South Jersey Industries (SJIIU) 10-K 27 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 15, 2017	Jun. 30, 2016
Entity [Abstract]
Entity Registrant Name	SOUTH JERSEY INDUSTRIES INC
Entity Central Index Key	91,928
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		79,516,553
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 2,506,525,273

Statements of Consolidated Inco

Statements of Consolidated Income shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares
Operating Revenues:
Utility	$ 453,819	$ 528,763	$ 500,752
Nonutility	582,681	430,805	386,244
Total Operating Revenues	1,036,500	959,568	886,996
Cost of Sales - (Excluding depreciation)
- Utility	167,154	239,763	230,093
- Nonutility	413,833	319,579	306,859
Operations	151,957	148,672	140,260
Maintenance	17,549	16,183	13,457
Depreciation	90,389	72,451	63,004
Energy and Other Taxes	6,342	6,026	5,720
Total Operating Expenses	847,224	802,674	759,393
Operating Income	189,276	156,894	127,603
Other Income and Expense	9,989	9,510	11,819
Interest Charges	(31,449)	(31,622)	(29,560)
Income Before Income Taxes	167,816	134,782	109,862
Income Taxes	(54,151)	(1,360)	(4,449)
Equity in Earnings (Loss) of Affiliated Companies	5,396	(27,812)	(7,785)
Income from Continuing Operations	119,061	105,610	97,628
Loss from Discontinued Operations - (Net of tax benefit)	(251)	(503)	(582)
Net Income	$ 118,810	$ 105,107	$ 97,046
Basic Earnings per Common Share:
Continuing Operations (in USD per share) | $ / shares	$ 1.56	$ 1.54	$ 1.47
Discontinued Operations (in USD per share) | $ / shares	0	(0.01)	(0.01)
Basic Earnings per Common Share (in USD per share) | $ / shares	$ 1.56	$ 1.53	$ 1.46
Average Shares of Common Stock Outstanding - Basic (in shares) | shares	76,362	68,735	66,278
Diluted Earnings per Common Share:
Continuing Operations (in USD per share) | $ / shares	$ 1.56	$ 1.53	$ 1.47
Discontinued Operations (in USD per share) | $ / shares	0	(0.01)	(0.01)
Diluted Earnings per Common Share (in USD per share) | $ / shares	$ 1.56	$ 1.52	$ 1.46
Average Shares of Common Stock Outstanding - Diluted (in shares) | shares	76,475	68,931	66,428

Statements of Consolidated Comp

Statements of Consolidated Comprehensive Income - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Net Income		$ 118,810	$ 105,107	$ 97,046
Other Comprehensive Income (Loss), Net of Tax:
Postretirement Liability Adjustment		(3,197)	5,518	(9,160)
Unrealized Gain (Loss) on Available-for-Sale Securities		118	(53)	(472)
Unrealized Gain on Derivatives - Other		197	321	247
Other Comprehensive Loss of Affiliated Companies		0	(27)	(113)
Other Comprehensive (Loss) Income - Net of Tax	[1],[2]	(2,882)	5,759	(9,498)
Comprehensive Income		$ 115,928	$ 110,866	$ 87,548
Additional Statement Information [Abstract]
Combined average statutory tax rate		40.00%
[1]	Determined using a combined average statutory tax rate of 40%.
[2]	Determined using a combined average statutory tax rate of 40%.

Statements of Consolidated Cash

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

Consolidated Balance Sheets

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

Consolidated Balance Sheets (Pa

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

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity and Comprehensive Income - USD ($) $ in Thousands		Total		Common Stock	Premium on Common Stock	Treasury Stock	Accumulated Other Comprehensive Loss		Retained Earnings	Postretirement Liability Adjustment		Unrealized Gain (Loss) on Derivatives-Other		Unrealized Gain (Loss) on Available- for-Sale Securities		Other Comprehensive Income (Loss) of Affiliated Companies
Balance at Dec. 31, 2013		$ 827,000		$ 81,788	$ 360,303	$ (372)	$ (20,760)		$ 406,041
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		97,046							97,046
Common Stock Issued or Granted Through Equity Offering or Stock Plans		81,753		3,630	78,081	42
Cash Dividends Declared - Common Stock		(63,869)							(63,869)
Balance at Dec. 31, 2014		932,432		85,418	438,384	(330)	(30,258)		439,218
Balance at January 1 at Dec. 31, 2013	[1]						(20,760)			$ (18,503)		$ (2,697)		$ 397		$ 43
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Changes During Year		(9,498)	[2],[3]				(9,498)	[1],[3]		(9,160)	[1]	247	[1]	(472)	[1]	(113)	[1]
Balance at December 31 at Dec. 31, 2014	[1]						(30,258)			(27,663)		(2,450)		(75)		(70)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		105,107							105,107
Common Stock Issued or Granted Through Equity Offering or Stock Plans		64,399		3,289	61,076	34
Cash Dividends Declared - Common Stock		(70,158)							(70,158)
Balance at Dec. 31, 2015		1,037,539		88,707	499,460	(296)	(24,499)		474,167
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Changes During Year		5,759	[2],[3]				5,759	[1],[3]		5,518	[1]	321	[1]	(53)	[1]	(27)	[1]
Balance at December 31 at Dec. 31, 2015		(24,499)					(24,499)	[1]		(22,145)	[1]	(2,129)	[1]	(128)	[1]	(97)	[1]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		118,810							118,810
Common Stock Issued or Granted Through Equity Offering or Stock Plans		218,153		10,640	207,483	30
Cash Dividends Declared - Common Stock		(82,380)							(82,380)
Balance at Dec. 31, 2016		$ 1,289,240		$ 99,347	$ 706,943	$ (266)	(27,381)		$ 510,597
Additional Statement Information [Abstract]
Combined average statutory tax rate		40.00%
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Changes During Year		$ (2,882)	[2],[3]				(2,882)	[1],[3]		(3,197)	[1]	197	[1]	118	[1]	0	[1]
Balance at December 31 at Dec. 31, 2016		$ (27,381)					$ (27,381)	[1]		$ (25,342)	[1]	$ (1,932)	[1]	$ (10)	[1]	$ (97)	[1]
[1]	Determined using a combined average statutory tax rate of 40%.
[2]	Determined using a combined average statutory tax rate of 40%.
[3]	Determined using a combined average statutory tax rate of 40%.

