South Jersey Industries (SJIIU) 10-Q 5 Aug 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 01, 2016
Document and Entity Information [Abstract]
Entity Registrant Name	SOUTH JERSEY INDUSTRIES INC
Entity Central Index Key	91,928
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		79,477,822

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Operating Revenues:
Utility	$ 68,273	$ 75,294	$ 251,942	$ 341,824
Nonutility	86,129	102,416	235,495	218,838
Total Operating Revenues	154,402	177,710	487,437	560,662
Cost of Sales - (Excluding depreciation)
- Utility	19,508	24,901	84,714	169,875
- Nonutility	78,832	66,044	166,601	162,777
Operations	36,250	33,802	75,047	75,663
Maintenance	4,259	3,928	8,643	7,926
Depreciation	22,296	17,430	42,997	34,249
Energy and Other Taxes	1,243	1,265	3,168	3,461
Total Operating Expenses	162,388	147,370	381,170	453,951
Operating (Loss) Income	(7,986)	30,340	106,267	106,711
Other Income and Expense	4,361	3,040	6,564	5,281
Interest Charges	(8,229)	(7,474)	(17,389)	(16,075)
(Loss) Income Before Income Taxes	(11,854)	25,906	95,442	95,917
Income Taxes	7,189	3,279	(32,078)	(13,334)
Equity in Losses of Affiliated Companies	(133)	(15,844)	25	(15,389)
(Loss) Income from Continuing Operations	(4,798)	13,341	63,389	67,194
Loss from Discontinued Operations - (Net of tax benefit)	(29)	(74)	(147)	(350)
Net (Loss) Income	$ (4,827)	$ 13,267	$ 63,242	$ 66,844
Basic Earnings Per Common Share:
Continuing Operations (in dollars per share)	$ (0.06)	$ 0.19	$ 0.86	$ 0.98
Discontinued Operations (in dollars per share)	0	0	0	0
Basic Earnings Per Common Share (in dollars per share)	$ (0.06)	$ 0.19	$ 0.86	$ 0.98
Average Shares of Common Stock Outstanding - Basic (in shares)	75,298	68,467	73,213	68,432
Diluted Earnings Per Common Share:
Continuing Operations (in dollars per share)	$ (0.06)	$ 0.19	$ 0.86	$ 0.98
Discontinued Operations (in dollars per share)	0	0	0	0
Diluted Earnings Per Common Share (in dollars per share)	$ (0.06)	$ 0.19	$ 0.86	$ 0.98
Average Shares of Common Stock Outstanding - Diluted (in shares)	75,298	68,653	73,506	68,636
Dividends Declared Per Common Share (in dollars per share)	$ 0.26	$ 0.25	$ 0.52	$ 0.5

CONDENSED CONSOLIDATED STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Net (Loss) Income		$ (4,827)	$ 13,267	$ 63,242	$ 66,844
Other Comprehensive Income, Net of Tax:
Unrealized Gain (Loss) on Available-for-Sale Securities	[1]	55	(64)	104	24
Unrealized Gain on Derivatives - Other	[1]	49	111	100	119
Other Comprehensive Income of Affiliated Companies	[1]	0	59	0	(36)
Other Comprehensive Income - Net of Tax	[1]	104	106	204	107
Comprehensive (Loss) Income		$ (4,723)	$ 13,373	$ 63,446	$ 66,951
[1]	Determined using a combined average statutory tax rate of 40%.

CONDENSED CONSOLIDATED STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Combined statutory tax rate	40.00%	40.00%	40.00%	40.00%

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Statement of Cash Flows [Abstract]
Net Cash Provided by Operating Activities	$ 158,099	$ 102,059
Cash Flows from Investing Activities:
Capital Expenditures	(118,843)	(141,585)
Purchase of Available-for-Sale Securities	0	(6,059)
Proceeds from Restricted Investments	1,738	0
Net Proceeds from Sale of Restricted Investments in Margin Account	7,781	12,581
Investment in Long-Term Receivables	(5,702)	(3,381)
Proceeds from Long-Term Receivables	5,195	2,040
Notes Receivable	(74)	(9,887)
Purchase of Company-Owned Life Insurance	(652)	(765)
Investment in Affiliate	(5,820)	(1,766)
Advances on Notes Receivable - Affiliate	0	(1,514)
Net Repayment of Notes Receivable - Affiliate	1,266	4,612
Net Cash Used in Investing Activities	(115,111)	(145,724)
Cash Flows from Financing Activities:
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(286,300)	120,300
Proceeds from Issuance of Long-Term Debt	61,000	0
Principal Repayments of Long-Term Debt	(13,078)	(64,000)
Dividends on Common Stock	(18,790)	(17,192)
Proceeds from Sale of Common Stock	214,463	3,596
Net Cash (Used in) Provided by Financing Activities	(42,705)	42,704
Net Increase (Decrease) in Cash and Cash Equivalents	283	(961)
Cash and Cash Equivalents at Beginning of Period	3,877	4,171
Cash and Cash Equivalents at End of Period	$ 4,160	$ 3,210

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Property, Plant and Equipment:
Utility Plant, at original cost	$ 2,310,223	$ 2,211,239
Accumulated Depreciation	(459,015)	(440,473)
Nonutility Property and Equipment, at cost	792,256	785,646
Accumulated Depreciation	(128,574)	(108,307)
Property, Plant and Equipment - Net	2,514,890	2,448,105
Investments:
Available-for-Sale Securities	15,160	14,810
Restricted	38,177	48,758
Investment in Affiliates	22,168	16,983
Total Investments	75,505	80,551
Current Assets:
Cash and Cash Equivalents	4,160	3,877
Accounts Receivable	175,341	178,359
Unbilled Revenues	29,385	40,044
Provision for Uncollectibles	(10,118)	(10,252)
Notes Receivable	11,843	11,800
Notes Receivable - Affiliate	1,868	3,134
Natural Gas in Storage, average cost	44,499	54,211
Materials and Supplies, average cost	6,815	5,088
Prepaid Taxes	27,922	21,753
Derivatives - Energy Related Assets	45,112	83,093
Other Prepayments and Current Assets	38,930	40,167
Total Current Assets	375,757	431,274
Regulatory and Other Noncurrent Assets:
Regulatory Assets	380,364	323,434
Derivatives - Energy Related Assets	11,929	16,238
Notes Receivable - Affiliate	13,275	13,275
Contract Receivables	28,976	28,609
Notes Receivable	31,187	35,439
Goodwill	8,139	8,880
Identifiable Intangible Assets	16,209	21,553
Other	66,350	64,575
Total Regulatory and Other Noncurrent Assets	556,429	512,003
Total Assets	3,522,581	3,471,933
Equity:
Common Stock	99,347	88,707
Premium on Common Stock	705,106	499,460
Treasury Stock (at par)	(259)	(296)
Accumulated Other Comprehensive Loss	(24,295)	(24,499)
Retained Earnings	497,648	474,167
Total Equity	1,277,547	1,037,539
Long-Term Debt	831,089	997,427
Total Capitalization	2,108,636	2,034,966
Current Liabilities:
Notes Payable	145,400	431,700
Current Portion of Long-Term Debt	244,605	29,454
Accounts Payable	166,418	186,400
Customer Deposits and Credit Balances	23,022	20,146
Environmental Remediation Costs	72,315	50,559
Taxes Accrued	2,832	2,336
Derivatives - Energy Related Liabilities	66,444	90,708
Derivative Liability, Current	945	0
Dividends Payable	20,962	0
Interest Accrued	7,176	7,316
Pension Benefits	2,261	2,261
Other Current Liabilities	6,053	11,596
Total Current Liabilities	758,433	832,476
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	330,046	295,945
Pension and Other Postretirement Benefits	79,821	76,068
Environmental Remediation Costs	83,495	76,064
Asset Retirement Obligations	59,032	57,943
Derivatives - Energy Related Liabilities	8,371	21,697
Derivatives - Other	13,386	10,943
Regulatory Liabilities	60,010	42,841
Other	21,351	22,990
Total Deferred Credits and Other Noncurrent Liabilities	655,512	604,491
Commitments and Contingencies
Total Capitalization and Liabilities	$ 3,522,581	$ 3,471,933

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Jun. 30, 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 following entities are wholly-owned subsidiaries of Marina as of December 31, 2015 (see Note 3): • 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 located 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 was formed in 2014 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. BASIS OF PRESENTATION — The condensed 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 condensed 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. SJI’s businesses are subject to seasonal fluctuations and, accordingly, this interim financial information should not be the basis for estimating the full year’s operating results. As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying unaudited condensed consolidated financial statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These financial statements should be read in conjunction with SJI’s 2015 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information. Certain reclassifications have been made to the prior period's condensed consolidated balance sheets, as well as the prior period's long-term debt carrying value and prior period's segment disclosures in Notes 5 and 6, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the condensed 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 period long-term debt carrying value in Note 5 to be adjusted, along with the prior period unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 6 to be removed. REVENUE-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include the 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 $0.2 million for both the three months ended June 30, 2016 and 2015 , and $0.5 million and $0.8 million for the six months ended June 30, 2016 and 2015 , respectively. IMPAIRMENT OF LONG-LIVED ASSETS - SJI reviews 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 six months ended June 30, 2016 and 2015 , no impairments were identified. 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 six months ended June 30, 2016 or 2015 . As of June 30, 2016 and December 31, 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 condensed consolidated balance sheets. TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of June 30, 2016 and December 31, 2015 , SJI held 207,573 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 Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”. 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, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods. GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects 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. No such events have occurred during the six months ended June 30, 2016 . Goodwill totaled $8.1 million and $8.9 million on the condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015 , respectively. The following table summarizes the changes in Goodwill for the six months ended June 30, 2016 (in thousands): 2016 Beginning Balance, January 1 $ 8,880 Fair Value Adjustments During Measurement Period (See Note 3) (741 ) Ending Balance, June 30 $ 8,139 NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2016 or 2015 had, or are expected to have, a material impact on the condensed 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. The new guidance 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 inventorying the contracts with customers and evaluating the impact that adoption of this guidance will have on the Company's financial statement results, as well as the transition method the Company will elect to adopt the guidance. 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. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption. 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 is 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. 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 March 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 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) . This standard amends ASU 2014-09 (discussed above), to improve the implementation guidance on principal versus agent considerations and whether an entity reports revenue on a gross or net basis. This standard will have the same effective date and transition requirements as ASU 2014-09. 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 April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing . This standard amends ASU 2014-09 (discussed above) to clarify identifying performance obligations and the licensing implementation guidance. This standard will have the same effective date and transition requirements as ASU 2014-09. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients . This standard amends ASU 2014-09 (discussed above) to provide 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 (5) disclosure of the effects of the accounting change in the period of adoption. This standard will have the same effective date and transition requirements as ASU 2014-09. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

STOCK-BASED COMPENSATION PLAN

STOCK-BASED COMPENSATION PLAN	6 Months Ended
	Jun. 30, 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 six months ended June 30, 2016 and 2015 . No stock appreciation rights have been issued under the plans. During the six months ended June 30, 2016 and 2015 , SJI granted 193,184 and 159,416 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 grants time-based shares of restricted stock, one-third of which vest annually over a three -year period and is limited to a 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. During the six months ended June 30, 2016 and 2015 , Officers and other key employees were granted 57,955 and 47,824 shares of time-based restricted stock, 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, earning-based performance targets included pre-defined EGR and return on equity (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. During the six months ended June 30, 2016 and 2015 , SJI granted 35,197 and 25,398 restricted shares, respectively, to Directors. 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 June 30, 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 - 2014 - TSR 50,712 $ 21.31 20.0 % 0.80 % 2014 - EGR 50,712 $ 27.22 N/A N/A 2015 - TSR 33,930 $ 26.31 16.0 % 1.10 % 2015 - EGR, ROE, Time 74,075 $ 29.47 N/A N/A 2016 - TSR 66,397 $ 22.53 18.1 % 1.31 % 2016 - CEGR, Time 123,309 $ 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 three and six months ended June 30, 2016 and 2015 (in thousands): Three Months Ended Six Months Ended 2016 2015 2016 2015 Officers & Key Employees $ 798 $ 511 $ 1,615 $ 1,310 Directors 227 186 420 372 Total Cost 1,025 697 2,035 1,682 Capitalized (106 ) (87 ) (212 ) (178 ) Net Expense $ 919 $ 610 $ 1,823 $ 1,504 As of June 30, 2016 , there was $6.1 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 2.0 years. The following table summarizes information regarding restricted stock award activity during the six months ended June 30, 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 193,184 35,197 $ 23.28 Cancelled/Forfeited (6,993 ) — $ 25.10 Vested (13,247 ) (26,338 ) $ 29.30 Nonvested Shares Outstanding, June 30, 2016 399,135 35,197 $ 24.80 Performance targets during the three -year vesting period 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 during the six months ended June 30, 2016 at a market value of $0.3 million . During the six months ended June 30, 2016 and 2015 , SJI granted 35,197 and 25,398 shares to its Directors at a market value of $0.8 million and $0.7 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 condensed consolidated balance sheets.

