ 189,542	184,824
Pension Benefits | Minimum
Defined Benefit Plan Disclosure [Line Items]
Fund Valuations Lag Period	90 days
Pension Benefits | Maximum
Defined Benefit Plan Disclosure [Line Items]
Fund Valuations Lag Period	120 days
Pension Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 19,702	19,702	23,674
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	19,702
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	23,674	19,702
Pension Benefits | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	138,176	138,176	141,859
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	138,176
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	141,859	138,176
Pension Benefits | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	26,946	26,335	24,009
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26,946	26,335
Actual return on plan assets:
Relating to assets still held at the reporting date	1,014	459
Relating to assets sold during the period	259	454
Purchases, Sales and Settlements	(4,210)	(302)
Fair Value of Plan Assets at End of Year	24,009	26,946
Pension Benefits | Common/Collective Trust Funds - U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	52,058	52,058	51,902
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	52,058
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	51,902	52,058
Pension Benefits | Common/Collective Trust Funds - U.S. | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds - U.S. | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	52,058	52,058	51,902
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	52,058
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	51,902	52,058
Pension Benefits | Common/Collective Trust Funds - U.S. | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Large-Cap
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	14,305	14,305	17,792
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	14,305
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	17,792	14,305
Pension Benefits | U.S. Large-Cap | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	14,305	14,305	$ 17,792
Number of sectors (in categories) | category			5
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	14,305
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	17,792	14,305
Pension Benefits | U.S. Large-Cap | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	$ 0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Large-Cap | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Mid-Cap
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	3,407	3,407	2,479
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,407
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,479	3,407
Pension Benefits | U.S. Mid-Cap | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	3,407	3,407	2,479
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,407
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,479	3,407
Pension Benefits | U.S. Mid-Cap | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Mid-Cap | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Small-Cap
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	260	260
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	260
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		260
Pension Benefits | U.S. Small-Cap | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	260	260
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	260
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		260
Pension Benefits | U.S. Small-Cap | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | U.S. Small-Cap | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | International equity securities
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,695	1,695	3,340
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,695
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	3,340	1,695
Pension Benefits | International equity securities | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,695	1,695	3,340
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,695
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	3,340	1,695
Pension Benefits | International equity securities | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | International equity securities | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	33,236	33,236	33,096
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	33,236
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	33,096	33,236
Pension Benefits | Common/Collective Trust Funds - International | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds - International | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	33,236	33,236	33,096
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	33,236
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	33,096	33,236
Pension Benefits | Common/Collective Trust Funds - International | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	50,664	50,664	54,970
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	50,664
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	54,970	50,664
Pension Benefits | Common/Collective Trust Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	50,664	50,664	54,970
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	50,664
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	54,970	50,664
Pension Benefits | Common/Collective Trust Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Guaranteed Insurance Contract
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	9,960	9,960	9,714
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	9,960
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	9,714	9,960
Pension Benefits | Guaranteed Insurance Contract | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Guaranteed Insurance Contract | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Guaranteed Insurance Contract | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	9,960	10,912	9,714
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	9,960	10,912
Actual return on plan assets:
Relating to assets still held at the reporting date	541	(106)
Relating to assets sold during the period	14	25
Purchases, Sales and Settlements	(801)	(871)
Fair Value of Plan Assets at End of Year	9,714	9,960
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,159	4,159
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,159
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		4,159
Pension Benefits | Hedge Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | Hedge Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | Hedge Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,159	4,331	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,159	4,331
Actual return on plan assets:
Relating to assets still held at the reporting date	(67)	(172)
Relating to assets sold during the period	0	0
Purchases, Sales and Settlements	(4,092)	0
Fair Value of Plan Assets at End of Year	0	4,159
Pension Benefits | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,312	4,312	5,100
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,312
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	5,100	4,312
Pension Benefits | Private Equity Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Private Equity Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Private Equity Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,312	3,616	5,100
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,312	3,616
Actual return on plan assets:
Relating to assets still held at the reporting date	(140)	(302)
Relating to assets sold during the period	245	429
Purchases, Sales and Settlements	683	569
Fair Value of Plan Assets at End of Year	5,100	4,312
Pension Benefits | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,515	8,515	9,195
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,515
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	9,195	8,515
Pension Benefits | Real Estate | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Real Estate | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Real Estate | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,515	7,476	9,195
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,515	7,476
Actual return on plan assets:
Relating to assets still held at the reporting date	680	1,039
Relating to assets sold during the period	0	0
Purchases, Sales and Settlements	0	0
Fair Value of Plan Assets at End of Year	9,195	8,515
Pension Benefits | Cash
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	35	35	63
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	35
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	63	35
Pension Benefits | Cash | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	35	35	63
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	35
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	63	35
Pension Benefits | Cash | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Cash | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	858	858	460
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	858
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	460	858
Pension Benefits | Common/Collective Trust Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	858	858	460
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	858
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	460	858
Pension Benefits | Common/Collective Trust Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | STIF-Type Instrument
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,360	1,360	1,431
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,360
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	1,431	1,360
Pension Benefits | STIF-Type Instrument | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | STIF-Type Instrument | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,360	1,360	1,431
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,360
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	1,431	1,360
Pension Benefits | STIF-Type Instrument | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	47,759	43,222	50,532
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	47,759	43,222
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	50,532	47,759
Other Postretirement Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	3,911	3,911	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,911
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	3,911
Other Postretirement Benefits | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	43,848	43,848	50,532
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	43,848
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	50,532	43,848
Other Postretirement Benefits | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	$ 0	0
Other Postretirement Benefits | U.S. equity securities | Minimum
Actual return on plan assets:
Target plan allocation	30.00%
Other Postretirement Benefits | U.S. equity securities | Maximum
Actual return on plan assets:
Target plan allocation	43.00%
Other Postretirement Benefits | Common/Collective Trust Funds - U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 13,522	13,522	14,878
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,522
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	14,878	13,522
Other Postretirement Benefits | Common/Collective Trust Funds - U.S. | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Common/Collective Trust Funds - U.S. | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	13,522	13,522	14,878
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,522
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	14,878	13,522
Other Postretirement Benefits | Common/Collective Trust Funds - U.S. | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Mutual Fund - U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,309	1,309
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,309
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,309
Other Postretirement Benefits | Mutual Fund - U.S. | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,309	1,309
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,309
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,309
Other Postretirement Benefits | Mutual Fund - U.S. | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Fund - U.S. | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | International equity securities | Minimum
Actual return on plan assets:
Target plan allocation	20.00%
Other Postretirement Benefits | International equity securities | Maximum
Actual return on plan assets:
Target plan allocation	30.00%
Other Postretirement Benefits | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 8,313	8,313	8,674
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,313
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	8,674	8,313
Other Postretirement Benefits | Common/Collective Trust Funds - International | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Common/Collective Trust Funds - International | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,313	8,313	8,674
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,313
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	8,674	8,313
Other Postretirement Benefits | Common/Collective Trust Funds - International | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Mutual Funds - International
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	983	983
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	983
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		983
Other Postretirement Benefits | Mutual Funds - International | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	983	983
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	983
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		983
Other Postretirement Benefits | Mutual Funds - International | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Funds - International | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Fixed income investments | Minimum
Actual return on plan assets:
Target plan allocation	32.00%
Other Postretirement Benefits | Fixed income investments | Maximum
Actual return on plan assets:
Target plan allocation	42.00%
Other Postretirement Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 13,187	13,187	13,537
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,187
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,537	13,187
Other Postretirement Benefits | Common/Collective Trust Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Common/Collective Trust Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	13,187	13,187	13,537
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,187
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,537	13,187
Other Postretirement Benefits | Common/Collective Trust Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Mutual Funds - Bonds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,441	1,441
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,441
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,441
Other Postretirement Benefits | Mutual Funds - Bonds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,441	1,441
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,441
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,441
Other Postretirement Benefits | Mutual Funds - Bonds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Funds - Bonds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Other investments | Minimum
Actual return on plan assets:
Target plan allocation	0.00%
Other Postretirement Benefits | Other investments | Maximum
Actual return on plan assets:
Target plan allocation	7.00%
Other Postretirement Benefits | Mutual Funds - REITS
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 152	152
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	152
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		152
Other Postretirement Benefits | Mutual Funds - REITS | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	152	152
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	152
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		152
Other Postretirement Benefits | Mutual Funds - REITS | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Funds - REITS | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Company Owned Life Insurance
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,826	8,826	13,443
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,826
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,443	8,826
Other Postretirement Benefits | Company Owned Life Insurance | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Company Owned Life Insurance | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,826	8,826	13,443
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,826
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,443	8,826
Other Postretirement Benefits | Company Owned Life Insurance | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Cash
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	26	26	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	26
Other Postretirement Benefits | Cash | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	26	26	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	26
Other Postretirement Benefits | Cash | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Cash | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	$ 0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	$ 0	$ 0