Consolidated Statements of Cha8

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

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries: ▪ South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey. ▪ South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial, industrial and residential customers. ▪ South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets along with fuel management services on a wholesale basis in the mid-Atlantic, Appalachian and southern states. ▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. ▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include: • ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey. • AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey. • MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey. ▪ South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. • SJI Midstream, LLC invests in infrastructure and other midstream projects, including a current project to build a 100 -mile natural gas pipeline in Pennsylvania and New Jersey. BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position, operating results and cash flows at the dates and for the periods presented. Certain reclassifications have been made to the prior period's consolidated balance sheets, as well as the prior period's long-term debt carrying value and the prior period's segment disclosures in Notes 7 and 8, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the consolidated balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described below under "New Accounting Pronouncements." This reclassification caused the prior periods long-term debt carrying value in Note 7 to be adjusted, along with the prior periods unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 8 to be removed. On February 26, 2015, the Board of Directors approved an amendment to SJI's Certificate of Incorporation to increase the authorized number of shares of common stock from 60,000,000 shares to 120,000,000 shares. The principal purpose of the increase was to permit a two -for-one split of all the issued shares of SJI's common stock, effected pursuant to a stock dividend of one share of common stock for each outstanding share of common stock, payable May 8, 2015 to shareholders of record at the close of business on April 17, 2015. All references to number of shares and per share information in the consolidated financial statements and related notes have been adjusted for all periods presented to reflect this stock split. EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary. Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. We include the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in Earnings (Loss) of Affiliated Companies (see Note 3). An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary. In 2015, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings due to the reduction in the carrying value of an investment in a project entered into by Energenic (see Note 7). No impairment losses were recorded on Investments during 2016 or 2014. ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (GAAP). Management makes estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition. REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980 -”Regulated Operations.” In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities. OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy-related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. SJRG presents revenues and expenses related to its energy trading activities on a net basis in operating revenues. This net presentation has no effect on operating income or net income. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers. REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both utility revenue and energy and other taxes and totaled $1.1 million , $1.2 million , and $1.1 million in 2016 , 2015 and 2014 , respectively. ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLECTIBLE ACCOUNTS - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts. NATURAL GAS IN STORAGE – Natural Gas in Storage is reflected at average cost on the consolidated balance sheets, and represents natural gas that will be utilized in the ordinary course of business. ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO. ARO activity was as follows (in thousands): 2016 2015 AROs as of January 1, $ 57,943 $ 42,502 Accretion 1,937 1,675 Additions 1,098 802 Settlements (1,551 ) (1,110 ) Revisions in Estimated Cash Flows (A) — 14,074 ARO's as of December 31, $ 59,427 $ 57,943 (A) The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings. PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account. As of December 31, 2016 , SJG's utility plant had a gross book value of $2.4 billion , which consists of utility plant assets along with projects for distribution, some of which are part of SJG's Accelerated Infrastructure Replacement Program (AIRP), as discussed in Note 10. As of December 31, 2016, the gross book value of SJI's nonutility property and equipment is $821.9 million , which consists of $652.8 million of solar assets, $124.2 million of cogeneration assets and $44.9 million of other property and equipment. DEPRECIATION - We depreciate utility plant on a straight-line basis over the estimated remaining lives of the various property classes. These estimates are periodically reviewed and adjusted as required after BPU approval. The composite annual rate for all depreciable utility property was approximately 2.2% in each of 2016 , 2015 and 2014 . The actual composite rate may differ from the approved rate as the asset mix changes over time. Except for retirements outside of the normal course of business, accumulated depreciation is charged with the cost of depreciable utility property retired, less salvage. Nonutility property depreciation is computed on a straight-line basis over the estimated useful lives of the property, ranging up to 50 years. Gain or loss on the disposition of nonutility property is recognized in operating income. As of December 31, 2016, total accumulated deprecation for utility and nonutility property and equipment was $471.2 million and $151.1 million , respectively. CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in SJG's last base rate proceeding. For SJG's accelerated infrastructure programs, SJG capitalizes interest on construction at a rate prescribed by the programs (see Note 10), and amounts are included in Utility Plant on the consolidated balance sheets. Marina and Midstream capitalize interest on capital projects in progress based on the actual cost of borrowed funds, and amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the statements of consolidated income. The amount of interest capitalized by SJI for the years ended December 31, 2016 , 2015 and 2014 was $6.6 million , $4.9 million and $4.6 million , respectively. IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the years ended December 31, 2016, 2015 and 2014, no significant impairments were identified. DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.” We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause. Initially and on an ongoing basis, we assess whether derivatives designated as hedges are highly effective in offsetting changes in cash flows or fair values of the hedged items. We discontinue hedge accounting prospectively if we decide to discontinue the hedging relationship; determine that the anticipated transaction is no longer likely to occur; or determine that a derivative is no longer highly effective as a hedge. In the event that hedge accounting is discontinued, we will continue to carry the derivative on the balance sheet at its current fair value and recognize subsequent changes in fair value in current period earnings. Unrealized gains and losses on the discontinued hedges that were previously included in Accumulated Other Comprehensive Loss will be reclassified into earnings when the forecasted transaction occurs, or when it is probable that it will not occur. Hedge accounting has been discontinued for all remaining derivatives that were designated as hedging instruments. GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment charges were recorded during the years ended December 31, 2016, 2015 and 2014. As of December 31, 2016 and 2015 , $8.8 million and $8.9 million , respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment and Other Noncurrent Assets on the consolidated balance sheets. TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of December 31, 2016 and 2015 , SJI held 212,617 and 236,571 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI. INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow-through method. CASH AND CASH EQUIVALENTS - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents. IDENTIFIABLE INTANGIBLE ASSETS - Identifiable intangible assets were acquired as part of the acquisition of Energenic projects as discussed in Note 3 and are a part of the On-Site Energy Production segment. The primary identifiable intangible assets of the Company are customer relationships. The Company determines the useful