AFFILIATIONS AND DISCONTINUED O

AFFILIATIONS AND DISCONTINUED OPERATIONS	6 Months Ended
	Jun. 30, 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 develops and operates 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 condensed consolidated balance sheets, with approximately $1.8 million being included as a current asset as of June 30, 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 condensed consolidated balance sheets and Marina’s share of the loss or earnings from the projects for the six months ended June 30, 2015 was included within Equity in Earnings (Losses) of Affiliated Companies on the condensed consolidated statements of income. As of December 31, 2015, the assets and liabilities of the projects that are now wholly-owned by Marina are consolidated into the condensed 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 condensed consolidated statements of income and cash flows. The results of the acquired projects are included in the On-Site Energy Production segment. The following table summarizes the preliminary 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. The Company is still awaiting final valuation reports supporting the allocation of the purchase price to certain identifiable intangibles. 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 8,139 Non-Current Assets 1,873 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 (572 ) Fair Value of Consolidated Assets and Liabilities of Acquired Projects $ 46,030 The recorded amounts for assets and liabilities represent the Company's best estimate as of June 30, 2016. The measurement period adjustments recorded during the six months ended June 30, 2016 did not have a significant impact on the Company's condensed consolidated balance sheet. 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 2018. During the first six months of 2016 and 2015, the Company made net investments in unconsolidated affiliates of $4.6 million and $1.3 million , respectively. As of June 30, 2016 and December 31, 2015 , the outstanding balance of Notes Receivable – Affiliate was $15.1 million and $16.4 million , respectively. As of June 30, 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 . The remaining $1.5 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 June 30, 2016 , the Company had a net asset of approximately $22.2 million included in Investment in Affiliates on the condensed 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 June 30, 2016 , is limited to its combined equity contributions and the Notes Receivable-Affiliate in the aggregate amount of $37.3 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 three and six months ended June 30, 2016 and 2015 , were (in thousands, except per share amounts): Three Months Ended Six Months Ended 2016 2015 2016 2015 Loss before Income Taxes: Sand Mining $ (18 ) $ (17 ) (164 ) (364 ) Fuel Oil (27 ) (97 ) (62 ) (163 ) Income Tax Benefits 16 40 79 177 Loss from Discontinued Operations — Net $ (29 ) $ (74 ) $ (147 ) $ (350 ) Earnings Per Common Share from Discontinued Operations — Net: Basic and Diluted $ — $ — $ — $ —

COMMON STOCK

COMMON STOCK	6 Months Ended
	Jun. 30, 2016
Common Stock [Abstract]
COMMON STOCK	COMMON STOCK: The following shares were issued and outstanding: 2016 Beginning Balance, January 1 70,965,622 New Issuances During the Period: Dividend Reinvestment Plan 416,862 Stock-Based Compensation Plan 45,338 Public Equity Offering 8,050,000 Ending Balance, June 30 79,477,822 The par value ( $1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $205.6 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 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. 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 186,147 for the three months ended June 30, 2015 and 292,782 and 203,455 for the six months ended June 30, 2016 and 2015 , respectively. For the three months ended June 30, 2016, incremental shares of 297,061 were not included in the denominator for the diluted EPS calculation because they would have an antidilutive effect on EPS. These additional shares relate to SJI's restricted stock as discussed in Note 2. DIVIDEND REINVESTMENT PLAN (DRP) - The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $10.8 million and $3.6 million of equity capital through the DRP during the six months ended June 30, 2016 and 2015 , respectively. SJI does not intend to issue any more new equity capital via the DRP in 2016. Effective May 1, 2016, SJI switched to purchasing shares on the open market to fund share purchases by DRP participants.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	6 Months Ended
	Jun. 30, 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 June 30, 2016 and December 31, 2015 , the escrowed funds, including interest earned, totaled $2.3 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 June 30, 2016 and December 31, 2015 , the balances in these accounts totaled $35.9 million and $43.7 million , respectively. As of December 31, 2015, in accordance with an outstanding loan agreement which ACB had 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); as such, there was no reserve as of June 30, 2016 . The carrying amounts of the Restricted Investments approximate their fair values at June 30, 2016 and December 31, 2015 , which would be included in Level 1 of the fair value hierarchy (see Note 13). 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 during the second quarter of 2015 on the condensed consolidated statements of 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, $2.1 million of which has been received as of June 30, 2016 and included in Other Income on the condensed consolidated statements of income. The remaining $4.9 million is expected to be received and recognized into income prior to the end of the year. As of June 30, 2016 , the Company, through its investment in Energenic, had a remaining net asset of approximately $1.1 million included in Investment in Affiliates on the condensed 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 condensed 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 bears 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. SJG holds a first lien security interest on land in Atlantic City as collateral against this note. The carrying amount of this receivable approximates its fair value at June 30, 2016 and December 31, 2015 , which would be included in Level 2 of the fair value hierarchy (see Note 13). In July 2016, the note was repaid in full (see Note 16). 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 a period of up to five to ten years with no interest. The carrying amounts of such loans were $11.0 million and $12.9 million as of June 30, 2016 and December 31, 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 condensed consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.1 million and $1.3 million as of June 30, 2016 and December 31, 2015 , respectively. The annualized amortization to interest is not material to the Company’s condensed consolidated financial statements. The carrying amounts of these receivables approximate their fair value at June 30, 2016 and December 31, 2015 , which would be included in Level 2 of the fair value hierarchy (see Note 13). CREDIT RISK - As of June 30, 2016 , approximately $6.1 million , or 10.8% , of the current and noncurrent Derivatives – Energy Related Assets are transacted with two counterparties. One counterparty has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of default by the counterparty. The second counterparty is 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 June 30, 2016 and December 31, 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 13). The estimated fair values of SJI's long-term debt, including current maturities, as of June 30, 2016 and December 31, 2015 , were $1,154.2 million and $1,079.0 million , respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of June 30, 2016 and December 31, 2015 , were $1,075.7 million and $1,026.9 million , respectively. The carrying amounts as of June 30, 2016 and December 31, 2015 are net of unamortized debt issuance costs of $8.1 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 June 30, 2016 and December 31, 2015 .

SEGMENTS OF BUSINESS

SEGMENTS OF BUSINESS	6 Months Ended
	Jun. 30, 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. Also included in this segment are the activities of 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’s servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. • 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): Three Months Ended Six Months Ended 2016 2015 2016 2015 Operating Revenues: Gas Utility Operations $ 68,762 $ 75,812 $ 256,528 $ 343,470 Energy Group: Wholesale Energy Operations (1,309 ) 33,276 63,765 68,621 Retail Gas and Other Operations 22,305 18,065 52,038 56,143 Retail Electric Operations 43,065 36,186 82,556 65,963 Subtotal Energy Group 64,061 87,527 198,359 190,727 Energy Services: On-Site Energy Production 23,043 15,136 39,364 28,708 Appliance Service Operations 2,050 2,699 3,938 5,056 Subtotal Energy Services 25,093 17,835 43,302 33,764 Corporate and Services 8,417 7,765 17,293 16,851 Subtotal 166,333 188,939 515,482 584,812 Intersegment Sales (11,931 ) (11,229 ) (28,045 ) (24,150 ) Total Operating Revenues $ 154,402 $ 177,710 $ 487,437 $ 560,662 Three Months Ended Six Months Ended 2016 2015 2016 2015 Operating (Loss) Income: Gas Utility Operations $ 9,931 $ 11,961 $ 85,704 $ 85,150 Energy Group: Wholesale Energy Operations (31,149 ) 15,158 7,095 15,488 Retail Gas and Other Operations 6,250 153 5,491 3,240 Retail Electric Operations 2,277 174 2,862 (8 ) Subtotal Energy Group (22,622 ) 15,485 15,448 18,720 Energy Services: On-Site Energy Production 4,561 2,177 4,472 1,695 Appliance Service Operations 258 247 302 195 Subtotal Energy Services 4,819 2,424 4,774 1,890 Corporate and Services (114 ) 470 341 951 Total Operating (Loss) Income $ (7,986 ) $ 30,340 $ 106,267 $ 106,711 Depreciation and Amortization: Gas Utility Operations $ 15,788 $ 14,239 $ 31,414 $ 28,406 Energy Group: Wholesale Energy Operations 204 15 408 47 Retail Gas and Other Operations 83 20 168 40 Subtotal Energy Group 287 35 576 87 Energy Services: On-Site Energy Production 10,895 7,457 20,814 14,508 Appliance Service Operations 91 73 175 147 Subtotal Energy Services 10,986 7,530 20,989 14,655 Corporate and Services 260 458 483 700 Total Depreciation and Amortization $ 27,321 $ 22,262 $ 53,462 $ 43,848 Interest Charges: Gas Utility Operations $ 4,552 $ 5,113 $ 9,339 $ 10,303 Energy Group: Wholesale Energy Operations 1 (112 ) 65 130 Retail Gas and Other Operations 78 47 210 120 Subtotal Energy Group 79 (65 ) 275 250 Energy Services: On-Site Energy Production 3,442 1,661 6,904 3,976 Corporate and Services 2,858 2,939 6,310 5,927 Subtotal 10,931 9,648 22,828 20,456 Intersegment Borrowings (2,702 ) (2,174 ) (5,439 ) (4,381 ) Total Interest Charges $ 8,229 $ 7,474 $ 17,389 $ 16,075 Three Months Ended Six Months Ended 2016 2015 2016 2015 Income Taxes: Gas Utility Operations $ 1,415 $ 3,292 $ 28,819 $ 29,464 Energy Group: Wholesale Energy Operations (12,258 ) 5,986 2,479 6,853 Retail Gas and Other Operations 2,450 92 2,282 1,668 Retail Electric Operations 931 71 1,170 (3 ) Subtotal Energy Group (8,877 ) 6,149 5,931 8,518 Energy Services: On-Site Energy Production 110 (12,861 ) (2,902 ) (24,908 ) Appliance Service Operations 126 105 152 97 Subtotal Energy Services 236 (12,756 ) (2,750 ) (24,811 ) Corporate and Services 37 36 78 163 Total Income Taxes $ (7,189 ) $ (3,279 ) $ 32,078 $ 13,334 Property Additions: Gas Utility Operations $ 50,133 $ 62,175 $ 101,503 $ 105,501 Energy Group: Wholesale Energy Operations 1 375 7 379 Retail Gas and Other Operations 354 392 725 1,121 Subtotal Energy Group 355 767 732 1,500 Energy Services: On-Site Energy Production 2,665 26,040 5,316 30,421 Appliance Service Operations 251 212 352 328 Subtotal Energy Services 2,916 26,252 5,668 30,749 Corporate and Services 564 537 727 1,601 Total Property Additions $ 53,968 $ 89,731 $ 108,630 $ 139,351 June 30, 2016 December 31, 2015 Identifiable Assets (See Note 1): Gas Utility Operations $ 2,410,522 $ 2,281,576 Energy Group: Wholesale Energy Operations 179,809 231,660 Retail Gas and Other Operations 40,581 55,111 Retail Electric Operations 44,958 55,528 Subtotal Energy Group 265,348 342,299 Energy Services: On-Site Energy Production 776,907 790,231 Appliance Service Operations 3,492 4,885 Subtotal Energy Services 780,399 795,116 Discontinued Operations 1,776 1,545 Corporate and Services 633,685 652,325 Intersegment Assets (569,149 ) (600,928 ) Total Identifiable Assets $ 3,522,581 $ 3,471,933