XML

PENSION AND OTHER POSTRETIREMENT BENEFITS - CONTRIBUTIONS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
Pension contribution	$ 0	$ 15,000,000	$ 0
Pension Benefits
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2017	12,141,000
2018	12,583,000
2019	13,529,000
2020	14,056,000
2021	14,757,000
2022- 2025	86,727,000
Pension contribution	0	15,000,000	0
Employer contributions	2,278,000	17,017,000
Other Postretirement Benefits
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2017	4,399,000
2018	4,316,000
2019	4,403,000
2020	4,514,000
2021	4,511,000
2022- 2025	21,308,000
Employer contributions	3,656,000	8,721,000
Expected contribution to plan	3,600,000
Supplemental Employee Retirement Plan
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
Employer contributions	2,300,000	$ 2,000,000	$ 1,500,000
Expected contribution to plan	$ 2,500,000

XML

PENSION AND OTHER POSTRETIREMENT BENEFITS - DEFINED CONTRIBUTION PLAN (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($) $ / employees	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Amount expensed and contributed for matching provision of Savings Plan | $	$ 2.3	$ 2.1	$ 2.0
Employees eligible for defined benefit pension plan
Defined Benefit Plan Disclosure [Line Items]
Matching percentage of participants' contributions	50.00%
Percentage of base compensation (up to)	6.00%
Employees ineligible for defined benefit pension plan
Defined Benefit Plan Disclosure [Line Items]
Matching percentage of participants' contributions	50.00%
Percentage of base compensation (up to)	8.00%
Year-end contribution (in dollars per employee)	1,500
Service threshold to determine year-end contribution (up to, more than)	10 years
Year-end contribution (in dollars per employee)	2,000

XML

LINES OF CREDIT (Details)	1 Months Ended	12 Months Ended
	Sep. 30, 2016 USD ($) extension	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014
Line of Credit Facility [Line Items]
Total Facility	$ 50,000,000	$ 660,000,000
Usage		301,700,000
Available Liquidity		358,300,000
Letters of credit outstanding		$ 4,800,000
Number of extensions (not more than) | extension	2
Weighted average borrowing cost		1.47%	1.13%	0.83%
Average borrowings outstanding		$ 321,900,000	$ 335,000,000
Maximum amounts outstanding		$ 467,700,000	$ 471,100,000
Financial covenant, ratio of indebtedness to consolidated total capitalization (not more than)		0.65
Commercial Paper Program/Revolving Credit Facility
Line of Credit Facility [Line Items]
Term of agreement	364 days
Letters of credit
Line of Credit Facility [Line Items]
Total Facility		$ 4,800,000.0
South Jersey Gas commercial paper program
Line of Credit Facility [Line Items]
Total Facility		$ 200,000,000.0
Fixed maturities of notes, which may not exceed specified number of days		270 days
South Jersey Gas Company
Line of Credit Facility [Line Items]
Total Facility		$ 210,000,000
Usage		105,100,000
Available Liquidity		104,900,000
South Jersey Gas Company | Letters of credit
Line of Credit Facility [Line Items]
Letters of credit outstanding		800,000
South Jersey Gas Company | Commercial Paper Program/Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility		200,000,000
Usage		105,100,000
Available Liquidity		94,900,000
South Jersey Gas Company | Uncommitted Bank Lines
Line of Credit Facility [Line Items]
Total Facility		10,000,000
Usage		0
Available Liquidity		10,000,000
South Jersey Industries Inc.
Line of Credit Facility [Line Items]
Total Facility		450,000,000
Usage		196,600,000
Available Liquidity		253,400,000
South Jersey Industries Inc. | Commercial Paper Program/Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility		450,000,000
Usage		196,600,000
Available Liquidity		$ 253,400,000