lives of identifiable intangible assets after considering the specific facts and circumstances related to each intangible asset. Considerations may include the contractual term of any agreement related to the asset, the historical performance of the asset, the Company's long-term strategy for using the asset, any laws or other local regulations which could impact the useful life of the asset, and other economic factors, including competition and specific market conditions. Intangible assets that are deemed to have definite lives (finite-lived intangible assets) are amortized, primarily on a straight-line basis, over their useful lives, generally ranging from 2 to 20 years. The cost of identifiable intangible assets of $15.8 million and $21.6 million are included in Noncurrent Assets on the consolidated balance sheets as of December 31, 2016 and 2015, respectively. The decrease in intangible assets of $5.7 million was attributable to the finalization of the purchase price allocation (see Note 3), which resulted in an adjustment of $4.6 million , along with amortization expense recorded during 2016 of $1.1 million . No amortization was recorded on these assets during 2015. GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects as discussed in Note 3 and is a part of the On-Site Energy Production segment. Goodwill represents the excess of the consideration paid over the fair value of identifiable net assets acquired. Goodwill is not amortized, but instead is subject to impairment testing on an annual basis, and between annual tests whenever events or changes in circumstances indicate that the fair value of a reporting unit may be below its carrying amount. The Company performed its annual goodwill impairment test in the fourth quarter of 2016 using a qualitative analysis at the reporting unit level. The reporting unit level is identified by assessing whether the components of our operating segments constitute businesses for which discrete financial information is available, whether segment management regularly reviews the operating results of those components and whether the economic and regulatory characteristics are similar. Factors utilized in the qualitative analysis performed on goodwill in our reporting units include, among other things, macroeconomic conditions, industry and market considerations, cost factors, overall financial performance, company specific operating results and other relevant entity-specific events affecting individual reporting units.The Company concluded based on the results of the annual testing performed that the carrying value of goodwill was not impaired as of December 31, 2016. Goodwill of $4.8 million and $8.9 million is included in Noncurrent Assets on the consolidated balance sheets as of December 31, 2016 and 2015, respectively. The following table summarizes the changes in Goodwill for the year ended December 31, 2016 (in thousands): 2016 Beginning Balance, January 1 $ 8,880 Fair Value Adjustments During Measurement Period (See Note 3) (4,042 ) Ending Balance, December 31 $ 4,838 NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2016 , 2015 or 2014 had, or is expected to have, a material impact on the consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition , and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. In connection with this new standard, the FASB has issued several amendments to ASU 2014-09, as follows: • In March 2016, the FASB issued ASU 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) . This standard improves the implementation guidance on principal versus agent considerations and whether an entity reports revenue on a gross or net basis. • In April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing . This standard clarifies identifying performance obligations and the licensing implementation guidance. • In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients . This standard provides additional guidance on (a) the objective of the collectibility criterion, (b) the presentation of sales tax collected from customers, (c) the measurement date of non-cash consideration received, (d) practical expedients in respect of contract modifications and completed contracts at transition, and (e) disclosure of the effects of the accounting change in the period of adoption. • In December 2016, the FASB issued ASU No. 2016-20, Technical Corrections and Improvements to (Topic 606), Revenue from Contracts with Customers , which amends certain narrow aspects of the guidance including the disclosure of remaining performance obligations and prior-period performance obligations, as well as other amendments to the guidance on loan guarantee fees, contract costs, refund liabilities, advertising costs and the clarification of certain examples. The new guidance in ASU 2014-09, as well as all amendments discussed above, is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Management has formed an implementation team that is currently evaluating the impact that adoption of this guidance will have on the Company's financial statement results. Based on the review of customer contracts to date, the Company is not anticipating a material impact to its statements of consolidated income, cash flows or consolidated balance sheets upon adoption. The Company expects to transition to the new guidance using the modified retrospective approach. In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results. In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis , which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results. In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs . This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's results of operations; however, balance sheet presentations were modified to conform to this guidance, as described under "Basis of Presentation" above. Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40) . This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's financial statement results. In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory . This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In January 2016, the FASB issued ASU 2016-01, Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities , which enhances the reporting model for financial instruments and includes amendments to address aspects of recognition, measurement, presentation and disclosure. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017. Early adoption is permitted for only certain portions of the new guidance. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) , which establishes a new lease accounting model for lessees. The new standard requires substantially all leases be recognized by lessees on their balance sheet as a right-of-use asset and corresponding lease liability, including leases currently accounted for as operating leases. The new standard also will result in enhanced quantitative and qualitative disclosures, including significant judgments made by management, to provide greater insight into the extent of revenue and expense recognized and expected to be recognized from existing leases. The accounting for leases by the lessor remains relatively the same. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2018, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In March 2016, the FASB issued ASU 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships . The amendments in this guidance clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In March 2016, the FASB issued ASU 2016-07, Investments- Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting, which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In March 2016, the FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting , which simplifies various aspects of accounting for share-based payment arrangements. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. This standard is intended to provide guidance concerning the classification of certain cash receipts and cash payments in the statement of cash flows and to eliminate the diversity in practice related to such classifications. This standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In October 2016, the FASB issued ASU 2016-16, Income Taxes (Topic 740); Intra-Entity Transfers of Assets Other Than Inventory. This standard requires recognition of the current and deferred income tax effects of an intra-entity asset transfer, other than inventory, when the transfer occurs, as opposed to current GAAP, which requires companies to defer the income tax effects of intra-entity asset transfers until the asset has been sold to an outside party. The income tax effects of intra-entity inventory transfers will continue to be deferred until the inventory is sold. ASU 2016-16 is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within those annual reporting periods, with early adoption permitted. The standard is required to be adopted on a modified retrospective basis with a cumulative-effect adjustment recorded to retained earnings as of the beginning of the period of adoption. Management is currently determining the impact that adoption o