RATES AND REGULATORY ACTIONS

RATES AND REGULATORY ACTIONS	6 Months Ended
	Jun. 30, 2016
Public Utilities, General Disclosures [Abstract]
RATES AND REGULATORY ACTIONS	RATES AND REGULATORY ACTIONS: SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). In January 2016, SJG provided a Basic Gas Supply Service (BGSS) bill credit of approximately $20.0 million to its residential and small commercial customers. This credit is in addition to an overall rate reduction of 10.3% that was approved by the BPU and took effect in October 2015. SJG’s ability to offer the BGSS bill credit is a direct result of lower wholesale natural gas prices and the overall management of its gas supply portfolio. The BGSS clause serves as a method to pass along increases or decreases in gas costs to customers; therefore, SJG’s income is not affected by BGSS rate adjustments or bill credits. In February 2016, SJG filed a petition with the BPU for approval to continue its Accelerated Infrastructure Replacement Program (AIRP), which will expire at the end of 2016. In its petition, SJG has requested approval to continue its AIRP for an additional seven years, with program investments totaling approximately $500.0 million , to retire and replace bare steel and cast iron mains, bare steel services, and other aging infrastructure. The petition proposes to recover the costs of, and a return on, future AIRP investments through annual base rate adjustments. The petition also includes a request to reflect in base rates approximately $76.0 million of AIRP investments that will have been made since the conclusion of SJG’s last base rate case in October 2014 through the end 2016. This petition is currently pending. In February 2016, the BPU approved a $7.9 million revenue decrease to SJG’s Energy Efficiency Tracker (EET), which recovers the cost of, and an allowed return on, investments in Energy Efficiency Programs (EEP). SJG’s original EEPs and its first EEP Extension, approved by the BPU in 2009 and 2013, respectively, ended in July 2013 and August 2015, respectively. The revenue requirements associated with these prior investments decrease over time as they are amortized and recovered. SJG is continuing to make energy efficiency investments under its most recent EEP Extension, which was approved by the BPU in August 2015, and is recovering the costs, and the allowed return on, those investments through the EET. In April 2016, the BPU approved a $2.6 million net decrease, including taxes, in annual revenues collected from SJG customers through the Societal Benefits Clause (SBC) charge and the Transportation Initiation Clause (TIC) charge, comprised of a $5.2 million increase in revenues from the Remediation Adjustment Clause (RAC) component of the SBC, a $7.1 million decrease in revenues from the Clean Energy Program (CLEP) component of the SBC, and a $0.7 million decrease in TIC revenues, effective May 7, 2016. The increase in the RAC is driven by an increase in costs associated with the remediation of former Manufactured Gas Plants. The decrease in the CLEP component of the SBC is primarily driven by the accumulation of prior year over-recoveries. The decrease in the TIC is driven by a decrease in costs. The SBC and TIC allow SJG to recover costs associated with certain State-mandated programs. SJG does not earn any profit from these charges. Also in April 2016, SJG filed a petition requesting to increase annual revenues from base rates by $4.4 million , including taxes, to reflect the roll-in of investments made through June 2016 under its Storm Hardening and Reliability Program (“SHARP”), with rates to become effective on October 1, 2016. This petition is currently pending. In June 2016, SJG filed its annual BGSS and Conservation Incentive Program (CIP) rate adjustment petition, requesting a $0.6 million net decrease in annual revenues to be implemented on October 1, 2016, comprised of a $47.1 million decrease in BGSS revenues and a $46.5 million increase in CIP revenues, both including taxes. The level of BGSS revenues requested in annual BGSS filings is based on forecasted gas costs and customer usage information for the upcoming BGSS/CIP year, which runs from October to September. SJG’s request for a decrease of BGSS revenues is caused primarily by decreases in forecasted gas commodity costs for the upcoming BGSS/CIP year of October 2016 to September 2017. The level of CIP revenues requested in annual CIP filings is based on historical customer usage information, comparing prior CIP year customer usage to normal customer usage. SJG’s request for an increase in CIP revenues is caused primarily by lower than normal customer usage caused by weather that was 16.4% warmer than normal during the 2015-2016 winter. This petition is currently pending. Also in 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 energy efficiency programs (EEPs). The EET rate recovers the forecasted revenue requirements for the upcoming EET year of October 2016 to September 2017. The requested revenue decrease is the result of the investments associated with SJG's original EEPs, approved by the BPU in 2009, and its EEP extension, approved by the BPU in 2013, which ended in July 2013 and August 2015, respectively. The revenue requirements associated with these prior investments decreases over time as they are amortized. This petition is currently pending. There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2015 . See Note 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K for the year ended December 31, 2015 .

REGULATORY ASSETS AND REGULATOR

REGULATORY ASSETS AND REGULATORY LIABILITIES	6 Months Ended
	Jun. 30, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
REGULATORY ASSETS AND REGULATORY LIABILITIES	REGULATORY ASSETS AND REGULATORY LIABILITIES: There have been no significant changes to the nature of the Company’s regulatory assets and liabilities since December 31, 2015 , which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015 . Regulatory Assets consisted of the following items (in thousands): June 30, 2016 December 31, 2015 Environmental Remediation Costs: Expended - Net $ 50,650 $ 42,032 Liability for Future Expenditures 152,349 123,194 Deferred Asset Retirement Obligation Costs 42,912 42,430 Deferred Pension and Other Postretirement Benefit Costs 79,779 79,779 Deferred Gas Costs - Net — 2,701 Conservation Incentive Program Receivable 21,766 2,624 Deferred Interest Rate Contracts 10,363 7,631 Energy Efficiency Tracker — 496 Pipeline Supplier Service Charges 2,943 3,776 Pipeline Integrity Cost 4,447 4,596 AFUDC - Equity Related Deferrals 11,938 11,423 Other Regulatory Assets 3,217 2,752 Total Regulatory Assets $ 380,364 $ 323,434 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 Remediation Adjustment Clause (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 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 the first six months of 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 GAS COSTS - NET - See discussion under "Deferred Revenues - Net" below. CONSERVATION INCENTIVE PROGRAM (CIP) RECEIVABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. Actual usage per customer was less than the established baseline during the 2015 - 2016 winter season and, more notably, during the first six months of 2016, resulting in an increase in the receivable. This is primarily the result of warm weather experienced in the region. Regulatory Liabilities consisted of the following items (in thousands): June 30, 2016 December 31, 2015 Excess Plant Removal Costs $ 31,078 $ 32,644 Deferred Revenues - Net 18,631 — Societal Benefit Costs 8,233 10,197 Energy Efficiency Tracker 2,068 — Total Regulatory Liabilities $ 60,010 $ 42,841 DEFERRED REVENUES - NET - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net under collected gas costs are classified as a regulatory asset and net over collected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The BGSS changed from a $2.7 million regulatory asset at December 31, 2015 to a $18.6 million regulatory liability at June 30, 2016 primarily due to the gas costs recovered from customers exceeding the actual cost of the commodity. ENERGY EFFICIENCY TRACKER (EET) - This regulatory liability primarily represents energy efficiency measures installed in customer homes and businesses. The change from a $0.5 million regulatory asset at December 31, 2015 to a $2.1 million regulatory liability at June 30, 2016 is due to recoveries being greater than the cost of, and allowed return on, investments in the Energy Efficiency Programs. In February 2016, the BPU approved a $7.9 million revenue decrease to SJG’s EET (see Note 7).

PENSION AND OTHER POSTRETIREMEN

PENSION AND OTHER POSTRETIREMENT BENEFITS	6 Months Ended
	Jun. 30, 2016
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
PENSION AND OTHER POSTRETIREMENT BENEFITS	PENSION AND OTHER POSTRETIREMENT BENEFITS: For the three and six months ended June 30, 2016 and 2015 , 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 Three Months Ended Six Months Ended 2016 2015 2016 2015 Service Cost $ 1,106 $ 1,225 $ 2,421 $ 2,668 Interest Cost 3,062 2,814 6,062 5,584 Expected Return on Plan Assets (3,374 ) (3,695 ) (6,754 ) (7,394 ) Amortizations: Prior Service Cost 53 53 106 106 Actuarial Loss 2,388 2,648 4,697 5,304 Net Periodic Benefit Cost 3,235 3,045 6,532 6,268 Capitalized Benefit Cost (1,213 ) (1,194 ) (2,400 ) (2,433 ) Deferred Benefit Cost (161 ) (325 ) (322 ) (325 ) Total Net Periodic Benefit Expense $ 1,861 $ 1,526 $ 3,810 $ 3,510 Other Postretirement Benefits Three Months Ended Six Months Ended 2016 2015 2016 2015 Service Cost $ 195 $ 231 $ 425 $ 558 Interest Cost 654 715 1,307 1,487 Expected Return on Plan Assets (776 ) (749 ) (1,552 ) (1,497 ) Amortizations: Prior Service Cost (86 ) 152 (172 ) 304 Actuarial Loss 261 287 555 671 Net Periodic Benefit Cost 248 636 563 1,523 Capitalized Benefit Cost (45 ) (271 ) (146 ) (528 ) Deferred Benefit Cost — (79 ) — (79 ) Total Net Periodic Benefit Expense $ 203 $ 286 $ 417 $ 916 Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to SJG's deferral of incremental expense associated with the adoption of new mortality tables effective December 31, 2014 and 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case. SJI contributed $15.0 million to the pension plans in January 2015. No contributions were made to the pension plans during the six months ended June 30, 2016 . SJI does not expect to make any contributions to the pension plans in 2016; however, changes in future investment performance and discount rates may ultimately result in a contribution. Payments related to the unfunded supplemental executive retirement plan (SERP) are expected to approximate $2.3 million in 2016 . SJG also has a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred. See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015 , for additional information related to SJI’s pension and other postretirement benefits.

LINES OF CREDIT

LINES OF CREDIT	6 Months Ended
	Jun. 30, 2016
Line of Credit Facility [Abstract]
LINES OF CREDIT	LINES OF CREDIT: Credit facilities and available liquidity as of June 30, 2016 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 14,100 (A) $ 185,900 May 2018 Uncommitted Bank Line 10,000 — 10,000 August 2016 (C) Total SJG 210,000 14,100 195,900 SJI: Revolving Credit Facility 400,000 134,900 (B) 265,100 February 2018 Total SJI 400,000 134,900 265,100 Total $ 610,000 $ 149,000 $ 461,000 (A) Includes letters of credit outstanding in the amount of $0.8 million . (B) Includes letters of credit outstanding in the amount of $2.8 million . (C) SJG anticipates renewing the Uncommitted Bank Line prior to expiration. 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 1.43% and 0.96% at June 30, 2016 and 2015 , respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2016 and 2015 were $325.5 million and $274.3 million , respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2016 and 2015 were $467.7 million and $368.1 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. SJI and SJG were in compliance with this covenant as of June 30, 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 its $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 .

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES: GUARANTEES — As part of the Transaction involving the Energenic projects (see Note 3), the Company is relieved of any guarantees from prior periods related to the projects in which it no longer has an ownership interest. As of June 30, 2016 , SJI had issued $5.9 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. COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 45% of our workforce at June 30, 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 2017. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017. STANDBY LETTERS OF CREDIT — As of June 30, 2016 , SJI provided $2.8 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 has 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. 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. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.1 million and $ 3.2 million related to all claims in the aggregate as of June 30, 2016 and December 31, 2015 , respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows. 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. Other than the changes discussed in Note 8 to the condensed consolidated financial statements, there have been no changes to the status of the Company’s environmental remediation efforts since December 31, 2015 , as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015 .

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS	6 Months Ended
	Jun. 30, 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 June 30, 2016 , the Company had outstanding derivative contracts intended to limit the exposure to market risk on 64.2 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 71.5 MMdts of expected future sales of natural gas, 2.6 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 2.4 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 148.7 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 condensed 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. 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 had been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the condensed consolidated balance sheets. Hedge accounting has been discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously included in Accumulated Other Comprehensive Loss (AOCL) on the condensed consolidated balance sheets, are being recorded in earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026. As of June 30, 2016 , SJI’s active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type 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 fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015 , are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP June 30, 2016 December 31, 2015 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current $ 45,112 $ 66,444 $ 83,093 $ 90,708 Derivatives – Energy Related – Non-Current 11,929 8,371 16,238 21,697 Interest rate contracts: Derivatives - Other - Current — 945 — — Derivatives - Other - Noncurrent — 13,386 — 10,943 Total derivatives not designated as hedging instruments under GAAP $ 57,041 $ 89,146 $ 99,331 $ 123,348 Total Derivatives $ 57,041 $ 89,146 $ 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 condensed consolidated balance sheets. As of June 30, 2016 and December 31, 2015 , information related to these offsetting arrangements were as follows (in thousands): As of June 30, 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 $ 57,041 $ — $ 57,041 $ (26,263 ) (A) $ — $ 30,778 Derivatives - Energy Related Liabilities $ (74,815 ) $ — $ (74,815 ) $ 26,263 (B) $ 12,854 $ (35,698 ) Derivatives - Other $ (14,331 ) $ — $ (14,331 ) $ — $ — $ (14,331 ) 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 June 30, 2016 and December 31, 2015 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at June 30, 2016 and December 31, 2015 were related to derivative assets which can be net settled against derivative liabilities. The effect of derivative instruments on the condensed consolidated statements of income for the three and six months ended June 30, 2016 and 2015 are as follows (in thousands): Three Months Ended Six Months Ended Derivatives in Cash Flow Hedging Relationships under GAAP 2016 2015 2016 2015 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — $ — Losses reclassified from AOCL into income (a) $ (82 ) $ (187 ) $ (168 ) $ (210 ) Gains (losses) recognized in income on ineffective portion (a) $ — $ — $ — $ — (a) Included in Interest Charges Three Months Ended Six Months Ended Derivatives Not Designated as Hedging Instruments under GAAP 2016 2015 2016 2015 (Losses) gains on energy-related commodity contracts (a) $ (21,371 ) $ 14,685 $ (2,716 ) $ 7,978 (Losses) gains on interest rate contracts (b) (229 ) 541 (656 ) 243 Total $ (21,600 ) $ 15,226 $ (3,372 ) $ 8,221 (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges Net realized loss of $1.6 million and $2.1 million for the three months ended June 30, 2016 and 2015 , respectively, and a net realized loss of $4.4 million and $4.8 million for the six months ended June 30, 2016 and 2015, respectively, associated with SJG's energy-related financial commodity contracts 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 to 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 June 30, 2016 , is $22.1 million . If the credit-risk-related contingent features underlying these agreements were triggered on June 30, 2016 , the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $20.1 million after offsetting asset positions with the same counterparties under master netting arrangements.