XML

LONG-TERM DEBT (Details) - USD ($)	1 Months Ended			12 Months Ended
	Aug. 31, 2016	Jul. 31, 2016	Jan. 31, 2016	Dec. 31, 2016	Sep. 30, 2016	Dec. 31, 2015	Oct. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2011
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 1,047,482,000		$ 1,035,848,000
Less Current Maturities				(231,909,000)		(29,454,000)
Total Long-Term Debt				815,573,000		1,006,394,000
Long-term Debt, Fiscal Year Maturity [Abstract]
2017				231,909,000
2018				38,909,000
2019				258,909,000
2020				67,909,000
2021				52,909,000
Amount of facility				660,000,000	$ 50,000,000
Unamortized debt issuance costs				$ 7,600,000		9,000,000
Energenic
Long-term Debt, Fiscal Year Maturity [Abstract]
Equity interest										50.00%
Senior notes | Series Notes at variable rates due 2019
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				2.32%
Medium-term notes
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity						400,000,000.0
South Jersey Gas Company
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility				$ 210,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2016
Debt Instrument [Line Items]
Stated interest rate	5.437%			5.437%
Total Long-Term Debt Outstanding				$ 0		10,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt retired	$ 10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2016
Debt Instrument [Line Items]
Stated interest rate		4.60%		4.60%
Total Long-Term Debt Outstanding				$ 0		17,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt retired		$ 17,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2017
Debt Instrument [Line Items]
Stated interest rate				4.657%
Total Long-Term Debt Outstanding				$ 15,000,000		15,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2018
Debt Instrument [Line Items]
Stated interest rate				7.97%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2018
Debt Instrument [Line Items]
Stated interest rate				7.125%
Total Long-Term Debt Outstanding				$ 20,000,000		20,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				5.587%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2024 (D)
Debt Instrument [Line Items]
Stated interest rate				3.00%
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2024 (E)
Debt Instrument [Line Items]
Stated interest rate				3.03%
Total Long-Term Debt Outstanding				$ 35,000,000		35,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 7,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2025
Debt Instrument [Line Items]
Stated interest rate				3.63%
Total Long-Term Debt Outstanding				$ 8,182,000		9,091,000
Less Current Maturities				(900,000)
Long-term Debt, Fiscal Year Maturity [Abstract]
Payment towards principal				$ 900,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2026 (G)
Debt Instrument [Line Items]
Stated interest rate				4.84%
Total Long-Term Debt Outstanding				$ 15,000,000		15,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 2,500,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2026 (H)
Debt Instrument [Line Items]
Stated interest rate				4.93%
Total Long-Term Debt Outstanding				$ 45,000,000		45,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 7,500,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2027
Debt Instrument [Line Items]
Stated interest rate				4.03%
Total Long-Term Debt Outstanding				$ 45,000,000		45,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2030 (I)
Debt Instrument [Line Items]
Stated interest rate				4.01%
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, Due November 2018 and November 2019
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				8,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2025
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				2,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2026
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				3,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2027
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				8,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2028, November 2029 and November 2030
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 7,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2030
Debt Instrument [Line Items]
Stated interest rate				4.23%
Total Long-Term Debt Outstanding				$ 30,000,000		30,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2032
Debt Instrument [Line Items]
Stated interest rate				3.74%
Total Long-Term Debt Outstanding				$ 35,000,000		35,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2033
Debt Instrument [Line Items]
Stated interest rate				5.55%
Total Long-Term Debt Outstanding				$ 32,000,000		32,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2034
Debt Instrument [Line Items]
Stated interest rate				6.213%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2035
Debt Instrument [Line Items]
Stated interest rate				5.45%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | Unsecured debt | Series A 2006 Bonds at variable rates due 2036
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 24,900,000		24,900,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.74%
South Jersey Gas Company | Loans payable | Term facility
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 200,000,000		139,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility				200,000,000
Line of credit balance				200,000,000		$ 139,000,000
Average interest rate			1.41%			1.17%
Issuance of additional long-term debt			$ 61,000,000
Marina Energy LLC | Energenic
Long-term Debt, Fiscal Year Maturity [Abstract]
Equity interest								50.00%
Marina Energy LLC | Unsecured debt
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				61,400,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Outstanding amount of note not fixed by interest rate derivatives				$ 46,100,000
Fixed interest rate				4.22%
Marina Energy LLC | Unsecured debt | Series A 2001 Bonds at variable rates due 2031
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 20,000,000		$ 20,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.72%
Marina Energy LLC | Unsecured debt | Series B 2001 Bonds at variable rates due 2021
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 25,000,000		25,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.73%
Marina Energy LLC | Unsecured debt | Series A 2006 Bonds at variable rates due 2036
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 16,400,000		16,400,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.72%
South Jersey Industries Inc.
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility				$ 450,000,000
South Jersey Industries Inc. | Unsecured debt | South Jersey Industries Term Loan at variable rates due 2020
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
South Jersey Industries Inc. | Unsecured debt | Term loan due 2015 | Term facility
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding							$ 50,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				1.79%
South Jersey Industries Inc. | Senior notes | Series B 2012 Notes due 2017
Debt Instrument [Line Items]
Stated interest rate				2.71%
Total Long-Term Debt Outstanding				$ 16,000,000		16,000,000
Less Current Maturities				$ (16,000,000)
South Jersey Industries Inc. | Senior notes | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				3.05%
Total Long-Term Debt Outstanding				$ 60,000,000		60,000,000
South Jersey Industries Inc. | Senior notes | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				3.05%
Total Long-Term Debt Outstanding				$ 30,000,000		30,000,000
South Jersey Industries Inc. | Senior notes | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				3.05%
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
South Jersey Industries Inc. | Senior notes | Series C 2012 Notes due 2022
Debt Instrument [Line Items]
Stated interest rate				3.46%
Total Long-Term Debt Outstanding				$ 35,000,000		35,000,000
South Jersey Industries Inc. | Senior notes | Series Notes at variable rates due 2019
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				40,000,000		40,000,000
South Jersey Industries Inc. | Senior notes | Series Notes at variable rates due 2019
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 60,000,000		60,000,000
ACB Energy Partners, LLC | Loan and security agreement | Loan & Security Agreement
Debt Instrument [Line Items]
Stated interest rate				7.60%
Total Long-Term Debt Outstanding				$ 0		12,735,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity				$ 16,000,000
Payment to retire outstanding debt			$ 12,700,000
ACLE | Debt agreement | Debt Agreement Due 2020, 4.83%, Agreement 1
Debt Instrument [Line Items]
Stated interest rate				4.83%
Total Long-Term Debt Outstanding				$ 0		3,551,000
SCLE | Debt agreement | Debt Agreement Due 2020, 4.83%, Agreement 2
Debt Instrument [Line Items]
Stated interest rate				4.83%
Total Long-Term Debt Outstanding				$ 0		1,738,000
SXLE | Debt agreement | Debt Agreement Due 2020, 4.83%, Agreement 3
Debt Instrument [Line Items]
Stated interest rate				4.83%
Total Long-Term Debt Outstanding				$ 0		3,433,000
ACLE, SCLE and SXLE | Debt agreement
Debt Instrument [Line Items]
Stated interest rate									4.83%
Total Long-Term Debt Outstanding						$ 8,700,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity									$ 10,000,000
Payment to retire outstanding debt	$ 8,300,000