STOCK-BASED COMPENSATION PLAN

STOCK-BASED COMPENSATION PLAN	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
STOCK-BASED COMPENSATION PLAN	STOCK-BASED COMPENSATION PLAN: On April 30, 2015, the shareholders of SJI approved the adoption of the Company's 2015 Omnibus Equity Compensation Plan (Plan), replacing the Amended and Restated 1997 Stock-Based Compensation Plan that had terminated on January 26, 2015. Under the Plan, shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. No options were granted or outstanding during the years ended December 31, 2016 , 2015 and 2014 . No stock appreciation rights have been issued under the plans. During the years ended December 31, 2016 , 2015 and 2014 , SJI granted 194,347 , 158,929 and 136,526 restricted shares, respectively, to Officers and other key employees under the plans. Performance-based restricted shares vest over a three -year period and are subject to SJI achieving certain market and earnings-based performance targets, which can cause the actual amount of shares that ultimately vest to range from 0% to 200% of the original share units granted. Beginning in 2015, SJI began granting time-based shares of restricted stock, one-third of which vests annually over a three -year period and is limited to 100% payout. Vesting of time-based grants is contingent upon SJI achieving a return on equity (ROE) of at least 7% during the initial year of the grant and meeting the service requirement. Provided that the 7% ROE requirement is met in the initial year, payout is solely contingent upon the service requirement being met in years two and three of the grant. In 2016 and 2015, Officers and other key employees were granted 58,304 and 47,678 shares of time-based restricted stock, respectively, which are included in the shares noted above. Grants containing market-based performance targets use SJI's total shareholder return (TSR) relative to a peer group to measure performance. As TSR-based grants are contingent upon market and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant on a straight-line basis over the requisite three-year period of each award. In addition, SJI identifies specific forfeitures of share-based awards, and compensation expense is adjusted accordingly over the requisite service period. Compensation expense is not adjusted based on the actual achievement of performance goals. The fair value of TSR-based restricted stock awards on the date of grant is estimated using a Monte Carlo simulation model. Through 2014, grants containing earnings-based targets were based on SJI's earnings growth rate per share (EGR) relative to a peer group to measure performance. In 2015, earnings-based performance targets included predefined EGR and ROE goals to measure performance. Beginning in 2016, performance targets include pre-defined compounded earnings annual growth rate (CEGR) for SJI. As EGR-based, ROE-based and CEGR-based grants are contingent upon performance and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant over the requisite three-year period of each award. The fair value is measured as the market price at the date of grant. The initial accruals of compensation expense are based on the estimated number of shares expected to vest, assuming the requisite service is rendered and probable outcome of the performance condition is achieved. That estimate is revised if subsequent information indicates that the actual number of shares is likely to differ from previous estimates. Compensation expense is ultimately adjusted based on the actual achievement of service and performance targets. SJI granted 35,197 , 26,338 and 23,220 restricted shares to Directors in 2016 , 2015 and 2014 , respectively. Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest. The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2016 , and the assumptions used to estimate the fair value of the awards: Grants Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate Officers & Key Employees - 2015 - TSR 33,537 $ 26.31 16.0 % 1.10 % 2015 - EGR, ROE, Time 73,118 $ 29.47 N/A N/A 2016 - TSR 66,101 $ 22.53 18.1 % 1.31 % 2016 - CEGR, Time 122,759 23.52 N/A N/A Directors - 2016 35,197 $ 23.88 N/A N/A Expected volatility is based on the actual volatility of SJI’s share price over the preceding three -year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three -year term of the Officers' and other key employees' restricted shares. As notional dividend equivalents are credited to the holders during the three -year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant. The following table summarizes the total stock-based compensation cost for the years ended December 31 (in thousands): 2016 2015 2014 Officers & Key Employees $ 3,051 $ 1,128 $ 1,260 Directors 841 769 633 Total Cost 3,892 1,897 1,893 Capitalized (385 ) (216 ) (147 ) Net Expense $ 3,507 $ 1,681 $ 1,746 The table above reflects the reversal of approximately $0.1 million , $1.2 million and $1.1 million of previously recorded costs in 2016, 2015 and 2014, respectively. These reversals are associated with EPS-based grants for which performance goals were not met. As of December 31, 2016 , there was $4.0 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the plans. That cost is expected to be recognized over a weighted average period of 1.7 years. The following table summarizes information regarding restricted stock award activity during 2016 , excluding accrued dividend equivalents: Officers & Other Key Employees Directors Weighted Average Fair Value Nonvested Shares Outstanding, January 1, 2016 226,191 26,338 $ 26.89 Granted 194,347 35,197 $ 23.28 Vested* (113,917 ) (26,338 ) $ 25.69 Cancelled/Forfeited** (11,106 ) — $ 25.11 Nonvested Shares Outstanding, December 31, 2016 295,515 35,197 $ 24.96 *Based on performance information available at the filing of this Report, management expects to award 29,044 shares associated with the 2014 grants to Officers and other key employees in 2017. ** Represents shares forfeited as a result of separation of employment prior to the satisfaction of service conditions. Performance targets during the three -year vesting periods were not attained for the 2012 or 2013 Officer and other key employee grants that vested at December 31, 2014 and 2015, respectively. As a result, no shares were awarded in 2015 or 2016 associated with those grants. However, the initial performance hurdle for the 2015 time-based grant was met. As a result, 13,247 shares were awarded to Officers and other key employees in 2016 at a market value of $0.3 million . Also, during the years ended December 31, 2016 , 2015 and 2014 , SJI granted 35,197 , 26,338 and 23,220 shares to its Directors at a market value of $0.8 million , $0.8 million and $0.6 million , respectively. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the Plan. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash. At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods. These deferred shares are included in Treasury Stock on the consolidated balance sheets.