FAIR VALUE OF FINANCIAL ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	6 Months Ended
	Jun. 30, 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 June 30, 2016 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 15,160 $ 2,985 $ 12,175 $ — Derivatives – Energy Related Assets (B) 57,041 18,379 7,145 31,517 $ 72,201 $ 21,364 $ 19,320 $ 31,517 Liabilities Derivatives – Energy Related Liabilities (B) $ 74,815 $ 16,589 $ 24,613 $ 33,613 Derivatives – Other (C) 14,331 — 14,331 — $ 89,146 $ 16,589 $ 38,944 $ 33,613 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): Type Fair Value at June 30, 2016 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $15,413 $20,012 Discounted Cash Flow Forward price (per dt) $ 1.56 - $10.34 [$2.37] (A) Forward Contract - Electric $16,104 $13,601 Discounted Cash Flow Fixed electric load profile (on-peak) 21.43% - 100.00% [56.08%] (B) Fixed electric load profile (off-peak) 0.00% - 78.57% [43.92%] (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 for the three and six months ended June 30, 2016 and 2015 , using significant unobservable inputs (Level 3), are as follows (in thousands): Three Months Ended Six Months Ended Balance at beginning of period $ 13,241 $ (632 ) Other changes in fair value from continuing and new contracts, net (12,073 ) (2,058 ) Settlements (3,264 ) 594 Balance at end of period $ (2,096 ) $ (2,096 ) Three Months Ended Six Months Ended Balance at beginning of period $ (17,311 ) $ (5,608 ) Other changes in fair value from continuing and new contracts, net 14,376 (2,062 ) Transfers in/(out) of Level 3 (A) 2,054 2,054 Settlements (1,663 ) 3,072 Balance at end of period $ (2,544 ) $ (2,544 ) (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 three and six months ended June 30, 2015, $2.1 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data. Total losses included in earnings for the three and six months ended June 30, 2016 that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of June 30, 2016 , are $12.1 million and $2.1 million , respectively. These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

LONG-TERM DEBT

LONG-TERM DEBT	6 Months Ended
	Jun. 30, 2016
Long-term Debt, Unclassified [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT: In January 2016, the Company paid $12.7 million to retire outstanding debt for ACB. In January 2016, SJG issued $61.0 million of long-term debt at an average interest rate of 1.37% under a $200.0 million aggregate syndicated bank term facility. The facility is now fully drawn. The total outstanding amount under this facility as of June 30, 2016 is $200.0 million , which was reclassified to current portion of long-term debt on the condensed consolidated balance sheets as it is due within one year. SJG is evaluating alternatives, including refinancing or renewing the facility. As of June 30, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017 were reclassified to current portion of long-term debt on the condensed consolidated balance sheets. At this time, the Company plans to pay off this debt at maturity. The Company did not issue or retire any other long-term debt during the six months ended June 30, 2016 .

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE LOSS	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
ACCUMULATED OTHER COMPREHENSIVE LOSS	ACCUMULATED OTHER COMPREHENSIVE LOSS: The following tables summarize the changes in accumulated other comprehensive loss (AOCL) for the three and six months ended June 30, 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 April 1, 2016 (a) $ (22,145 ) $ (2,078 ) $ (79 ) $ (97 ) $ (24,399 ) Other comprehensive income before reclassifications — — 73 — 73 Amounts reclassified from AOCL (b) — 49 (18 ) — 31 Net current period other comprehensive income (loss) — 49 55 — 104 Balance at June 30, 2016 (a) $ (22,145 ) $ (2,029 ) $ (24 ) $ (97 ) $ (24,295 ) 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 — — 136 — 136 Amounts reclassified from AOCL (b) — 100 (32 ) — 68 Net current period other comprehensive income (loss) — 100 104 — 204 Balance at June 30, 2016 (a) $ (22,145 ) $ (2,029 ) $ (24 ) $ (97 ) $ (24,295 ) (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 three and six months ended June 30, 2016 : Amounts Reclassified from AOCL (in thousands) Affected Line Item in the Condensed Consolidated Statements of Income Three Months Ended Six Months Ended Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 82 $ 168 Interest Charges Income Taxes (33 ) (68 ) Income Taxes (a) $ 49 $ 100 Unrealized Gain on Available-for-Sale Securities $ (33 ) $ (57 ) Other Income Income Taxes 15 25 Income Taxes (a) $ (18 ) $ (32 ) Losses from reclassifications for the period net of tax $ 31 $ 68 (a) Determined using a combined average statutory tax rate of 40% .

SUBSEQUENT EVENT

SUBSEQUENT EVENT	6 Months Ended
	Jun. 30, 2016
Subsequent Events [Abstract]
SUBSEQUENT EVENT	SUBSEQUENT EVENT: In July 2016, the $10.0 million note receivable as of June 30, 2016 from a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey (see Note 5), was repaid in full, including interest.

SUMMARY OF SIGNIFICANT ACCOUN23

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 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 following entities are wholly-owned subsidiaries of Marina as of December 31, 2015 (see Note 3): • 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 located 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 was formed in 2014 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.
BASIS OF PRESENTATION	BASIS OF PRESENTATION — The condensed 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 condensed 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. SJI’s businesses are subject to seasonal fluctuations and, accordingly, this interim financial information should not be the basis for estimating the full year’s operating results. As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying unaudited condensed consolidated financial statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These financial statements should be read in conjunction with SJI’s 2015 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.
RECLASSIFICATIONS	Certain reclassifications have been made to the prior period's condensed consolidated balance sheets, as well as the prior period's long-term debt carrying value and prior period's segment disclosures in Notes 5 and 6, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the condensed 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 period long-term debt carrying value in Note 5 to be adjusted, along with the prior period unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 6 to be removed.
REVENUE-BASED TAXES	REVENUE-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include the 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.
IMPAIRMENT OF LONG-LIVED ASSETS	IMPAIRMENT OF LONG-LIVED ASSETS - SJI reviews the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable.
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 Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”. 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, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods.
GOODWILL	GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects 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. No such events have occurred during the six months ended June 30, 2016 .
NEW ACCOUNTING PRONOUNCEMENTS	NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2016 or 2015 had, or are expected to have, a material impact on the condensed 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. The new guidance 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 inventorying the contracts with customers and evaluating the impact that adoption of this guidance will have on the Company's financial statement results, as well as the transition method the Company will elect to adopt the guidance. 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. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption. 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 is 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. 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 March 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 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) . This standard amends ASU 2014-09 (discussed above), to improve the implementation guidance on principal versus agent considerations and whether an entity reports revenue on a gross or net basis. This standard will have the same effective date and transition requirements as ASU 2014-09. 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 April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing . This standard amends ASU 2014-09 (discussed above) to clarify identifying performance obligations and the licensing implementation guidance. This standard will have the same effective date and transition requirements as ASU 2014-09. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients . This standard amends ASU 2014-09 (discussed above) to provide 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 (5) disclosure of the effects of the accounting change in the period of adoption. This standard will have the same effective date and transition requirements as ASU 2014-09. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
FAIR VALUE OF FINANCIAL ASSETS AND 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. (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.

SUMMARY OF SIGNIFICANT ACCOUN24

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Schedule of Changes in Goodwill	The following table summarizes the changes in Goodwill for the six months ended June 30, 2016 (in thousands): 2016 Beginning Balance, January 1 $ 8,880 Fair Value Adjustments During Measurement Period (See Note 3) (741 ) Ending Balance, June 30 $ 8,139

STOCK-BASED COMPENSATION PLAN (

STOCK-BASED COMPENSATION PLAN (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 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 - 2014 - TSR 50,712 $ 21.31 20.0 % 0.80 % 2014 - EGR 50,712 $ 27.22 N/A N/A 2015 - TSR 33,930 $ 26.31 16.0 % 1.10 % 2015 - EGR, ROE, Time 74,075 $ 29.47 N/A N/A 2016 - TSR 66,397 $ 22.53 18.1 % 1.31 % 2016 - CEGR, Time 123,309 $ 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 three and six months ended June 30, 2016 and 2015 (in thousands): Three Months Ended Six Months Ended 2016 2015 2016 2015 Officers & Key Employees $ 798 $ 511 $ 1,615 $ 1,310 Directors 227 186 420 372 Total Cost 1,025 697 2,035 1,682 Capitalized (106 ) (87 ) (212 ) (178 ) Net Expense $ 919 $ 610 $ 1,823 $ 1,504
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 the six months ended June 30, 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 193,184 35,197 $ 23.28 Cancelled/Forfeited (6,993 ) — $ 25.10 Vested (13,247 ) (26,338 ) $ 29.30 Nonvested Shares Outstanding, June 30, 2016 399,135 35,197 $ 24.80

AFFILIATIONS AND DISCONTINUED26

AFFILIATIONS AND DISCONTINUED OPERATIONS (Tables)	6 Months Ended
	Jun. 30, 2016
Business Combinations [Abstract]
Schedule of the fair value of the assets acquired and the liabilities assumed	The following table summarizes the preliminary 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. The Company is still awaiting final valuation reports supporting the allocation of the purchase price to certain identifiable intangibles. 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 8,139 Non-Current Assets 1,873 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 (572 ) Fair Value of Consolidated Assets and Liabilities of Acquired Projects $ 46,030
Summary of operating results of discontinued operations	Summarized operating results of the discontinued operations for the three and six months ended June 30, 2016 and 2015 , were (in thousands, except per share amounts): Three Months Ended Six Months Ended 2016 2015 2016 2015 Loss before Income Taxes: Sand Mining $ (18 ) $ (17 ) (164 ) (364 ) Fuel Oil (27 ) (97 ) (62 ) (163 ) Income Tax Benefits 16 40 79 177 Loss from Discontinued Operations — Net $ (29 ) $ (74 ) $ (147 ) $ (350 ) Earnings Per Common Share from Discontinued Operations — Net: Basic and Diluted $ — $ — $ — $ —

COMMON STOCK (Tables)

COMMON STOCK (Tables)	6 Months Ended
	Jun. 30, 2016
Common Stock [Abstract]
Common stock shares issued and outstanding	The following shares were issued and outstanding: 2016 Beginning Balance, January 1 70,965,622 New Issuances During the Period: Dividend Reinvestment Plan 416,862 Stock-Based Compensation Plan 45,338 Public Equity Offering 8,050,000 Ending Balance, June 30 79,477,822

SEGMENTS OF BUSINESS (Tables)