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COMMITMENTS AND CONTINGENCIES (Details)	12 Months Ended		444 Months Ended
	Dec. 31, 2016 USD ($) site union decatherm / day contract	Dec. 31, 2015 USD ($)	Dec. 31, 2016 USD ($) site union decatherm / day contract	Sep. 30, 2016 USD ($)	Dec. 31, 2012 USD ($)	Dec. 31, 1996 USD ($)
Commitment and Contingencies [Line Items]
Minimum purchase amount under contract (in dts/d) | decatherm / day	745,000		745,000
Maximum purchase amount under contract (in dts/d) | decatherm / day	940,000		940,000
Minimum length of contract term	3 years
Maximum length of contract term	10 years
Capacity management contract, term	3 years
Accrual for pending litigation	$ 3,100,000	$ 3,200,000	$ 3,100,000
Percentage of workforce that is unionized	45.00%		45.00%
Number of unions with collective bargaining agreements | union	2		2
Guarantor obligations	$ 125,400,000		$ 125,400,000
Letter of credit provided	660,000,000		660,000,000	$ 50,000,000
Letters of credit outstanding	$ 4,800,000		$ 4,800,000
Number of sites for environmental cleanup (in number of sites) | site	12		12
Number of sites covered by insurance | site	11		11
Insurance policy limit					$ 50,000,000
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning of Year	$ 126,623,000	128,172,000
Accruals	60,713,000	19,489,000	$ 437,100,000
Expenditures	(32,323,000)	(21,038,000)	(282,100,000)
End of Year	155,013,000	$ 126,623,000	155,013,000
Letters of credit
Commitment and Contingencies [Line Items]
Letter of credit provided	4,800,000.0		4,800,000.0
Variable-rate demand bonds
Commitment and Contingencies [Line Items]
Letter of credit provided	$ 87,500,000.0		$ 87,500,000.0
Environmental restoration costs
Commitment and Contingencies [Line Items]
EMI's assumed responsibility for environment liabilities, minimum						$ 1,300,000.0
EMI's assumed responsibility for environment liabilities, maximum						$ 2,100,000.0
Environmental restoration costs | Fuel Oil
Commitment and Contingencies [Line Items]
Number of sites affected by environmental remediation | site	5		5
Environmental restoration costs | Majority of the environmental remediation
Commitment and Contingencies [Line Items]
Number of sites affected by environmental remediation | site	6		6
Environmental restoration costs | Minimum
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	$ 153,000,000		$ 153,000,000
Environmental restoration costs | Minimum | Fuel Oil
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	700,000.0		700,000.0
Environmental restoration costs | Minimum | Majority of the environmental remediation
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	141,200,000		141,200,000
Environmental restoration costs | Maximum
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	257,100,000		257,100,000
Environmental restoration costs | Maximum | Fuel Oil
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	1,300,000.0		1,300,000.0
Environmental restoration costs | Maximum | Majority of the environmental remediation
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	246,700,000		246,700,000
Parental guarantee
Commitment and Contingencies [Line Items]
Guaranteed amount	$ 6,000,000		$ 6,000,000
Contract term	2 years
Pricing dispute, long-term gas supply contract
Commitment and Contingencies [Line Items]
Number of long-term gas supply contracts | contract	2		2
South Jersey Resources Group, LLC
Commitment and Contingencies [Line Items]
Amount of monthly fees paid to supplier	$ 500,000
South Jersey Resources Group, LLC | Pending litigation | Pricing dispute, long-term gas supply contract
Commitment and Contingencies [Line Items]
Damages sought	40,200,000
South Jersey Resources Group, LLC | Pending litigation | Dispute, long-term management contract
Commitment and Contingencies [Line Items]
Damages sought	13,300,000
South Jersey Gas Company
Commitment and Contingencies [Line Items]
Amount of monthly fees paid to supplier	5,600,000
Letter of credit provided	210,000,000		$ 210,000,000
South Jersey Gas Company | Letters of credit
Commitment and Contingencies [Line Items]
Letters of credit outstanding	800,000		$ 800,000
South Jersey Gas Company | Pending litigation | Pricing dispute, long-term gas supply contract
Commitment and Contingencies [Line Items]
Damages sought	$ 14,900,000

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DERIVATIVE INSTRUMENTS (Details) MWh in Millions	12 Months Ended
	Dec. 31, 2016 USD ($) MWh	Dec. 31, 2016 USD ($) MMcfe
Marina Energy LLC | Interest Rate Swap, 14,500,000
Derivative [Line Items]
Notional Amount	$ 14,500,000	$ 14,500,000
Fixed Interest Rate	3.905%	3.905%
Marina Energy LLC | Interest Rate Swap, 500,000
Derivative [Line Items]
Notional Amount	$ 500,000	$ 500,000
Fixed Interest Rate	3.905%	3.905%
Marina Energy LLC | Interest Rate Swap, 330,000
Derivative [Line Items]
Notional Amount	$ 330,000	$ 330,000
Fixed Interest Rate	3.905%	3.905%
South Jersey Gas Company | Interest Rate Swap, 12,500,000, Contract 1
Derivative [Line Items]
Notional Amount	$ 12,500,000	$ 12,500,000
Fixed Interest Rate	3.53%	3.53%
South Jersey Gas Company | Interest Rate Swap, 12,500,000, Contract 2
Derivative [Line Items]
Notional Amount	$ 12,500,000	$ 12,500,000
Fixed Interest Rate	3.43%	3.43%
Basis and index related purchase and sales contracts
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh) | MMcfe		141,600
Expected future purchases
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh)	2.3	67,900
Expected future sales
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh)	1.7	62,100