AFFILIATIONS AND DISCONTINUED O

AFFILIATIONS AND DISCONTINUED OPERATIONS	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
AFFILIATIONS AND DISCONTINUED OPERATIONS	AFFILIATIONS AND DISCONTINUED OPERATIONS: AFFILIATIONS — The following affiliated entities are accounted for under the equity method: Energenic – US, LLC (Energenic) - Marina and a joint venture partner formed Energenic, in which Marina has a 50% equity interest. Energenic developed and operated on-site, self-contained, energy-related projects. On December 31, 2015, Energenic, Marina and its joint venture partner entered into two Equity Distribution and Purchase Agreements (the "Transaction"), pursuant to which Marina became the sole owner of eight of the Energenic projects ("Marina Projects") and its joint venture partner became the sole owner of seven other Energenic projects ("Partner Projects"). The Transaction has been accounted for as a distribution of member interests by Energenic to its owners and a business combination through the exchange of member interests in various projects between Marina and its joint venture partner. In connection with the exchange, the joint venture partner provided a $19.5 million note payable to Marina. The note and other existing obligations of the joint venture partner to Marina are included in Notes Receivable on the consolidated balance sheets, with approximately $1.5 million being included as a current asset as of December 31, 2016 as it is due within one year. This note is collateralized by security interests in various energy project assets owned by the joint venture partner, as well as personal guarantees from its principals. As part of the transaction, each party is relieved of any guarantees related to the Projects in which it no longer has an ownership interest. The projects that are now wholly-owned by Marina are ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS. Through December 31, 2015, Marina’s investment in Energenic was accounted for under the equity method of accounting. As such, Marina’s share of the equity value of the projects was included within Investment in Affiliates on the consolidated balance sheets and Marina’s share of the loss or earnings from the projects was included within Equity in (Loss) Earnings of Affiliated Companies on the statements of consolidated income for the years ended December 31, 2015 and 2014, respectively. As of December 31, 2015, the assets and liabilities of the projects that are now wholly-owned by Marina are consolidated into the consolidated balance sheets. Beginning in 2016, the respective results from operations and cash flows of the projects that are now wholly-owned by Marina are consolidated into the statements of consolidated income and cash flows, respectively. This transaction represents a non-cash investing and financing activity. The results of the acquired projects are included in the On-Site Energy Production segment. The following table summarizes the final purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.0 million , which represents the fair value of the Company’s interest in the Partner Projects exchanged ( $31.5 million ) as well as the existing value of the Marina Projects immediately prior to the exchange ( $14.5 million ) (in thousands): Current assets (excluding inventory) $ 7,804 Inventory 3,154 Note Receivable Received 19,504 Fixed Assets 46,460 Intangible Assets: Identifiable Intangibles 16,950 Goodwill 4,838 Non-Current Assets 4,783 Current Liabilities (8,196 ) Note Payable - Affiliate (16,986 ) Long-Term Debt, including current portion (21,642 ) Capital Lease Payable (10,458 ) Other Non-Current Liabilities (181 ) Fair Value of Consolidated Assets and Liabilities of Acquired Projects $ 46,030 The pro forma impact of this transaction on the operations of the Company is not significant. Potato Creek, LLC (Potato Creek) - SJI and a joint venture partner formed Potato Creek, in which SJI has a 30% equity interest. Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania. PennEast Pipeline Company, LLC (PennEast) - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 100 -mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, with a target completion of late 2018. The Company made net investments in unconsolidated affiliates of $7.5 million and $18.0 million in 2016 and 2015, respectively. During 2014, the Company provided net advances to unconsolidated affiliates of $2.4 million . As of December 31, 2016 and 2015 , the outstanding balance of Notes Receivable – Affiliate was $15.7 million and $16.4 million , respectively. As of December 31, 2016 , approximately $13.6 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025 , and the remaining $2.1 million of these notes are unsecured and accrue interest at variable rates. SJI holds significant variable interests in these entities but is not the primary beneficiary. Consequently, these entities are accounted for under the equity method because SJI does not have both (a) the power to direct the activities of the entity that most significantly impact the entity’s economic performance and (b) the obligation to absorb losses of the entity that could potentially be significant to the entity or the right to receive benefits from the entity that could potentially be significant to the entity. As of December 31, 2016 , the Company had a net asset of approximately $28.9 million included in Investment in Affiliates on the consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of December 31, 2016 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the aggregate amount of $44.6 million . DISCONTINUED OPERATIONS - Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (EMI), an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996. SJI conducts tests annually to estimate the environmental remediation costs for these properties. Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts): 2016 2015 2014 Loss before Income Taxes: Sand Mining $ (205 ) $ (422 ) $ (620 ) Fuel Oil (179 ) (338 ) (274 ) Income Tax Benefits 133 257 312 Loss from Discontinued Operations — Net $ (251 ) $ (503 ) $ (582 ) Earnings Per Common Share from Discontinued Operations — Net: Basic and Diluted $ — $ (0.01 ) $ (0.01 )

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES: SJI files a consolidated federal income tax return. State income tax returns are filed on a separate company basis in states where SJI has operations and/or a requirement to file. Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for the following reasons (in thousands): 2016 2015 2014 Tax at Statutory Rate $ 60,624 $ 37,440 $ 35,727 Increase (Decrease) Resulting from: State Income Taxes 6,438 3,985 1,960 ESOP Dividend (1,300 ) (1,298 ) (1,232 ) Amortization of Investment Tax Credits - Utility — (149 ) (211 ) AFUDC (900 ) (1,109 ) (1,481 ) Investment and Other Tax Credits (10,706 ) (37,503 ) (30,661 ) Other - Net (5 ) (6 ) 347 Income Taxes: Continuing Operations 54,151 1,360 4,449 Discontinued Operations (133 ) (257 ) (312 ) Total Income Tax Expense $ 54,018 $ 1,103 $ 4,137 The provision for Income Taxes is comprised of the following (in thousands): 2016 2015 2014 Current: Federal $ — $ — $ (62 ) State (1,638 ) (2,352 ) 3,052 Total Current (1,638 ) (2,352 ) 2,990 Deferred: Federal 44,246 (4,622 ) 1,707 State 11,543 8,483 (37 ) Total Deferred 55,789 3,861 1,670 Investment Tax Credit - Utility — (149 ) (211 ) Income Taxes: Continuing Operations 54,151 1,360 4,449 Discontinued Operations (133 ) (257 ) (312 ) Total Income Tax Expense $ 54,018 $ 1,103 $ 4,137 For the year ended December 31, 2016, the Company's overall tax expense increased primarily due to a decrease in the investment tax credits available on renewable energy facilities at Marina, along with higher income before income taxes. Investment Tax Credits attributable to SJG are deferred and amortized at the annual rate of 3.0% , which approximates the life of related assets. The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax assets and liabilities at December 31 (in thousands): 2016 2015 Deferred Tax Assets: Net Operating Loss Carryforward $ 211,004 $ 195,358 Investment and Other Tax Credits 213,946 200,491 Derivatives / Unrealized Gain — 5,652 Deferred State Tax 28,833 24,833 Pension & Other Post Retirement Benefits 19,351 29,998 Deferred Revenues 7,669 4,924 Provision for Uncollectibles 5,231 4,200 Other 8,368 6,448 Total Deferred Tax Asset $ 494,402 $ 471,904 Deferred Tax Liabilities: Book versus Tax Basis of Property $ 732,535 $ 675,521 Deferred Gas Costs - Net 2,052 3,998 Derivatives / Unrealized Loss 1,794 — Environmental Remediation 32,885 19,207 Deferred Regulatory Costs 1,554 566 Budget Billing - Customer Accounts 3,347 830 Deferred Pension & Other Post Retirement Benefits 34,432 42,216 Conservation Incentive Program 11,846 1,132 Equity In Loss Of Affiliated Companies 3,092 9,111 Other 14,414 15,268 Total Deferred Tax Liability $ 837,951 $ 767,849 Deferred Tax Liability - Net $ 343,549 $ 295,945 As of December 31, 2016 , SJI has the following federal and state net operating loss carryforwards (in thousands): Net Operating Loss Carryforwards Expire in: Federal State 2031 $ 163,572 $ 45,866 2032 42,988 19,356 2033 67,496 34,940 2034 119,122 28,622 2035 70,992 9,860 2036 93,508 81,369 $ 557,678 $ 220,013 As of December 31, 2016 , SJI has the following investment tax credit carryforwards (in thousands): Expire in: Investment Tax Credit Carryforward 2030 $ 11,628 2031 25,664 2032 32,071 2033 45,606 2034 37,699 2035 45,097 2036 11,659 $ 209,424 SJI has $1.2 million of federal alternative minimum tax credits which have no expiration date. SJI also has research and development credits of $3.3 million that will expire between 2031 and 2035. A valuation allowance is recorded when it is more likely than not that any of SJI's deferred tax assets will not be realized. SJI believes that it will generate sufficient future taxable income to realize the income tax benefits related to SJI's net deferred tax assets. The total unrecognized tax benefits as of December 31, 2016 , 2015 , and 2014 were $1.4 million , $0.6 million , and $0.6 million , respectively, which excludes $0.7 million , of accrued interest and penalties for each period. A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands): 2016 2015 2014 Balance at January 1, $ 559 $ 552 $ 547 Increase as a result of tax positions taken in prior years 886 7 5 Balance at December 31, $ 1,445 $ 559 $ 552 The amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is not significant. The Company's policy is to record interest and penalties related to unrecognized tax benefits as interest expense and other expense, respectively. These amounts were not significant in 2016 , 2015 or 2014 . The majority of the increased tax position in 2016 is attributable to research and development credits. The Company does not anticipate any significant changes in the total unrecognized tax benefits within the next 12 months. The unrecognized tax benefits are primarily related to an uncertainty of state income tax issues relating to the Company's nexus in certain states and tax credits. Federal income tax returns from 2013 forward and state income tax returns from 2008 forward are open and subject to examination.