SEGMENTS OF BUSINESS (Tables)	6 Months Ended
	Jun. 30, 2016
Segment Reporting [Abstract]
Segments of Business	Information about SJI’s operations in different reportable operating segments is presented below (in thousands): Three Months Ended Six Months Ended 2016 2015 2016 2015 Operating Revenues: Gas Utility Operations $ 68,762 $ 75,812 $ 256,528 $ 343,470 Energy Group: Wholesale Energy Operations (1,309 ) 33,276 63,765 68,621 Retail Gas and Other Operations 22,305 18,065 52,038 56,143 Retail Electric Operations 43,065 36,186 82,556 65,963 Subtotal Energy Group 64,061 87,527 198,359 190,727 Energy Services: On-Site Energy Production 23,043 15,136 39,364 28,708 Appliance Service Operations 2,050 2,699 3,938 5,056 Subtotal Energy Services 25,093 17,835 43,302 33,764 Corporate and Services 8,417 7,765 17,293 16,851 Subtotal 166,333 188,939 515,482 584,812 Intersegment Sales (11,931 ) (11,229 ) (28,045 ) (24,150 ) Total Operating Revenues $ 154,402 $ 177,710 $ 487,437 $ 560,662 Three Months Ended Six Months Ended 2016 2015 2016 2015 Operating (Loss) Income: Gas Utility Operations $ 9,931 $ 11,961 $ 85,704 $ 85,150 Energy Group: Wholesale Energy Operations (31,149 ) 15,158 7,095 15,488 Retail Gas and Other Operations 6,250 153 5,491 3,240 Retail Electric Operations 2,277 174 2,862 (8 ) Subtotal Energy Group (22,622 ) 15,485 15,448 18,720 Energy Services: On-Site Energy Production 4,561 2,177 4,472 1,695 Appliance Service Operations 258 247 302 195 Subtotal Energy Services 4,819 2,424 4,774 1,890 Corporate and Services (114 ) 470 341 951 Total Operating (Loss) Income $ (7,986 ) $ 30,340 $ 106,267 $ 106,711 Depreciation and Amortization: Gas Utility Operations $ 15,788 $ 14,239 $ 31,414 $ 28,406 Energy Group: Wholesale Energy Operations 204 15 408 47 Retail Gas and Other Operations 83 20 168 40 Subtotal Energy Group 287 35 576 87 Energy Services: On-Site Energy Production 10,895 7,457 20,814 14,508 Appliance Service Operations 91 73 175 147 Subtotal Energy Services 10,986 7,530 20,989 14,655 Corporate and Services 260 458 483 700 Total Depreciation and Amortization $ 27,321 $ 22,262 $ 53,462 $ 43,848 Interest Charges: Gas Utility Operations $ 4,552 $ 5,113 $ 9,339 $ 10,303 Energy Group: Wholesale Energy Operations 1 (112 ) 65 130 Retail Gas and Other Operations 78 47 210 120 Subtotal Energy Group 79 (65 ) 275 250 Energy Services: On-Site Energy Production 3,442 1,661 6,904 3,976 Corporate and Services 2,858 2,939 6,310 5,927 Subtotal 10,931 9,648 22,828 20,456 Intersegment Borrowings (2,702 ) (2,174 ) (5,439 ) (4,381 ) Total Interest Charges $ 8,229 $ 7,474 $ 17,389 $ 16,075 Three Months Ended Six Months Ended 2016 2015 2016 2015 Income Taxes: Gas Utility Operations $ 1,415 $ 3,292 $ 28,819 $ 29,464 Energy Group: Wholesale Energy Operations (12,258 ) 5,986 2,479 6,853 Retail Gas and Other Operations 2,450 92 2,282 1,668 Retail Electric Operations 931 71 1,170 (3 ) Subtotal Energy Group (8,877 ) 6,149 5,931 8,518 Energy Services: On-Site Energy Production 110 (12,861 ) (2,902 ) (24,908 ) Appliance Service Operations 126 105 152 97 Subtotal Energy Services 236 (12,756 ) (2,750 ) (24,811 ) Corporate and Services 37 36 78 163 Total Income Taxes $ (7,189 ) $ (3,279 ) $ 32,078 $ 13,334 Property Additions: Gas Utility Operations $ 50,133 $ 62,175 $ 101,503 $ 105,501 Energy Group: Wholesale Energy Operations 1 375 7 379 Retail Gas and Other Operations 354 392 725 1,121 Subtotal Energy Group 355 767 732 1,500 Energy Services: On-Site Energy Production 2,665 26,040 5,316 30,421 Appliance Service Operations 251 212 352 328 Subtotal Energy Services 2,916 26,252 5,668 30,749 Corporate and Services 564 537 727 1,601 Total Property Additions $ 53,968 $ 89,731 $ 108,630 $ 139,351 June 30, 2016 December 31, 2015 Identifiable Assets (See Note 1): Gas Utility Operations $ 2,410,522 $ 2,281,576 Energy Group: Wholesale Energy Operations 179,809 231,660 Retail Gas and Other Operations 40,581 55,111 Retail Electric Operations 44,958 55,528 Subtotal Energy Group 265,348 342,299 Energy Services: On-Site Energy Production 776,907 790,231 Appliance Service Operations 3,492 4,885 Subtotal Energy Services 780,399 795,116 Discontinued Operations 1,776 1,545 Corporate and Services 633,685 652,325 Intersegment Assets (569,149 ) (600,928 ) Total Identifiable Assets $ 3,522,581 $ 3,471,933

REGULATORY ASSETS & REGULATORY

REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	6 Months Ended
	Jun. 30, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory Assets consisted of the following items (in thousands): June 30, 2016 December 31, 2015 Environmental Remediation Costs: Expended - Net $ 50,650 $ 42,032 Liability for Future Expenditures 152,349 123,194 Deferred Asset Retirement Obligation Costs 42,912 42,430 Deferred Pension and Other Postretirement Benefit Costs 79,779 79,779 Deferred Gas Costs - Net — 2,701 Conservation Incentive Program Receivable 21,766 2,624 Deferred Interest Rate Contracts 10,363 7,631 Energy Efficiency Tracker — 496 Pipeline Supplier Service Charges 2,943 3,776 Pipeline Integrity Cost 4,447 4,596 AFUDC - Equity Related Deferrals 11,938 11,423 Other Regulatory Assets 3,217 2,752 Total Regulatory Assets $ 380,364 $ 323,434
Schedule of Regulatory Liabilities	Regulatory Liabilities consisted of the following items (in thousands): June 30, 2016 December 31, 2015 Excess Plant Removal Costs $ 31,078 $ 32,644 Deferred Revenues - Net 18,631 — Societal Benefit Costs 8,233 10,197 Energy Efficiency Tracker 2,068 — Total Regulatory Liabilities $ 60,010 $ 42,841

PENSION AND OTHER POSTRETIREM30

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	6 Months Ended
	Jun. 30, 2016
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
Schedule of defined benefit plans disclosures	For the three and six months ended June 30, 2016 and 2015 , 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 Three Months Ended Six Months Ended 2016 2015 2016 2015 Service Cost $ 1,106 $ 1,225 $ 2,421 $ 2,668 Interest Cost 3,062 2,814 6,062 5,584 Expected Return on Plan Assets (3,374 ) (3,695 ) (6,754 ) (7,394 ) Amortizations: Prior Service Cost 53 53 106 106 Actuarial Loss 2,388 2,648 4,697 5,304 Net Periodic Benefit Cost 3,235 3,045 6,532 6,268 Capitalized Benefit Cost (1,213 ) (1,194 ) (2,400 ) (2,433 ) Deferred Benefit Cost (161 ) (325 ) (322 ) (325 ) Total Net Periodic Benefit Expense $ 1,861 $ 1,526 $ 3,810 $ 3,510 Other Postretirement Benefits Three Months Ended Six Months Ended 2016 2015 2016 2015 Service Cost $ 195 $ 231 $ 425 $ 558 Interest Cost 654 715 1,307 1,487 Expected Return on Plan Assets (776 ) (749 ) (1,552 ) (1,497 ) Amortizations: Prior Service Cost (86 ) 152 (172 ) 304 Actuarial Loss 261 287 555 671 Net Periodic Benefit Cost 248 636 563 1,523 Capitalized Benefit Cost (45 ) (271 ) (146 ) (528 ) Deferred Benefit Cost — (79 ) — (79 ) Total Net Periodic Benefit Expense $ 203 $ 286 $ 417 $ 916

LINES OF CREDIT (Tables)

LINES OF CREDIT (Tables)	6 Months Ended
	Jun. 30, 2016
Line of Credit Facility [Abstract]
Schedule of lines of credit	Credit facilities and available liquidity as of June 30, 2016 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 14,100 (A) $ 185,900 May 2018 Uncommitted Bank Line 10,000 — 10,000 August 2016 (C) Total SJG 210,000 14,100 195,900 SJI: Revolving Credit Facility 400,000 134,900 (B) 265,100 February 2018 Total SJI 400,000 134,900 265,100 Total $ 610,000 $ 149,000 $ 461,000 (A) Includes letters of credit outstanding in the amount of $0.8 million . (B) Includes letters of credit outstanding in the amount of $2.8 million .

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of notional amounts of outstanding derivative positions	As of June 30, 2016 , SJI’s active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type 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 condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015 , are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP June 30, 2016 December 31, 2015 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current $ 45,112 $ 66,444 $ 83,093 $ 90,708 Derivatives – Energy Related – Non-Current 11,929 8,371 16,238 21,697 Interest rate contracts: Derivatives - Other - Current — 945 — — Derivatives - Other - Noncurrent — 13,386 — 10,943 Total derivatives not designated as hedging instruments under GAAP $ 57,041 $ 89,146 $ 99,331 $ 123,348 Total Derivatives $ 57,041 $ 89,146 $ 99,331 $ 123,348
Offsetting assets	As of June 30, 2016 and December 31, 2015 , information related to these offsetting arrangements were as follows (in thousands): As of June 30, 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 $ 57,041 $ — $ 57,041 $ (26,263 ) (A) $ — $ 30,778 Derivatives - Energy Related Liabilities $ (74,815 ) $ — $ (74,815 ) $ 26,263 (B) $ 12,854 $ (35,698 ) Derivatives - Other $ (14,331 ) $ — $ (14,331 ) $ — $ — $ (14,331 ) 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 June 30, 2016 and December 31, 2015 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at June 30, 2016 and December 31, 2015 were related to derivative assets which can be net settled against derivative liabilities.
Offsetting liabilities	As of June 30, 2016 and December 31, 2015 , information related to these offsetting arrangements were as follows (in thousands): As of June 30, 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 $ 57,041 $ — $ 57,041 $ (26,263 ) (A) $ — $ 30,778 Derivatives - Energy Related Liabilities $ (74,815 ) $ — $ (74,815 ) $ 26,263 (B) $ 12,854 $ (35,698 ) Derivatives - Other $ (14,331 ) $ — $ (14,331 ) $ — $ — $ (14,331 ) 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 June 30, 2016 and December 31, 2015 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at June 30, 2016 and December 31, 2015 were related to derivative assets which can be net settled against derivative liabilities.
Derivatives in cash flow hedging relationships	The effect of derivative instruments on the condensed consolidated statements of income for the three and six months ended June 30, 2016 and 2015 are as follows (in thousands): Three Months Ended Six Months Ended Derivatives in Cash Flow Hedging Relationships under GAAP 2016 2015 2016 2015 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — $ — Losses reclassified from AOCL into income (a) $ (82 ) $ (187 ) $ (168 ) $ (210 ) Gains (losses) recognized in income on ineffective portion (a) $ — $ — $ — $ — (a) Included in Interest Charges Three Months Ended Six Months Ended Derivatives Not Designated as Hedging Instruments under GAAP 2016 2015 2016 2015 (Losses) gains on energy-related commodity contracts (a) $ (21,371 ) $ 14,685 $ (2,716 ) $ 7,978 (Losses) gains on interest rate contracts (b) (229 ) 541 (656 ) 243 Total $ (21,600 ) $ 15,226 $ (3,372 ) $ 8,221 (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges

FAIR VALUE OF FINANCIAL ASSET33

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair value of 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 June 30, 2016 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 15,160 $ 2,985 $ 12,175 $ — Derivatives – Energy Related Assets (B) 57,041 18,379 7,145 31,517 $ 72,201 $ 21,364 $ 19,320 $ 31,517 Liabilities Derivatives – Energy Related Liabilities (B) $ 74,815 $ 16,589 $ 24,613 $ 33,613 Derivatives – Other (C) 14,331 — 14,331 — $ 89,146 $ 16,589 $ 38,944 $ 33,613 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 of assets in Level 3 fair value measurements	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands): Type Fair Value at June 30, 2016 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $15,413 $20,012 Discounted Cash Flow Forward price (per dt) $ 1.56 - $10.34 [$2.37] (A) Forward Contract - Electric $16,104 $13,601 Discounted Cash Flow Fixed electric load profile (on-peak) 21.43% - 100.00% [56.08%] (B) Fixed electric load profile (off-peak) 0.00% - 78.57% [43.92%] (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.
Quantitative information regarding significant unobservable inputs of liabilities in Level 3 fair value measurements	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands): Type Fair Value at June 30, 2016 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $15,413 $20,012 Discounted Cash Flow Forward price (per dt) $ 1.56 - $10.34 [$2.37] (A) Forward Contract - Electric $16,104 $13,601 Discounted Cash Flow Fixed electric load profile (on-peak) 21.43% - 100.00% [56.08%] (B) Fixed electric load profile (off-peak) 0.00% - 78.57% [43.92%] (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 fair value of assets using significant unobservable inputs	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and six months ended June 30, 2016 and 2015 , using significant unobservable inputs (Level 3), are as follows (in thousands): Three Months Ended Six Months Ended Balance at beginning of period $ 13,241 $ (632 ) Other changes in fair value from continuing and new contracts, net (12,073 ) (2,058 ) Settlements (3,264 ) 594 Balance at end of period $ (2,096 ) $ (2,096 ) Three Months Ended Six Months Ended Balance at beginning of period $ (17,311 ) $ (5,608 ) Other changes in fair value from continuing and new contracts, net 14,376 (2,062 ) Transfers in/(out) of Level 3 (A) 2,054 2,054 Settlements (1,663 ) 3,072 Balance at end of period $ (2,544 ) $ (2,544 ) (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 three and six months ended June 30, 2015, $2.1 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.