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DERIVATIVE INSTRUMENTS - FAIR VALUES OF ALL DERIVATIVE INSTRUMENTS (Details) - Derivatives not designated as hedging instruments under GAAP - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Assets	$ 80,893	$ 99,331
Liabilities	74,652	123,348
Commodity contract | Derivatives – Energy Related – Current
Derivatives, Fair Value [Line Items]
Assets	72,391	83,093
Liabilities	60,082	90,708
Commodity contract | Derivatives – Energy Related – Non-Current
Derivatives, Fair Value [Line Items]
Assets	8,502	16,238
Liabilities	4,540	21,697
Interest rate contract | Derivatives - Other - Current
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	681	0
Interest rate contract | Derivatives - Other - Non-Current
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	$ 9,349	$ 10,943

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DERIVATIVE INSTRUMENTS - OFFSETTING ARRANGEMENTS (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Commodity contract
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	$ 80,893	$ 99,331
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	80,893	99,331
Gross amounts not offset in the balance sheet, Financial Instruments	(38,809)	(35,491)
Gross amounts not offset in the balance sheet, Cash Collateral Posted	(3,474)	0
Net amount	38,610	63,840
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(64,622)	(112,405)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(64,622)	(112,405)
Gross amounts not offset in the balance sheet, Financial Instruments	38,809	35,491
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	23,045
Net amount	(25,813)	(53,869)
Interest rate contract
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(10,030)	(10,943)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(10,030)	(10,943)
Gross amounts not offset in the balance sheet, Financial Instruments	0	0
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	0
Net amount	$ (10,030)	$ (10,943)

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DERIVATIVE INSTRUMENTS - EFFECTS OF DERIVATIVE INSTRUMENTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Interest Rate Contracts [Abstract]
Losses recognized in AOCL on effective portion	$ 0	$ 0	$ 0
Losses reclassified from AOCL into income	(333)	(551)	(419)
Losses recognized in income on ineffective portion	0	0	0
Gains (losses) on energy-related commodity contracts	26,935	8,401	(6,592)
Gains (losses) on interest rate contracts	647	96	(467)
Total	27,582	8,497	(7,059)
Net realized gains (losses) on commodity contracts	(3,000)	$ (9,100)	$ 1,700
Fair value derivative instruments with credit-risk-related features	9,600
Additional collateral, aggregate fair value	$ 8,100

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016 USD ($) $ / decatherm	Dec. 31, 2015 USD ($) $ / decatherm
Liabilities
Net derivative assets (liabilities) transferred	$ 4,100	$ 7,400
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period	(632)	(5,608)
Other changes in fair value from continuing and new contracts, net	5,657	(5,069)
Transfers in to/(out of) of Level 3	4,116	7,402
Settlements	(106)	2,643
Balance at end of period	$ 9,035	$ (632)
Level 3 | Forward Contract | Minimum
Liabilities
Forward price (in USD per dt) | $ / decatherm	1.03	(0.77)
Level 3 | Forward Contract | Maximum
Liabilities
Forward price (in USD per dt) | $ / decatherm	11.33	10.00
Level 3 | Forward Contract | Weighted Average
Liabilities
Forward price (in USD per dt) | $ / decatherm	2.71	2.15
Level 3 | Forward Contract | Natural Gas
Liabilities
Assets	$ 23,301	$ 29,459
Liabilities	18,109	31,733
Level 3 | Forward Contract | Electric
Liabilities
Assets	11,784	29,136
Liabilities	$ 7,941	$ 27,494
Level 3 | Forward Contract | Electric | Minimum | On-peak
Liabilities
Fixed electric load profile	21.43%	8.47%
Level 3 | Forward Contract | Electric | Minimum | Off-peak
Liabilities
Fixed electric load profile	0.00%	0.00%
Level 3 | Forward Contract | Electric | Maximum | On-peak
Liabilities
Fixed electric load profile	100.00%	100.00%
Level 3 | Forward Contract | Electric | Maximum | Off-peak
Liabilities
Fixed electric load profile	78.57%	91.53%
Level 3 | Forward Contract | Electric | Weighted Average | On-peak
Liabilities
Fixed electric load profile	55.14%	56.20%
Level 3 | Forward Contract | Electric | Weighted Average | Off-peak
Liabilities
Fixed electric load profile	44.86%	43.80%
Measurement at fair value on recurring basis
Assets
Available-for-Sale Securities	$ 32	$ 14,810
Derivatives - Energy Related Assets	80,893	99,331
Assets	80,925	114,141
Liabilities
Derivatives - Energy Related Liabilities	64,622	112,405
Derivatives - Other	10,030	10,943
Liabilities	74,652	123,348
Measurement at fair value on recurring basis | Level 1
Assets
Available-for-Sale Securities	32	2,925
Derivatives - Energy Related Assets	33,994	16,006
Assets	34,026	18,931
Liabilities
Derivatives - Energy Related Liabilities	16,502	42,170
Derivatives - Other	0	0
Liabilities	16,502	42,170
Measurement at fair value on recurring basis | Level 2
Assets
Available-for-Sale Securities	0	11,885
Derivatives - Energy Related Assets	11,814	24,730
Assets	11,814	36,615
Liabilities
Derivatives - Energy Related Liabilities	22,070	11,008
Derivatives - Other	10,030	10,943
Liabilities	32,100	21,951
Measurement at fair value on recurring basis | Level 3
Assets
Available-for-Sale Securities	0	0
Derivatives - Energy Related Assets	35,085	58,595
Assets	35,085	58,595
Liabilities
Derivatives - Energy Related Liabilities	26,050	59,227
Derivatives - Other	0	0
Liabilities	$ 26,050	$ 59,227

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ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		$ 1,037,539	$ 932,432	$ 827,000
Other comprehensive income before reclassifications		(5,294)
Amounts reclassified from AOCL		2,412
Other Comprehensive (Loss) Income - Net of Tax	[1],[2]	(2,882)	5,759	(9,498)
Balance		$ 1,289,240	1,037,539	$ 932,432
Combined average statutory tax rate		40.00%
Postretirement Liability Adjustment
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		$ (22,145)
Other comprehensive income before reclassifications		(5,617)
Amounts reclassified from AOCL		2,420
Other Comprehensive (Loss) Income - Net of Tax		(3,197)
Balance		(25,342)	(22,145)
Unrealized Gain (Loss) on Derivatives-Other
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(2,129)
Other comprehensive income before reclassifications		0
Amounts reclassified from AOCL		197
Other Comprehensive (Loss) Income - Net of Tax		197
Balance		(1,932)	(2,129)
Unrealized Gain (Loss) on Available- for-Sale Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(128)
Other comprehensive income before reclassifications		323
Amounts reclassified from AOCL		(205)
Other Comprehensive (Loss) Income - Net of Tax		118
Balance		(10)	(128)
Other Comprehensive Income (Loss) of Affiliated Companies
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(97)
Other comprehensive income before reclassifications		0
Amounts reclassified from AOCL		0
Other Comprehensive (Loss) Income - Net of Tax		0
Balance		(97)	(97)
Accumulated Other Comprehensive Loss
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(24,499)
Balance		$ (27,381)	$ (24,499)

[1] Determined using a combined average statutory tax rate of 40%.