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
PREFERRED STOCK	PREFERRED STOCK: REDEEMABLE CUMULATIVE PREFERRED STOCK - SJI has 2,500,000 authorized shares of Preference Stock, no par value, which has not been issued.

COMMON STOCK

COMMON STOCK	12 Months Ended
	Dec. 31, 2016
Common Stock [Abstract]
COMMON STOCK	COMMON STOCK: The following shares were issued and outstanding at December 31 (See Note 1): 2016 2015 2014 Beginning of Year 70,965,622 68,334,860 65,430,084 New Issues During Year: Dividend Reinvestment Plan 417,095 2,604,424 2,881,556 Stock-Based Compensation Plan 45,338 26,338 23,220 Public Equity Offering 8,050,000 — — End of Year 79,478,055 70,965,622 68,334,860 The par value ( $1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value at December 31, 2016 of approximately $207.5 million was recorded in Premium on Common Stock. In May 2016, the Company issued and sold 8,050,000 shares of its common stock, par value $1.25 per share pursuant to a public offering, raising net proceeds of approximately $203.6 million . The net proceeds from this offering were or will be used for capital expenditures, primarily for regulated businesses, including infrastructure investments at its utility business. EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 112,590 , 195,139 , and 150,062 shares for the years ended December 31, 2016 , 2015 and 2014 , respectively. These shares relate to SJI’s restricted stock as discussed in Note 2. DIVIDENDS PER SHARE - Dividends per share were $1.07 , $1.02 and $0.96 for the years ended December 31, 2016 , 2015 and 2014 , respectively. DIVIDEND REINVESTMENT PLAN (DRP) — The Company offered a DRP which allowed participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases, prior to May 1, 2016. Shares of common stock offered by the DRP had been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $10.8 million and $63.2 million of equity capital through the DRP in 2016 and 2015 , respectively. Effective May 1, 2016, SJI switched to purchasing shares on the open market to fund share purchases by DRP participants. SJI does not intend to issue any more new equity capital via the DRP in 2017.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2016
Financial Instruments, Owned, at Fair Value [Abstract]
FINANCIAL INSTRUMENTS	FINANCIAL INSTRUMENTS: RESTRICTED INVESTMENTS —Marina is required to maintain escrow accounts related to ongoing capital projects as well as unused loan proceeds pending approval of construction expenditures. As of December 31, 2016 and 2015 , the escrowed funds, including interest earned, totaled $1.9 million and $3.4 million , respectively. The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy-related contracts with the respective counterparties decrease. As of December 31, 2016 and 2015 , the balances in these accounts totaled $11.7 million and $43.7 million , respectively. As of December 31, 2015, in accordance with an outstanding loan agreement with a third party, ACB was required to maintain control accounts, which included a debt service reserve of $1.7 million . In January 2016, the remaining debt on the loan agreement was paid (see Note 14); accordingly, there was no such reserve as of December 31, 2016. The carrying amounts of the Restricted Investments approximate their fair values at December 31, 2016 and 2015 , which would be included in Level 1 of the fair value hierarchy (see Note 17). INVESTMENT IN AFFILIATES - During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20 -year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex. In June 2014, the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. As of December 31, 2015, the Energenic subsidiaries were providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries had not been able to secure a permanent or long-term energy services agreement with the new owner. In 2015, management of the Company and Energenic evaluated the carrying value of the investment in this project and a related note receivable. Based on the inability of the Energenic subsidiaries to secure a permanent or long-term energy services agreement, the Company r ecorded a $7.7 million (net of tax) no n-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge was included in Equity in Loss of Affiliated Companies for the year ended December 31, 2015 on the statements of consolidated income. The central energy center and energy distribution system owned by the Energenic subsidiaries was financed in part by the issuance of bonds during 2011. These bonds were collateralized primarily by certain assets of the central energy center and revenue from the energy services agreement with the hotel, casino and entertainment complex. During 2015, due to the cessation of normal business operations of the complex and the inability of the Energenic subsidiaries to meet its obligations under the bonds, the trustee for the bondholders filed suit to foreclose on certain assets of the central energy center. In November 2015 during settlement discussions, the bondholders alleged, among other things, that they were entitled to recover from Energenic itself, any amounts owed under the bonds that were not covered by the collateral, including principal, interest and attorney’s fees. The bondholders’ assertion was based on inconsistent language in the bond documents. In January 2016, Energenic and certain subsidiaries reached a multi-party settlement with the bondholders. This agreement resolves all outstanding litigation and transfers ownership of the bondholders’ collateral to the owners of the entertainment complex. The Company's share of this settlement was $7.5 million , which was accrued by Energenic as of December 31, 2015 and paid in 2016. The Company entered into agreements with its insurance carrier and external legal advisors to recover, net of legal costs, approximately $7.0 million of costs associated with the bondholder settlement discussed above. The Company received $2.1 million in the second quarter of 2016, which is included in Other Income on the statements of consolidated income for the year ended December 31, 2016, and $5.3 million was received in the third quarter of 2016 and is included in Equity in Earnings of Affiliated Companies on the statements of consolidated income for the year ended December 31, 2016, as the loss recorded in the prior year was included in this line item on the statements of consolidated income for the year ended December 31, 2015. As of December 31, 2016, the Company, through its investment in Energenic, had a remaining net asset of approximately $0.6 million included in Investment in Affiliates on the consolidated balance sheets related to cogeneration assets for this project. In addition, the Company had approximately $13.6 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from Energenic, which is secured by those cogeneration assets. This note is subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid. Management will continue to monitor the situation surrounding the complex and will evaluate the carrying value of the investment and the note receivable as future events occur. NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The note bore interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. In December 2015 and February 2016, the borrower exercised each option, respectively. In July 2016, the note was repaid in full, including interest. LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over periods ranging from five to ten years, with no interest. The carrying amounts of such loans were $9.5 million and $12.9 million as of December 31, 2016 and 2015 , respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $0.9 million and $1.3 million as of December 31, 2016 and 2015 , respectively. The annual amortization to interest is not material to the Company’s consolidated financial statements. The carrying amounts of these receivables approximate their fair value at December 31, 2016 and 2015 , which would be included in Level 2 of the fair value hierarchy (see Note 17). CREDIT RISK - As of December 31, 2016 , approximately $9.3 million or 11.5% of current and noncurrent Derivatives–Energy Related Assets are transacted with three counterparties, all of which are investment-grade-rated. FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJI's financial instruments approximate their fair values at December 31, 2016 and 2015 , except as noted below. • For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJI at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy, see Note 17). The estimated fair values of SJI's long-term debt, including current maturities, as of December 31, 2016 and 2015 , were $1,080.8 million and $1,079.0 million , respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of December 31, 2016 and 2015 , was $1,039.9 million and $1,026.9 million , respectively. The carrying amounts as of December 31, 2016 and 2015 are net of unamortized debt issuance costs of $7.6 million and $9.0 million , respectively (see Note 1). OTHER FINANCIAL INSTRUMENTS - The carrying amounts of SJI's other financial instruments approximate their fair values at December 31, 2016 and 2015 .