ACCUMULATED OTHER COMPREHENSI34

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
Schedule of changes in accumulated other comprehensive loss (AOCL)	The following tables summarize the changes in accumulated other comprehensive loss (AOCL) for the three and six months ended June 30, 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 April 1, 2016 (a) $ (22,145 ) $ (2,078 ) $ (79 ) $ (97 ) $ (24,399 ) Other comprehensive income before reclassifications — — 73 — 73 Amounts reclassified from AOCL (b) — 49 (18 ) — 31 Net current period other comprehensive income (loss) — 49 55 — 104 Balance at June 30, 2016 (a) $ (22,145 ) $ (2,029 ) $ (24 ) $ (97 ) $ (24,295 ) 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 — — 136 — 136 Amounts reclassified from AOCL (b) — 100 (32 ) — 68 Net current period other comprehensive income (loss) — 100 104 — 204 Balance at June 30, 2016 (a) $ (22,145 ) $ (2,029 ) $ (24 ) $ (97 ) $ (24,295 ) (a) Determined using a combined average statutory tax rate of 40% . (b) See table below.
Reclassifications out of AOCL	The following table provides details about reclassifications out of AOCL for the three and six months ended June 30, 2016 : Amounts Reclassified from AOCL (in thousands) Affected Line Item in the Condensed Consolidated Statements of Income Three Months Ended Six Months Ended Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 82 $ 168 Interest Charges Income Taxes (33 ) (68 ) Income Taxes (a) $ 49 $ 100 Unrealized Gain on Available-for-Sale Securities $ (33 ) $ (57 ) Other Income Income Taxes 15 25 Income Taxes (a) $ (18 ) $ (32 ) Losses from reclassifications for the period net of tax $ 31 $ 68 (a) Determined using a combined average statutory tax rate of 40% .

SUMMARY OF SIGNIFICANT ACCOUN35

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2016USD ($)countymishares	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)countymishares	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)shares
Accounting Policies [Abstract]
Number of counties in which SJG operates | county	7		7
Length of pipeline (in miles) | mi	100		100
Public utility assessment	$ 200,000	$ 200,000	$ 500,000	$ 800,000
Impairment charges			0	$ 0
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization	$ 8,800,000		$ 8,800,000		$ 8,900,000
Shares of treasury stock held (in shares) | shares	207,573		207,573		236,571
Goodwill	$ 8,139,000		$ 8,139,000		$ 8,880,000

SUMMARY OF SIGNIFICANT ACCOUN36

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - GOODWILL (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)
Goodwill [Roll Forward]
Beginning Balance, January 1	$ 8,880
Fair Value Adjustments During Measurement Periods	(741)
Ending Balance, June 30	$ 8,139

STOCK-BASED COMPENSATION PLAN37

STOCK-BASED COMPENSATION PLAN (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of options granted (in shares)			0	0
Fair value per share (in dollars per share)	$ 24.80		$ 26.89		$ 24.80
Expected volatility, measurement period			3 years
Service period of shares (in years)			3 years
Total Cost	$ 1,025	$ 697	$ 2,035	$ 1,682
Capitalized	(106)	(87)	(212)	(178)
Net Expense	$ 919	610	$ 1,823	1,504
Unrecognized compensation cost of awards granted under the plan					$ 6,100
Weighted average period over which unrecognized compensation cost is to be recognized			2 years
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-beginning balance (in dollars per share)			$ 26.89
Weighted average fair value nonvested shares-granted during the period (in dollars per share)			23.28
Weighted average fair value nonvested shares-cancelled/forfeited during the period (in dollars per share)			25.10
Weighted average fair value nonvested shares-vested during the period (in dollars per share)			29.30
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 24.80		$ 24.80
Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted (in shares)			193,184
Shares outstanding (in shares)	399,135		226,191		399,135
Total Cost	$ 798	511	$ 1,615	$ 1,310
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)			226,191
Granted (in shares)			193,184
Cancelled/Forfeited (in shares)			(6,993)
Vested (in shares)			(13,247)
Nonvested shares outstanding, ending balance (in shares)	399,135		399,135
Officers and Key Employees | 2014 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	50,712		50,712		50,712
Fair value per share (in dollars per share)	$ 21.31		$ 21.31		$ 21.31
Expected volatility			20.00%
Risk-free interest rate			0.80%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	50,712		50,712
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 21.31		$ 21.31
Officers and Key Employees | 2014 - EGR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	50,712		50,712		50,712
Fair value per share (in dollars per share)	$ 27.22		$ 27.22		$ 27.22
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	50,712		50,712
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 27.22		$ 27.22
Officers and Key Employees | 2015 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	33,930		33,930		33,930
Fair value per share (in dollars 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, ending balance (in shares)	33,930		33,930
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 26.31		$ 26.31
Officers and Key Employees | 2015 - EGR, ROE, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	74,075		74,075		74,075
Fair value per share (in dollars per share)	$ 29.47		$ 29.47		$ 29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	74,075		74,075
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 29.47		$ 29.47
Officers and Key Employees | 2016 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	66,397		66,397		66,397
Fair value per share (in dollars per share)	$ 22.53		$ 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)	66,397		66,397
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 22.53		$ 22.53
Officers and Key Employees | 2016 - CEGR, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	123,309		123,309		123,309
Fair value per share (in dollars per share)	$ 23.52		$ 23.52		$ 23.52
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	123,309		123,309
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 23.52		$ 23.52
Officers and Key Employees | 2015 - Time
Additional disclosures [Abstract]
Number of shares awarded during the period			13,247
Fair value of shares issued			$ 300
Director
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted (in shares)			35,197	25,398
Vesting period of shares (in years)			12 months
Director shares vested (as percent)					100.00%
Shares outstanding (in shares)	35,197		26,338		35,197
Total Cost	$ 227	$ 186	$ 420	$ 372
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)			26,338
Granted (in shares)			35,197	25,398
Cancelled/Forfeited (in shares)			0
Vested (in shares)			(26,338)
Nonvested shares outstanding, ending balance (in shares)	35,197		35,197
Additional disclosures [Abstract]
Fair value of shares issued			$ 800	$ 700
Director | 2016
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	35,197		35,197		35,197
Fair value per share (in dollars per share)	$ 23.88		$ 23.88		$ 23.88
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	35,197		35,197
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 23.88		$ 23.88
Stock Appreciation Rights (SARs)
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted (in shares)			0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Granted (in shares)			0	0
Restricted Stock | Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted (in shares)			193,184	159,416
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Granted (in shares)			193,184	159,416
Restricted Stock | Officers and Key Employees | Minimum
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted			0.00%
Restricted Stock | Officers and Key Employees | Maximum
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted			200.00%
Time-based Restricted Stock
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Return on equity award threshold (as percent)			7.00%
Time-based Restricted Stock | Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted (in shares)			57,955	47,824
Vesting period of shares (in years)			3 years
Payout limit (as percent)			100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Granted (in shares)			57,955	47,824
Performance Shares | January 2012 and 2013 Grants
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares (in years)			3 years
Additional disclosures [Abstract]
Number of shares awarded during the period			0	0

AFFILIATIONS AND DISCONTINUED38

AFFILIATIONS AND DISCONTINUED OPERATIONS (Details) $ in Thousands	Dec. 31, 2015USD ($)investmentagreement	Jun. 30, 2016USD ($)mi	Jun. 30, 2015USD ($)
Affiliations [Abstract]
Notes receivable - affiliate	$ 16,400	$ 15,100
Notes receivable - affiliate, current	$ 3,134	$ 1,868
Length of pipeline (in miles) | mi		100
Investments in unconsolidated affiliates		$ 4,600	$ 1,300
Notes secured by property, plant and equipment of affiliates		$ 13,600
Interest accrual on secured notes receivable		7.50%
Due from affiliate, non-current and unsecured		$ 1,500
Net asset - included in investment in affiliates and other noncurrent liabilities		22,200
Combined equity contributions and the notes receivable - affiliate		$ 37,300
Energenic US LLC
Affiliations [Abstract]
Equity interest (as percent)		50.00%
Energenic US LLC | Marina Energy LLC
Affiliations [Abstract]
Number of purchase agreements | agreement	2
Number of investments owned | investment	8
Notes receivable - affiliate	$ 19,500
Notes receivable - affiliate, current		$ 1,800
Percentage of voting interests	100.00%
Total consideration transferred	$ 46,000
Fair value of interest exchanged	$ 14,500
Energenic US LLC | Marina Energy LLC | Co-venturer
Affiliations [Abstract]
Number of investments owned | investment	7
Fair value of interest exchanged	$ 31,500
Potato Creek, LLC (Potato Creek)
Affiliations [Abstract]
Equity interest (as percent)		30.00%
PennEast Pipeline Company, LLC (PennEast)
Affiliations [Abstract]
Equity interest (as percent)		20.00%
Length of pipeline (in miles) | mi		100

AFFILIATIONS AND DISCONTINUED39

AFFILIATIONS AND DISCONTINUED OPERATIONS AFFILIATIONS AND DISCONTINUED OPERATIONS - SUMMARY OF FINAL PURCHASE PRICE ALLOCATION (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Goodwill	$ 8,139	$ 8,880
Marina Energy LLC | Energenic US LLC
Schedule of Equity Method Investments [Line Items]
Current assets (excluding inventory)		7,804
Inventory		3,154
Note Receivable Received		19,504
Fixed Assets		46,460
Identifiable Intangibles		16,950
Goodwill		8,139
Non-Current Assets		1,873
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		(572)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects		$ 46,030

AFFILIATIONS AND DISCONTINUED40

AFFILIATIONS AND DISCONTINUED OPERATIONS - SUMMARY OF OPERATING RESULTS OF THE DISCONTINUED OPERATIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Loss Before Income Taxes:
Income Tax Benefits	$ 16	$ 40	$ 79	$ 177
Loss from Discontinued Operations — Net	$ (29)	$ (74)	$ (147)	$ (350)
Earnings (Loss) Per Common Share from
Basic and Diluted (in dollars per share)	$ 0	$ 0	$ 0	$ 0
Sand Mining
Loss Before Income Taxes:
Loss Before Income Taxes	$ (18)	$ (17)	$ (164)	$ (364)
Fuel Oil
Loss Before Income Taxes:
Loss Before Income Taxes	$ (27)	$ (97)	$ (62)	$ (163)

COMMON STOCK COMMON STOCK - Com

COMMON STOCK COMMON STOCK - Common stock shares issued and outstanding (Details) - shares	1 Months Ended	6 Months Ended
	May 31, 2016	Jun. 30, 2016
Common Stock [Roll Forward]
Beginning balance (in shares)		70,965,622
New Issuances During the Period:
Dividend Reinvestment Plan (in shares)		416,862
Stock-Based Compensation Plan (in shares)		45,338
Amount of stock issued in public offering (in shares)	8,050,000	8,050,000
Ending balance (in shares)		79,477,822

COMMON STOCK (Details)

COMMON STOCK (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	May 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Par value of common stock (in dollars per share)	$ 1.25	$ 1.25		$ 1.25
Net excess over par value recorded in premium on common stock				$ 205,600
Amount of stock issued in public offering (in shares)	8,050,000			8,050,000
Proceeds from sale of common stock	$ 203,600			$ 214,463	$ 3,596
Incremental shares included in diluted EPS calculation (in shares)		297,061	186,147	292,782	203,455
Dividend Reinvestment Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Proceeds from sale of common stock				$ 10,800	$ 3,600

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details)	1 Months Ended	3 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2015USD ($)term	Jun. 30, 2015USD ($)term	Jun. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2011	Mar. 31, 2016USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held In escrow			$ 2,300,000	$ 3,400,000
Margin accounts with selected counterparties to support risk management activities			35,900,000	43,700,000
Investment in Affiliates			22,168,000	16,983,000
Notes Receivable - Affiliate			$ 13,275,000	13,275,000
Atlantic City Note Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Note receivable, face amount	$ 10,000,000	$ 10,000,000
Notes receivable, interest rate (as a percent)	1.00%
Notes receivable, term	6 months
Notes receivable, number of additional terms | term	2	2
Notes receivable, length of each additional term	3 months
Energenic US LLC
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest (as percent)			50.00%
Contract term (in years)					20 years
Non-cash charge		$ 7,700,000
Loss from settlement				7,500,000
Cash payments from insurance recovery			$ 2,100,000
Insurance recovery receivable			4,900,000			$ 7,000,000
Investment in Affiliates			1,100,000
Notes Receivable - Affiliate			13,600,000
ACB
Accounts, Notes, Loans and Financing Receivable [Line Items]
Escrow deposit			0	1,700,000
South Jersey Gas Company | Financing Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Long-term receivables, net of unamortized discount			11,000,000	12,900,000
Imputed interest on long term receivables			$ 1,100,000	$ 1,300,000
South Jersey Gas Company | Financing Receivable | Minimum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Notes receivable, term			5 years
South Jersey Gas Company | Financing Receivable | Maximum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Notes receivable, term			10 years

FINANCIAL INSTRUMENTS - CREDIT

FINANCIAL INSTRUMENTS - CREDIT RISK (Details) - Supplier Concentration Risk - Derivatives Energy Related Assets $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)
Concentration Risk [Line Items]
Amount of derivatives - energy related assets with single retail counterparty	$ 6.1
Percentage of derivatives - energy related assets with a single retail counterparty	10.80%

FINANCIAL INSTRUMENTS - FINANCI

FINANCIAL INSTRUMENTS - FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VLAUE (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Financial Instruments, Owned, at Fair Value [Abstract]
Long-term debt, fair value	$ 1,154.2	$ 1,079
Long-term debt, carrying value	1,075.7	1,026.9
Unamortized debt issuance costs	$ 8.1	$ 9