[2] Determined using a combined average statutory tax rate of 40%.

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ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) - RECLASSIFICATIONS OUT OF AOCL (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Operations									$ 151,957	$ 148,672	$ 140,260
Income Taxes	$ 19,266	$ 2,807	$ (7,189)	$ 39,267	$ (1,006)	$ (10,968)	$ (3,279)	$ 16,613	54,151	1,360	4,449
Net Income									(118,810)	(105,107)	(97,046)
Income from Continuing Operations	$ (46,008)	$ (9,664)	$ 4,798	$ (68,187)	$ (50,948)	$ 12,532	$ (13,341)	$ (53,853)	(119,061)	$ (105,610)	$ (97,628)
Losses from reclassifications for the period net of tax									$ 2,412
Combined average statutory tax rate									40.00%
Unrealized Gain (Loss) on Available- for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Losses from reclassifications for the period net of tax									$ (205)
Amounts Reclassified from AOCL | Actuarial Loss on Postretirement Benefits
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Operations									4,001
Income Taxes									(1,581)
Income from Continuing Operations									2,420
Amounts Reclassified from AOCL | Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Income Taxes									(136)
Net Income									197
Amounts Reclassified from AOCL | Unrealized Gain (Loss) on Available- for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Other Income									(342)
Income Taxes									137
Net Income									(205)
Amounts Reclassified from AOCL | Interest rate contract | Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges									$ 333

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SUBSEQUENT EVENTS (Details)	1 Months Ended
	Jan. 31, 2017 USD ($) bank	Dec. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)	Dec. 31, 2015 USD ($)
Subsequent Event [Line Items]
Amount of facility		$ 660,000,000	$ 50,000,000
South Jersey Gas Company
Subsequent Event [Line Items]
Amount of facility		210,000,000
South Jersey Gas Company | Loans payable | Term facility
Subsequent Event [Line Items]
Amount of facility		200,000,000
Line of credit balance		$ 200,000,000		$ 139,000,000
Subsequent event | South Jersey Gas Company | Unsecured term loan
Subsequent Event [Line Items]
Line of credit balance	$ 73,000,000
Subsequent event | South Jersey Gas Company | Credit Agreement | Unsecured term loan
Subsequent Event [Line Items]
Amount of facility	$ 200,000,000.0
Credit agreement syndicated among number of banks | bank	7
Subsequent event | South Jersey Gas Company | Medium-term notes | Series E, 2017, due January 2047
Subsequent Event [Line Items]
Private placement	$ 200,000,000.0
Stated interest rate	3.00%
Subsequent event | South Jersey Gas Company | Loans payable | Term facility
Subsequent Event [Line Items]
Repayments of multiple-draw term facility	$ 200,000,000

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Quarterly Financial Data (Unaudited) (Details) $ / shares in Units, shares in Thousands, $ in Thousands			3 Months Ended								12 Months Ended
	May 08, 2015	Feb. 26, 2015	Dec. 31, 2016 USD ($) $ / shares shares	Sep. 30, 2016 USD ($) $ / shares shares	Jun. 30, 2016 USD ($) $ / shares shares	Mar. 31, 2016 USD ($) $ / shares shares	Dec. 31, 2015 USD ($) $ / shares shares	Sep. 30, 2015 USD ($) $ / shares shares	Jun. 30, 2015 USD ($) $ / shares shares	Mar. 31, 2015 USD ($) $ / shares shares	Dec. 31, 2016 USD ($) $ / shares shares	Dec. 31, 2015 USD ($) $ / shares shares	Dec. 31, 2014 USD ($) $ / shares shares
Quarterly Financial Information Disclosure [Abstract]
Operating Revenues			$ 329,981	$ 219,082	$ 154,402	$ 333,035	$ 257,844	$ 141,062	$ 177,710	$ 382,952	$ 1,036,500	$ 959,568	$ 886,996
Expenses:
Cost of Sales - (Excluding depreciation)			186,684	142,988	98,340	152,975	127,566	99,124	90,945	241,707
Operations and Maintenance Including Fixed Charges			77,858	69,410	71,034	73,042	71,148	63,867	62,634	71,279
Income Taxes			19,266	2,807	(7,189)	39,267	(1,006)	(10,968)	(3,279)	16,613	54,151	1,360	4,449
Energy and Other Taxes			1,725	1,449	1,243	1,925	1,334	1,231	1,265	2,196	6,342	6,026	5,720
Total Expenses			285,533	216,654	163,428	267,209	199,042	153,254	151,565	331,795
Other Income and Expense			1,560	7,236	4,228	2,361	(7,854)	(340)	(12,804)	2,696
Income from Continuing Operations			46,008	9,664	(4,798)	68,187	50,948	(12,532)	13,341	53,853	119,061	105,610	97,628
Loss from Discontinued Operations - (Net of tax benefit)			(75)	(29)	(29)	(118)	(62)	(91)	(74)	(276)	$ (251)	$ (503)	$ (582)
Net Income (Loss)			$ 45,933	$ 9,635	$ (4,827)	$ 68,069	$ 50,886	$ (12,623)	$ 13,267	$ 53,577
Basic Earnings Per Common Share:
Continuing Operations (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.96	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.54	$ 1.47
Discontinued Operations (in USD per share) | $ / shares			0.00	0.00	0.00	0.00	0.00	0.00	0.00	0.00	0.00	0.01	0.01
Basic Earnings per Common Share (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.96	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.53	$ 1.46
Average Shares of Common Stock Outstanding - Basic (in shares) | shares			79,478	79,478	75,298	71,127	69,460	68,607	68,467	68,397	76,362	68,735	66,278
Diluted Earnings Per Common Share:
Continuing Operations (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.95	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.53	$ 1.47
Discontinued Operations (in USD per share) | $ / shares			0.00	0.00	0.00	0.00	0.00	0.00	0.00	0.00	0.00	0.01	0.01
Diluted Earnings per Common Share (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.95	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.52	$ 1.46
Average Shares of Common Stock Outstanding - Diluted (in shares) | shares			79,643	79,635	75,298	71,416	69,646	68,607	68,653	68,618	76,475	68,931	66,428
Stock split, conversion ratio	2	2