SEGMENTS OF BUSINESS

SEGMENTS OF BUSINESS	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
SEGMENTS OF BUSINESS	SEGMENTS OF BUSINESS: SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. These segments are as follows: • Gas utility operations (SJG) consist primarily of natural gas distribution to residential, commercial and industrial customers. • Wholesale energy operations include the activities of SJRG and SJEX. • SJE is involved in both retail gas and retail electric activities. ◦ Retail gas and other operations include natural gas acquisition and transportation service business lines. ◦ Retail electric operations consist of electricity acquisition and transportation to commercial, industrial and residential customers. • On-Site energy production consists of Marina’s thermal energy facility and other energy-related projects. Included in this segment are the activities of the following significant entities: ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS. These entities became wholly-owned subsidiaries of Marina on December 31, 2015 (see Note 3). • Appliance service operations includes SJESP, which services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. • Midstream was formed to invest in infrastructure and other midstream projects, including a current project to build a natural gas pipeline in Pennsylvania and New Jersey. The activities of Midstream are a part of the Corporate and Services segment. SJI groups its nonutility operations into two categories: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices. Information about SJI’s operations in different reportable operating segments is presented below (in thousands): 2016 2015 2014 Operating Revenues: Gas Utility Operations $ 461,055 $ 534,290 $ 501,875 Energy Group: Wholesale Energy Operations 220,707 129,098 77,048 Retail Gas and Other Operations 92,371 87,198 127,001 Retail Electric Operations 182,540 150,049 123,773 Subtotal Energy Group 495,618 366,345 327,822 Energy Services: On-Site Energy Production 94,375 63,665 56,129 Appliance Service Operations 7,898 11,186 10,518 Subtotal Energy Services 102,273 74,851 66,647 Corporate & Services 35,147 31,156 30,174 Subtotal 1,094,093 1,006,642 926,518 Intersegment Sales (57,593 ) (47,074 ) (39,522 ) Total Operating Revenues $ 1,036,500 $ 959,568 $ 886,996 2016 2015 2014 Operating Income: Gas Utility Operations $ 122,455 $ 119,585 $ 113,690 Energy Group: Wholesale Energy Operations 41,667 35,024 9,493 Retail Gas and Other Operations 4,680 (3,218 ) 479 Retail Electric Operations 7,007 1,042 (466 ) Subtotal Energy Group 53,354 32,848 9,506 Energy Services: On-Site Energy Production 13,301 2,027 2,560 Appliance Service Operations 582 468 362 Subtotal Energy Services 13,883 2,495 2,922 Corporate and Services (416 ) 1,966 1,485 Total Operating Income $ 189,276 $ 156,894 $ 127,603 Depreciation and Amortization: Gas Utility Operations $ 63,901 $ 58,668 $ 52,155 Energy Group: Wholesale Energy Operations 484 435 168 Retail Gas and Other Operations 337 161 83 Subtotal Energy Group 821 596 251 Energy Services: On-Site Energy Production 43,395 30,242 25,020 Appliance Service Operations 301 316 269 Subtotal Energy Services 43,696 30,558 25,289 Corporate and Services 1,400 1,220 816 Total Depreciation and Amortization $ 109,818 $ 91,042 $ 78,511 Interest Charges: Gas Utility Operations $ 17,875 $ 19,906 $ 17,872 Energy Group: Wholesale Energy Operations — 441 371 Retail Gas and Other Operations 350 185 267 Subtotal Energy Group 350 626 638 Energy Services: On-Site Energy Production 11,961 8,169 8,723 Corporate and Services 12,118 11,822 8,803 Subtotal 42,304 40,523 36,036 Intersegment Borrowings (10,855 ) (8,901 ) (6,476 ) Total Interest Charges $ 31,449 $ 31,622 $ 29,560 2016 2015 2014 Income Taxes: Gas Utility Operations $ 39,366 $ 36,945 $ 34,895 Energy Group: Wholesale Energy Operations 15,882 14,410 4,822 Retail Gas and Other Operations 2,118 (978 ) 787 Retail Electric Operations 2,862 426 (190 ) Subtotal Energy Group 20,862 13,858 5,419 Energy Services: On-Site Energy Production (6,353 ) (49,225 ) (36,404 ) Appliance Service Operations 232 186 223 Subtotal Energy Services (6,121 ) (49,039 ) (36,181 ) Corporate and Services 44 (404 ) 316 Total Income Taxes $ 54,151 $ 1,360 $ 4,449 Property Additions: Gas Utility Operations $ 228,275 $ 218,260 $ 201,737 Energy Group: Wholesale Energy Operations 7 382 18 Retail Gas and Other Operations 1,642 2,053 1,421 Subtotal Energy Group 1,649 2,435 1,439 Energy Services: On-Site Energy Production (1) 38,193 139,018 132,214 Appliance Service Operations 431 379 84 Subtotal Energy Services 38,624 139,397 132,298 Corporate and Services 1,141 1,902 3,995 Total Property Additions $ 269,689 $ 361,994 $ 339,469 (1) The property additions for On-Site Energy Production in 2016 and 2015 do not include the approximately $5.6 million and $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3. 2016 2015 Identifiable Assets (See Note 1): Gas Utility Operations $ 2,551,923 $ 2,281,576 Energy Group: Wholesale Energy Operations 233,019 231,660 Retail Gas and Other Operations 52,729 55,111 Retail Electric Operations 41,280 55,528 Subtotal Energy Group 327,028 342,299 Energy Services: On-Site Energy Production 767,710 790,231 Appliance Service Operations 2,879 4,885 Subtotal Energy Services 770,589 795,116 Discontinued Operations 1,756 1,545 Corporate and Services 649,795 652,325 Intersegment Assets (570,524 ) (600,928 ) Total Identifiable Assets $ 3,730,567 $ 3,471,933