SEGMENTS OF BUSINESS (Details)

SEGMENTS OF BUSINESS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Total Operating Revenues	$ 154,402	$ 177,710	$ 487,437	$ 560,662
Total Operating (Loss) Income	(7,986)	30,340	106,267	106,711
Total Depreciation and Amortization	27,321	22,262	53,462	43,848
Total Interest Charges	8,229	7,474	17,389	16,075
Total Income Taxes	(7,189)	(3,279)	32,078	13,334
Total Property Additions	53,968	89,731	108,630	139,351
Total Identifiable Assets	3,522,581		3,522,581		$ 3,471,933
Discontinued Operations
Segment Reporting Information [Line Items]
Total Identifiable Assets	1,776		1,776		1,545
Operating Segments
Segment Reporting Information [Line Items]
Total Operating Revenues	166,333	188,939	515,482	584,812
Total Interest Charges	10,931	9,648	22,828	20,456
Operating Segments | Gas Utility Operations
Segment Reporting Information [Line Items]
Total Operating Revenues	68,762	75,812	256,528	343,470
Total Operating (Loss) Income	9,931	11,961	85,704	85,150
Total Depreciation and Amortization	15,788	14,239	31,414	28,406
Total Interest Charges	4,552	5,113	9,339	10,303
Total Income Taxes	1,415	3,292	28,819	29,464
Total Property Additions	50,133	62,175	101,503	105,501
Total Identifiable Assets	2,410,522		2,410,522		2,281,576
Operating Segments | Energy Group
Segment Reporting Information [Line Items]
Total Operating Revenues	64,061	87,527	198,359	190,727
Total Operating (Loss) Income	(22,622)	15,485	15,448	18,720
Total Depreciation and Amortization	287	35	576	87
Total Interest Charges	79	(65)	275	250
Total Income Taxes	(8,877)	6,149	5,931	8,518
Total Property Additions	355	767	732	1,500
Total Identifiable Assets	265,348		265,348		342,299
Operating Segments | Energy Group | Wholesale Energy Operations
Segment Reporting Information [Line Items]
Total Operating Revenues	(1,309)	33,276	63,765	68,621
Total Operating (Loss) Income	(31,149)	15,158	7,095	15,488
Total Depreciation and Amortization	204	15	408	47
Total Interest Charges	1	(112)	65	130
Total Income Taxes	(12,258)	5,986	2,479	6,853
Total Property Additions	1	375	7	379
Total Identifiable Assets	179,809		179,809		231,660
Operating Segments | Energy Group | Retail Gas and Other Operations
Segment Reporting Information [Line Items]
Total Operating Revenues	22,305	18,065	52,038	56,143
Total Operating (Loss) Income	6,250	153	5,491	3,240
Total Depreciation and Amortization	83	20	168	40
Total Interest Charges	78	47	210	120
Total Income Taxes	2,450	92	2,282	1,668
Total Property Additions	354	392	725	1,121
Total Identifiable Assets	40,581		40,581		55,111
Operating Segments | Energy Group | Retail Electric Operations
Segment Reporting Information [Line Items]
Total Operating Revenues	43,065	36,186	82,556	65,963
Total Operating (Loss) Income	2,277	174	2,862	(8)
Total Income Taxes	931	71	1,170	(3)
Total Identifiable Assets	44,958		44,958		55,528
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Total Operating Revenues	25,093	17,835	43,302	33,764
Total Operating (Loss) Income	4,819	2,424	4,774	1,890
Total Depreciation and Amortization	10,986	7,530	20,989	14,655
Total Income Taxes	236	(12,756)	(2,750)	(24,811)
Total Property Additions	2,916	26,252	5,668	30,749
Total Identifiable Assets	780,399		780,399		795,116
Operating Segments | Energy Services | On-Site Energy Production
Segment Reporting Information [Line Items]
Total Operating Revenues	23,043	15,136	39,364	28,708
Total Operating (Loss) Income	4,561	2,177	4,472	1,695
Total Depreciation and Amortization	10,895	7,457	20,814	14,508
Total Interest Charges	3,442	1,661	6,904	3,976
Total Income Taxes	110	(12,861)	(2,902)	(24,908)
Total Property Additions	2,665	26,040	5,316	30,421
Total Identifiable Assets	776,907		776,907		790,231
Operating Segments | Energy Services | Appliance Service Operations
Segment Reporting Information [Line Items]
Total Operating Revenues	2,050	2,699	3,938	5,056
Total Operating (Loss) Income	258	247	302	195
Total Depreciation and Amortization	91	73	175	147
Total Income Taxes	126	105	152	97
Total Property Additions	251	212	352	328
Total Identifiable Assets	3,492		3,492		4,885
Corporate and Services
Segment Reporting Information [Line Items]
Total Operating Revenues	8,417	7,765	17,293	16,851
Total Operating (Loss) Income	(114)	470	341	951
Total Depreciation and Amortization	260	458	483	700
Total Interest Charges	2,858	2,939	6,310	5,927
Total Income Taxes	37	36	78	163
Total Property Additions	564	537	727	1,601
Total Identifiable Assets	633,685		633,685		652,325
Intersegment Elimination
Segment Reporting Information [Line Items]
Total Operating Revenues	(11,931)	(11,229)	(28,045)	(24,150)
Total Interest Charges	(2,702)	$ (2,174)	(5,439)	$ (4,381)
Total Identifiable Assets	$ (569,149)		$ (569,149)		$ (600,928)

RATES AND REGULATORY ACTIONS (D

RATES AND REGULATORY ACTIONS (Details) - USD ($) $ in Millions	Feb. 29, 2016	Jun. 30, 2016	Apr. 30, 2016	Jan. 31, 2016	Oct. 31, 2015
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Decrease in amount of regulatory costs approved	$ 7.9
Requested rate increase (decrease)		$ (0.8)
New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Requested rate increase (decrease)		0.6
New Jersey Board of Public Utilities | Transportation Initiation Clause
Schedule of Capitalization [Line Items]
Approved revenue increase (decrease)			$ 5.2
New Jersey Board of Public Utilities | Clean Energy Program
Schedule of Capitalization [Line Items]
Approved revenue increase (decrease)			(7.1)
New Jersey Board of Public Utilities | Tenants in Common
Schedule of Capitalization [Line Items]
Approved revenue increase (decrease)			(0.7)
New Jersey Board of Public Utilities | Storm Hardening and Reliability Program
Schedule of Capitalization [Line Items]
Requested rate increase (decrease)			4.4
New Jersey Board of Public Utilities | Conservation Incentive Program
Schedule of Capitalization [Line Items]
Requested rate increase (decrease)		46.5
Basic Gas Supply Service
Schedule of Capitalization [Line Items]
Refunds to customers				$ 20
Approved rate decrease (as a percent)					10.30%
Basic Gas Supply Service | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Requested rate increase (decrease)		$ (47.1)
Accelerated Infrastructure Replacement Program
Schedule of Capitalization [Line Items]
Extension period of AIRP	7 years
Investment requested to be recovered through CIRT	$ 500
Investment requested to be recovered through end of 2016	$ 76
Societal Benefits Clause
Schedule of Capitalization [Line Items]
Approved revenue increase (decrease)			$ (2.6)

REGULATORY ASSETS & REGULATOR48

REGULATORY ASSETS & REGULATORY LIABILITIES - REGULATORY ASSETS (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Regulatory Assets [Line Items]
Regulatory assets	$ 380,364	$ 323,434
Environmental Remediation Costs: Expended - Net
Regulatory Assets [Line Items]
Regulatory assets	50,650	42,032
Environmental Remediation Costs: Liability for Future Expenditures
Regulatory Assets [Line Items]
Regulatory assets	152,349	123,194
Deferred Asset Retirement Obligation Costs
Regulatory Assets [Line Items]
Regulatory assets	42,912	42,430
Deferred Pension and Other Postretirement Benefit Costs
Regulatory Assets [Line Items]
Regulatory assets	79,779	79,779
Deferred Gas Costs - Net
Regulatory Assets [Line Items]
Regulatory assets	0	2,701
Conservation Incentive Program Receivable
Regulatory Assets [Line Items]
Regulatory assets	21,766	2,624
Deferred Interest Rate Contracts
Regulatory Assets [Line Items]
Regulatory assets	10,363	7,631
Energy Efficiency Tracker
Regulatory Assets [Line Items]
Regulatory assets	0	496
Pipeline Supplier Service Charges
Regulatory Assets [Line Items]
Regulatory assets	2,943	3,776
Pipeline Integrity Cost
Regulatory Assets [Line Items]
Regulatory assets	4,447	4,596
AFUDC - Equity Related Deferrals
Regulatory Assets [Line Items]
Regulatory assets	11,938	11,423
Other Regulatory Assets
Regulatory Assets [Line Items]
Regulatory assets	$ 3,217	$ 2,752

REGULATORY ASSETS AND REGULAT49

REGULATORY ASSETS AND REGULATORY LIABILITIES REGULATORY ASSETS & REGULATORY LIABILITIES (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)siteasset	Feb. 29, 2016USD ($)	Dec. 31, 2015USD ($)
Regulatory Assets [Line Items]
Regulatory assets	$ 380,364		$ 323,434
Regulatory Liabilities [Line Items]
Regulatory liabilities	60,010		42,841
Excess Plant Removal Costs
Regulatory Liabilities [Line Items]
Regulatory liabilities	31,078		32,644
Deferred Revenues - Net
Regulatory Liabilities [Line Items]
Regulatory liabilities	18,631		0
Societal Benefit Costs
Regulatory Liabilities [Line Items]
Regulatory liabilities	8,233		10,197
Energy Efficiency Tracker
Regulatory Liabilities [Line Items]
Regulatory liabilities	$ 2,068		0
Environmental Restoration Costs
Regulatory Assets [Line Items]
Number of regulatory assets | asset	2
Number of sites for environmental cleanup | site	12
Original recovery period of expenditures	7 years
Deferred Revenues - Net
Regulatory Assets [Line Items]
Regulatory assets			2,700
Energy Efficiency Tracker
Regulatory Assets [Line Items]
Regulatory assets	$ 0		$ 496
Regulatory Liabilities [Line Items]
Decrease in amount of regulatory costs approved		$ 7,900

PENSION AND OTHER POSTRETIREM50

PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($)	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2015	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pension Benefits
Net periodic benefit cost [Abstract]
Service Cost		$ 1,106,000	$ 1,225,000	$ 2,421,000	$ 2,668,000
Interest Cost		3,062,000	2,814,000	6,062,000	5,584,000
Expected Return on Plan Assets		(3,374,000)	(3,695,000)	(6,754,000)	(7,394,000)
Amortizations:
Prior Service Cost		53,000	53,000	106,000	106,000
Actuarial Loss		2,388,000	2,648,000	4,697,000	5,304,000
Net Periodic Benefit Cost		3,235,000	3,045,000	6,532,000	6,268,000
Capitalized Benefit Cost		(1,213,000)	(1,194,000)	(2,400,000)	(2,433,000)
Deferred Benefit Cost		(161,000)	(325,000)	(322,000)	(325,000)
Total Net Periodic Benefit Expense		1,861,000	1,526,000	3,810,000	3,510,000
Contributions	$ 15,000,000			0
Estimated future contributions				0
Other Postretirement Benefits
Net periodic benefit cost [Abstract]
Service Cost		195,000	231,000	425,000	558,000
Interest Cost		654,000	715,000	1,307,000	1,487,000
Expected Return on Plan Assets		(776,000)	(749,000)	(1,552,000)	(1,497,000)
Amortizations:
Prior Service Cost		(86,000)	152,000	(172,000)	304,000
Actuarial Loss		261,000	287,000	555,000	671,000
Net Periodic Benefit Cost		248,000	636,000	563,000	1,523,000
Capitalized Benefit Cost		(45,000)	(271,000)	(146,000)	(528,000)
Deferred Benefit Cost		0	(79,000)	0	(79,000)
Total Net Periodic Benefit Expense		$ 203,000	$ 286,000	417,000	$ 916,000
Defined benefit plan regulatory obligation to contribute to the plan during the period				3,600,000
Supplemental Employee Retirement Plans, Defined Benefit
Amortizations:
Estimated future contributions				$ 2,300,000

LINES OF CREDIT (Details)

LINES OF CREDIT (Details) - Line of Credit	6 Months Ended
	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)
Line of Credit Facility [Line Items]
Total Facility	$ 610,000,000
Usage	149,000,000
Available Liquidity	$ 461,000,000
Weighted average interest rate on borrowings (as a percent)	1.43%	0.96%
Average borrowings outstanding during the period	$ 325,500,000	$ 274,300,000
Maximum amounts outstanding during the period	$ 467,700,000	$ 368,100,000
Financial covenant, ratio of indebtedness to consolidated total capitalization (not more than)	0.65
SJG Commercial Paper Program
Line of Credit Facility [Line Items]
Total Facility	$ 200,000,000
Fixed maturities of notes, at maximum number of days (in days)	270 days
South Jersey Gas Company
Line of Credit Facility [Line Items]
Total Facility	$ 210,000,000
Usage	14,100,000
Available Liquidity	195,900,000
South Jersey Gas Company | Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility	200,000,000
Usage	14,100,000
Available Liquidity	185,900,000
South Jersey Gas Company | Uncommitted Bank Line
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	400,000,000
Usage	134,900,000
Available Liquidity	265,100,000
South Jersey Industries Inc | Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility	400,000,000
Usage	134,900,000
Available Liquidity	265,100,000
Letters of credit outstanding	2,800,000
Revolving Credit Facility | South Jersey Gas Company
Line of Credit Facility [Line Items]
Letters of credit outstanding	$ 800,000