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Schedule I (Details) - USD ($)		1 Months Ended	3 Months Ended								12 Months Ended
		May 31, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Feb. 26, 2015	Feb. 25, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Expenses:
Operations											$ 151,957,000	$ 148,672,000	$ 140,260,000
Depreciation											90,389,000	72,451,000	63,004,000
Energy and Other Taxes			$ 1,725,000	$ 1,449,000	$ 1,243,000	$ 1,925,000	$ 1,334,000	$ 1,231,000	$ 1,265,000	$ 2,196,000	6,342,000	6,026,000	5,720,000
Operating Income											189,276,000	156,894,000	127,603,000
Other Income:
Equity in Earnings of Subsidiaries											5,396,000	(27,812,000)	(7,785,000)
Total Other Income											9,989,000	9,510,000	11,819,000
Interest Charges											31,449,000	31,622,000	29,560,000
Income Taxes			19,266,000	2,807,000	(7,189,000)	39,267,000	(1,006,000)	(10,968,000)	(3,279,000)	16,613,000	54,151,000	1,360,000	4,449,000
Income from Continuing Operations			46,008,000	9,664,000	(4,798,000)	68,187,000	50,948,000	(12,532,000)	13,341,000	53,853,000	119,061,000	105,610,000	97,628,000
Equity in Undistributed Earnings of Discontinued Operations			(75,000)	$ (29,000)	$ (29,000)	(118,000)	(62,000)	$ (91,000)	$ (74,000)	(276,000)	(251,000)	(503,000)	(582,000)
Net Income											118,810,000	105,107,000	97,046,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net Income											118,810,000	105,107,000	97,046,000
Other Comprehensive (Loss) Income - Net of Tax
Postretirement Liability Adjustment											(3,197,000)	5,518,000	(9,160,000)
Other Comprehensive (Loss) Income - Net of Tax	[1],[2]										$ (2,882,000)	5,759,000	(9,498,000)
Combined average statutory tax rate											40.00%
Retained Earnings [Roll Forward]
Retained Earnings - Beginning						474,167,000					$ 474,167,000
Net Income											118,810,000	105,107,000	97,046,000
Dividends Declared - Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Retained Earnings - Ending			510,597,000				474,167,000				510,597,000	474,167,000
Statement of Cash Flows [Abstract]
CASH PROVIDED BY OPERATING ACTIVITIES											262,240,000	186,794,000	161,332,000
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital Expenditures											(278,002,000)	(345,621,000)	(342,578,000)
Proceeds from Sale of Property, Plant & Equipment											0	0	53,000
Purchase of Company-Owned Life Insurance											(2,398,000)	(2,328,000)	(1,250,000)
Net Cash Used in Investing Activities											(245,168,000)	(370,652,000)	(375,019,000)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt											61,000,000	130,000,000	329,000,000
Principal Repayments of Long Term Debt											(49,366,000)	(125,009,000)	(21,000,000)
Payments for Issuance of Long Term Debt											(147,000)	(64,000)	(2,184,000)
Net (Repayments of) Borrowings from Short-Term Credit Facilities											(135,600,000)	186,000,000	(108,200,000)
Dividends on Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Proceeds from Sale of Common Stock		$ 203,600,000									214,426,000	63,192,000	80,680,000
Net Cash (Used in) Provided by Financing Activities											(2,667,000)	183,564,000	214,040,000
Net Increase (Decrease) in Cash and Cash Equivalents											14,405,000	(294,000)	353,000
Cash and Cash Equivalents at Beginning of Year						3,877,000				4,171,000	3,877,000	4,171,000	3,818,000
Cash and Cash Equivalents at End of Year			18,282,000				3,877,000				18,282,000	3,877,000	4,171,000
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost														$ 821,942,000	$ 785,646,000
Accumulated Depreciation														(151,084,000)	(108,307,000)
Property, Plant and Equipment - Net														2,623,770,000	2,448,105,000
Investments:
Available-for-Sale Securities														32,000	14,810,000
Total Investments														42,566,000	80,551,000
Current Assets:
Cash and Cash Equivalents			18,282,000			3,877,000	3,877,000			4,171,000	3,877,000	4,171,000	3,818,000	18,282,000	3,877,000			$ 4,171,000	$ 3,818,000
Other														31,369,000	40,167,000
Total Current Assets														473,313,000	431,274,000
Other Noncurrent Assets (See Note 1)														83,429,000	64,575,000
Total Assets														3,730,567,000	3,471,933,000
Equity:
Common Stock SJI, Par Value $1.25, Authorized 120,000,000 shares, Outstanding - 79,478,055 (2016) shares and 70,965,622 (2015)														99,347,000	88,707,000			$ 85,418,000
Premium on Common Stock														706,943,000	499,460,000
Treasury Stock (at par)														(266,000)	(296,000)
Accumulated Other Comprehensive Loss														(27,381,000)	(24,499,000)
Retained Earnings			510,597,000			474,167,000	474,167,000				474,167,000	474,167,000		510,597,000	474,167,000
Total Equity														1,289,240,000	1,037,539,000
Long-Term Debt (See Note 1)														1,047,482,000	1,035,848,000
Current Liabilities:
Notes Payable - Banks														296,100,000	431,700,000
Current Portion of Long-Term Debt														231,909,000	29,454,000
Accounts Payable														243,669,000	186,400,000
Other Current Liabilities														15,219,000	11,596,000
Total Current Liabilities														952,624,000	832,476,000
Other Noncurrent Liabilities														10,584,000	22,990,000
Total Capitalization and Liabilities														$ 3,730,567,000	$ 3,471,933,000
Common stock, par value (in USD per share)		$ 1.25												$ 1.25	$ 1.25
Common stock, authorized (in shares)														120,000,000	120,000,000	120,000,000	60,000,000
Common Stock, outstanding (in shares)														79,478,055	70,965,622			68,334,860	65,430,084
SOUTH JERSEY INDUSTRIES, INC.
Income Statement [Abstract]
Management Service Fee Revenues											25,463,000	20,990,000	21,118,000
Operating Expenses:
Operations											23,852,000	17,979,000	18,183,000
Depreciation											377,000	406,000	439,000
Energy and Other Taxes											1,033,000	806,000	813,000
Total Operating Expenses											25,262,000	19,191,000	19,435,000
Operating Income											201,000	1,799,000	1,683,000
Other Income:
Equity in Earnings of Subsidiaries											119,061,000	105,610,000	97,628,000
Other											11,953,000	10,145,000	7,283,000
Total Other Income											131,014,000	115,755,000	104,911,000
Interest Charges											12,148,000	11,822,000	8,803,000
Income Taxes											6,000	122,000	163,000
Income from Continuing Operations											119,061,000	105,610,000	97,628,000
Equity in Undistributed Earnings of Discontinued Operations											(251,000)	(503,000)	(582,000)
Net Income											118,810,000	105,107,000	97,046,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net Income											118,810,000	105,107,000	97,046,000
Other Comprehensive (Loss) Income - Net of Tax
Postretirement Liability Adjustment											(3,197,000)	5,518,000	(9,160,000)
Unrealized Gain (Loss) on Available-for-Sale Securities											118,000	(53,000)	(472,000)
Unrealized Gain on Derivatives - Other											197,000	294,000	134,000
Other Comprehensive (Loss) Income - Net of Tax											(2,882,000)	5,759,000	(9,498,000)
Comprehensive Income											$ 115,928,000	$ 110,866,000	$ 87,548,000
Combined average statutory tax rate											40.00%	40.00%	40.00%
Retained Earnings [Roll Forward]
Retained Earnings - Beginning						474,167,000				439,218,000	$ 474,167,000	$ 439,218,000	$ 406,041,000
Net Income											118,810,000	105,107,000	97,046,000
Retained Earnings After Net Income Before Dividends Declared														$ 592,977,000	$ 544,325,000			$ 503,087,000
Dividends Declared - Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Retained Earnings - Ending			510,597,000				474,167,000				510,597,000	474,167,000	439,218,000
Statement of Cash Flows [Abstract]
CASH PROVIDED BY OPERATING ACTIVITIES											20,120,000	38,593,000	22,244,000
CASH FLOWS FROM INVESTING ACTIVITIES:
Net Repayments from (Advances to) Associated Companies											32,300,000	(118,802,000)	(104,979,000)
Capital Expenditures											(345,000)	(150,000)	(1,610,000)
Proceeds from Sale of Property, Plant & Equipment											0	0	27,000
Purchase of Company-Owned Life Insurance											(2,398,000)	(2,328,000)	(1,250,000)
Investment in Affiliate											(65,000,000)	0	(25,000,000)
Net Cash Used in Investing Activities											(35,443,000)	(121,280,000)	(132,812,000)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt											0	50,000,000	240,000,000
Principal Repayments of Long Term Debt											0	(114,000,000)	0
Payments for Issuance of Long Term Debt											(84,000)	(55,000)	(1,558,000)
Net (Repayments of) Borrowings from Short-Term Credit Facilities											(105,500,000)	153,000,000	(144,100,000)
Dividends on Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Proceeds from Sale of Common Stock											214,426,000	63,192,000	80,680,000
Net Cash (Used in) Provided by Financing Activities											26,462,000	81,979,000	111,153,000
Net Increase (Decrease) in Cash and Cash Equivalents											11,139,000	(708,000)	585,000
Cash and Cash Equivalents at Beginning of Year						1,708,000				2,416,000	1,708,000	2,416,000	1,831,000
Cash and Cash Equivalents at End of Year			12,847,000				1,708,000				12,847,000	1,708,000	2,416,000
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost														2,685,000	2,468,000
Accumulated Depreciation														(2,026,000)	(1,768,000)
Property, Plant and Equipment - Net														659,000	700,000
Investments:
Investments in Subsidiaries														1,233,856,000	1,051,675,000
Available-for-Sale Securities														32,000	3,860,000
Total Investments														1,233,888,000	1,055,535,000
Current Assets:
Cash and Cash Equivalents			12,847,000			1,708,000	1,708,000			2,416,000	1,708,000	2,416,000	1,831,000	12,847,000	1,708,000			2,416,000	$ 1,831,000
Receivable from Associated Companies														550,227,000	582,406,000
Accounts Receivable														49,000	49,000
Other														0	2,859,000
Total Current Assets														563,123,000	587,022,000
Other Noncurrent Assets (See Note 1)														44,974,000	38,168,000
Total Assets														1,842,644,000	1,681,425,000
Equity:
Common Stock SJI, Par Value $1.25, Authorized 120,000,000 shares, Outstanding - 79,478,055 (2016) shares and 70,965,622 (2015)														99,347,000	88,707,000
Premium on Common Stock														706,943,000	499,460,000
Treasury Stock (at par)														(266,000)	(296,000)
Accumulated Other Comprehensive Loss														(27,381,000)	(24,499,000)
Retained Earnings			$ 510,597,000			$ 474,167,000	$ 474,167,000			$ 439,218,000	474,167,000	439,218,000	406,041,000	510,597,000	474,167,000			$ 439,218,000	$ 406,041,000
Total Equity														1,289,240,000	1,037,539,000
Long-Term Debt (See Note 1)														323,971,000	339,665,000
Current Liabilities:
Notes Payable - Banks														191,800,000	297,300,000
Current Portion of Long-Term Debt														16,000,000	0
Payable to Associated Companies														382,000	262,000
Accounts Payable														211,000	425,000
Other Current Liabilities														7,707,000	3,579,000
Total Current Liabilities														216,100,000	301,566,000
Other Noncurrent Liabilities														13,333,000	2,655,000
Total Capitalization and Liabilities														$ 1,842,644,000	$ 1,681,425,000
Common stock, par value (in USD per share)														$ 1.25	$ 1.25
Common stock, authorized (in shares)														120,000,000	120,000,000
Common Stock, outstanding (in shares)														79,478,055	70,965,622
Dividends received from subsidiaries											$ 0	$ 40,800,000	$ 18,200,000

[1] Determined using a combined average statutory tax rate of 40%.

[2] Determined using a combined average statutory tax rate of 40%.

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Schedule II - Valuation and Qualifying Accounts (Details) - Provision for Uncollectible Accounts - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 10,252	$ 7,910	$ 5,854
Charged to Costs and Expenses	6,907	14,730	9,519
Charged to Other Accounts	(47)	(79)	(102)
Deductions	4,368	12,309	7,361
Balance at End of Period	$ 12,744	$ 10,252	$ 7,910