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)siteunions	Dec. 31, 2015USD ($)
Collective bargaining agreements [Abstract]
Percentage of personnel represented by collective bargaining agreements	45.00%
Number of unions (in unions) | unions	2
Pending litigation [Abstract]
Estimated litigation liability	$ 3,100	$ 3,200
Environmental Restoration Costs
Environmental remediation costs [Abstract]
Number of sites for environmental cleanup (in number of sites) | site	12
Line of Credit
Collective bargaining agreements [Abstract]
Letter of credit provided	$ 610,000
Line of Credit | South Jersey Gas Company
Collective bargaining agreements [Abstract]
Letter of credit provided	210,000
Line of Credit | South Jersey Gas Company | Revolving Credit Facility
Collective bargaining agreements [Abstract]
Letters of credit outstanding	800
Standby Letter of Credit
Collective bargaining agreements [Abstract]
Letter of credit provided	2,800
Letter of Credit, Separate Facility
Collective bargaining agreements [Abstract]
Letter of credit provided	87,500
Parental Guarantee
Guarantees [Abstract]
Guaranteed amount	$ 5,900
Guarantee expiration period	2 years

DERIVATIVE INSTRUMENTS - DERIVA

DERIVATIVE INSTRUMENTS - DERIVATIVE INSTRUMENTS AND THE ACTIVE INTEREST SWAPS (Details) MWh in Millions	6 Months Ended
	Jun. 30, 2016USD ($)MWh	Jun. 30, 2016USD ($)MMcfe
Marina | Interest Rate Swap, $14,500,000 Contract
Derivative [Line Items]
Derivative, Notional Amount	$ 14,500,000	$ 14,500,000
Derivative, Fixed Interest Rate	3.905%	3.905%
Marina | Interest Rate Swap, $500,000 Contract
Derivative [Line Items]
Derivative, Notional Amount	$ 500,000	$ 500,000
Derivative, Fixed Interest Rate	3.905%	3.905%
Marina | Interest Rate Swap, $330,000 Contract
Derivative [Line Items]
Derivative, Notional Amount	$ 330,000	$ 330,000
Derivative, Fixed Interest Rate	3.905%	3.905%
SJG | Interest Rate Swap, $12,500,000 Contract 1
Derivative [Line Items]
Derivative, Notional Amount	$ 12,500,000	$ 12,500,000
Derivative, Fixed Interest Rate	3.53%	3.53%
SJG | Interest Rate Swap, $12,500,000 Contract 2
Derivative [Line Items]
Derivative, Notional Amount	$ 12,500,000	$ 12,500,000
Derivative, 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		148,700
Derivative Transaction Type, Purchase
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh)	2.6	64,200
Derivative Transaction Type, Sale
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh)	2.4	71,500

DERIVATIVE INSTRUMENTS - FAIR V

DERIVATIVE INSTRUMENTS - FAIR VALUE OF ALL DERIVATIVE INSTRUMENTS (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	$ 57,041	$ 99,331
Fair value Derivative Liabilities	89,146	123,348
Commodity Contract
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	57,041	99,331
Fair value Derivative Liabilities	0	0
Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	57,041	99,331
Fair value Derivative Liabilities	89,146	123,348
Not Designated as Hedging Instrument | Commodity Contract | Derivatives-Energy Related-Current
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	45,112	83,093
Fair value Derivative Liabilities	66,444	90,708
Not Designated as Hedging Instrument | Commodity Contract | Derivatives-Energy Related-NonCurrent
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	11,929	16,238
Fair value Derivative Liabilities	8,371	21,697
Not Designated as Hedging Instrument | Interest Rate Contract | Derivatives-Other Current
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	945	0
Not Designated as Hedging Instrument | Interest Rate Contract | Derivatives-Other Noncurrent
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$ 13,386	$ 10,943

DERIVATIVE INSTRUMENTS - OFFSET

DERIVATIVE INSTRUMENTS - OFFSETTING ARRANGEMENTS (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	$ 57,041	$ 99,331
Offsetting Derivative Liabilities [Abstract]
Gross amount offset in the balance sheet	89,146	123,348
Commodity Contract
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	57,041	99,331
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	57,041	99,331
Gross amounts not offset in the balance sheet, Financial Instruments	(26,263)	(35,491)
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	0
Net amount	30,778	63,840
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(74,815)	(112,405)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(74,815)	(112,405)
Gross amounts not offset in the balance sheet, Financial Instruments	26,263	35,491
Gross amounts not offset in the balance sheet, Cash Collateral Posted	12,854	23,045
Net amount	(35,698)	(53,869)
Other Contract
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(14,331)	(10,943)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(14,331)	(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	$ (14,331)	$ (10,943)

DERIVATIVE INSTRUMENTS (Details

DERIVATIVE INSTRUMENTS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Interest Rate Contracts:
Total	$ (21,600)	$ 15,226	$ (3,372)	$ 8,221
Net realized gains (losses), derivative instruments, energy-related contracts	(1,600)	(2,100)	(4,400)	(4,800)
Fair value derivative instruments with credit-risk-related features	22,100		22,100
Additional collateral, aggregate fair value	20,100		20,100
Designated as Hedging Instrument
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	0	0	0	0
Losses reclassified from AOCL into income	(82)	(187)	(168)	(210)
Gains (losses) recognized in income on ineffective portion	0	0	0	0
Not Designated as Hedging Instrument
Interest Rate Contracts:
Gain (losses) on energy related commodity contracts	(21,371)	14,685	(2,716)	7,978
Gain (losses) on interest rate contracts	$ (229)	$ 541	$ (656)	$ 243

FAIR VALUE OF FINANCIAL ASSET57

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of derivatives transferred to level 3	$ 2,100		$ 2,100
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period	13,241	$ (17,311)	(632)	$ (5,608)
Other changes in fair value from continuing and new contracts, net	(12,073)	(14,376)	(2,058)	2,062
Transfers in/(out) of Level 3		2,054		2,054
Settlements	(3,264)	(1,663)	594	3,072
Balance at end of period	(2,096)	$ (2,544)	(2,096)	$ (2,544)
Fair Value, Measurements, Recurring
Assets
Available-for-Sale Securities	15,160		15,160		$ 14,810
Derivatives - Energy Related Assets	57,041		57,041		99,331
Total Assets	72,201		72,201		114,141
Liabilities
Derivatives - Energy Related Liabilities	74,815		74,815		112,405
Derivatives - Other	14,331		14,331		10,943
Total Liabilities	89,146		89,146		123,348
Fair Value, Measurements, Recurring | Level 1
Assets
Available-for-Sale Securities	2,985		2,985		2,925
Derivatives - Energy Related Assets	18,379		18,379		16,006
Total Assets	21,364		21,364		18,931
Liabilities
Derivatives - Energy Related Liabilities	16,589		16,589		42,170
Derivatives - Other	0		0		0
Total Liabilities	16,589		16,589		42,170
Fair Value, Measurements, Recurring | Level 2
Assets
Available-for-Sale Securities	12,175		12,175		11,885
Derivatives - Energy Related Assets	7,145		7,145		24,730
Total Assets	19,320		19,320		36,615
Liabilities
Derivatives - Energy Related Liabilities	24,613		24,613		11,008
Derivatives - Other	14,331		14,331		10,943
Total Liabilities	38,944		38,944		21,951
Fair Value, Measurements, Recurring | Level 3
Assets
Available-for-Sale Securities	0		0		0
Derivatives - Energy Related Assets	31,517		31,517		58,595
Total Assets	31,517		31,517		58,595
Liabilities
Derivatives - Energy Related Liabilities	33,613		33,613		59,227
Derivatives - Other	0		0		0
Total Liabilities	$ 33,613		$ 33,613		$ 59,227

FAIR VALUE OF FINANCIAL ASSET58

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES - LEVEL THREE INPUTS (Details) - Forward Contracts - Fair Value, Inputs, Level 3 $ in Thousands	Jun. 30, 2016USD ($)$ / decatherm	Dec. 31, 2015USD ($)$ / decatherm
Natural Gas | Minimum
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) | $ / decatherm	1.56	(0.77)
Natural Gas | Maximum
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) | $ / decatherm	10.34	10
Natural Gas | Weighted Average
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) | $ / decatherm	2.37	(2.15)
Electricity | Minimum | On-Peak
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	21.43%	8.47%
Electricity | Minimum | Off-Peak
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	0.00%	0.00%
Electricity | Maximum | On-Peak
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	100.00%	100.00%
Electricity | Maximum | Off-Peak
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	78.57%	91.53%
Electricity | Weighted Average | On-Peak
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	56.08%	56.20%
Electricity | Weighted Average | Off-Peak
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	43.92%	43.80%
Discounted Cash Flow | Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	$ 15,413	$ 29,459
Liabilities	20,012	31,733
Discounted Cash Flow | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	16,104	29,136
Liabilities	$ 13,601	$ 27,494

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details) - USD ($)	1 Months Ended	6 Months Ended
	Jan. 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Debt Instrument [Line Items]
Proceeds from issuance of debt		$ 61,000,000	$ 0
Long-term debt outstanding		1,075,700,000		$ 1,026,900,000
Current Portion of Long-Term Debt		$ 244,605,000		$ 29,454,000
Interest rate		7.50%
Senior Notes
Debt Instrument [Line Items]
Current Portion of Long-Term Debt		$ 16,000,000
Interest rate		2.71%
ACB
Debt Instrument [Line Items]
Repayments of debt	$ 12,700,000
South Jersey Gas Company | Loans Payable | Line of Credit
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 61,000,000
Interest rate (as percent)	1.37%
Letter of credit provided	$ 200,000,000
Long-term debt outstanding		$ 200,000,000

ACCUMULATED OTHER COMPREHENSI60

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		$ (24,399)		$ (24,499)
Other comprehensive income before reclassifications		73		136
Amounts reclassified from AOCL		31		68
Other Comprehensive Income - Net of Tax	[1]	104	$ 106	204	$ 107
Ending balance		$ (24,295)		$ (24,295)
Combined statutory tax rate		40.00%	40.00%	40.00%	40.00%
Postretirement Liability Adjustment
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		$ (22,145)		$ (22,145)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL		0		0
Other Comprehensive Income - Net of Tax		0		0
Ending balance		(22,145)		(22,145)
Unrealized Gain (Loss) on Derivatives-Other
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(2,078)		(2,129)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL		49		100
Other Comprehensive Income - Net of Tax		49		100
Ending balance		(2,029)		(2,029)
Unrealized Gain (Loss) on Available-for-Sale Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(79)		(128)
Other comprehensive income before reclassifications		73		136
Amounts reclassified from AOCL		(18)		(32)
Other Comprehensive Income - Net of Tax		55		104
Ending balance		(24)		(24)
Other Comprehensive Income (Loss) of Affiliated Companies
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(97)		(97)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL		0		0
Other Comprehensive Income - Net of Tax		0		0
Ending balance		$ (97)		$ (97)
[1]	Determined using a combined average statutory tax rate of 40%.

ACCUMULATED OTHER COMPREHENSI61

ACCUMULATED OTHER COMPREHENSIVE LOSS - RECLASSIFICATIONS OUT OF AOCL (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	$ 8,229	$ 7,474	$ 17,389	$ 16,075
Income Taxes	(7,189)	(3,279)	32,078	13,334
Other Income	(4,361)	(3,040)	(6,564)	(5,281)
Losses (Gains) from reclassifications for the period net of tax	$ 4,798	$ (13,341)	$ (63,389)	$ (67,194)
Combined statutory tax rate	40.00%	40.00%	40.00%	40.00%
Reclassification out of Accumulated Other Comprehensive Income
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Losses (Gains) from reclassifications for the period net of tax	$ 31		$ 68
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Gain (Loss) on Derivatives-Other
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	82		168
Income Taxes	(33)		(68)
Losses (Gains) from reclassifications for the period net of tax	49		100
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Loss on Available-for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Income Taxes	15		25
Other Income	(33)		(57)
Losses (Gains) from reclassifications for the period net of tax	$ (18)		$ (32)

SUBSEQUENT EVENT (Details)

SUBSEQUENT EVENT (Details) $ in Millions	1 Months Ended
	Jul. 31, 2016USD ($)
Subsequent Event
Subsequent Event [Line Items]
Proceeds from collection of notes receivable	$ 10