LEASES

LEASES	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
LEASES	LEASES: Marina is considered to be the lessor of certain thermal energy generating property and equipment under an operating lease which expires in May 2027 . As of December 31, 2016 and 2015 , the carrying costs of this property and equipment under operating lease was $75.9 million and $78.2 million , respectively (net of accumulated depreciation of $31.4 million and $28.5 million , respectively), and is included in Nonutility Property and Equipment in the consolidated balance sheets. Minimum future rentals to be received on this operating lease of property and equipment as of December 31, 2016 for each of the next five years and in the aggregate are (in thousands): Year ended December 31, 2017 $ 5,396 2018 5,396 2019 5,396 2020 5,396 2021 5,396 Thereafter 29,230 Total minimum future rentals 56,210 Minimum future rentals do not include additional amounts to be received based on actual use of the leased property. BCLE was considered to be the lessee of certain electric generating units and related facilities and equipment under a capital lease which was set to expire in October 2027. The interest rate related to the obligation was 6.8% , and the related facilities and equipment were being amortized over the useful life ranging from 7 - 39 years. As of December 31, 2015, the carrying costs of this property and equipment under capital lease was $4.1 million and was included in Nonutility Property and Equipment in the consolidated balance sheets. On December 31, 2016, BCLE terminated the lease and purchased the respective assets for $10.6 million . Total accumulated depreciation taken on this capital lease, prior to termination, was $0.2 million as of December 31, 2016 ; no depreciation was taken on this lease by Marina as of December 31, 2015.

RATES AND REGULATORY ACTIONS

RATES AND REGULATORY ACTIONS	12 Months Ended
	Dec. 31, 2016
Public Utilities, General Disclosures [Abstract]
RATES AND REGULATORY ACTIONS	RATES AND REGULATORY ACTIONS: BASE RATES - SJG is subject to the rules and regulations of the BPU. In September 2014, the BPU granted SJG a base rate increase of $20.0 million , which was predicated, in part, upon a 7.10% rate of return on rate base that included a 9.75% return on common equity. The $20.0 million includes approximately $7.5 million of revenue associated with previously approved Accelerated Infrastructure Replacement Program (AIRP) investments that were rolled into base rates. SJG was also permitted to recover certain regulatory assets and to reduce its composite depreciate rate from 2.4% to 2.1% . These changes became effective on October 1, 2014. In January 2017, SJG filed a base rate case with the BPU to increase its base rates in order to obtain a return on new capital investments made by SJG since the settlement of its last base rate case in 2014. SJG expects the base rate case to be concluded during 2017 (see Note 19). RATE MECHANISMS - SJG's tariff, a schedule detailing the terms, conditions and rate information applicable to its various types of natural gas service, as approved by the BPU, has several primary rate mechanisms as discussed in detail below: Basic Gas Supply Service (BGSS) Clause - The BGSS price structure allows SJG to recover all prudently incurred gas costs. BGSS charges to customers can be either monthly or periodic (annual). Monthly BGSS charges are applicable to large use customers and are referred to as monthly because the rate changes on a monthly basis pursuant to a BPU-approved formula based on commodity market prices. Periodic BGSS charges are applicable to lower usage customers, which include all of SJG's residential customers, and are evaluated at least annually by the BPU. However, to some extent, more frequent rate changes to the periodic BGSS are allowed. SJG collects gas costs from customers on a forecasted basis and defers periodic over/under recoveries to the following BGSS year, which runs from October 1 through September 30. If SJG is in a net cumulative undercollected position, gas costs deferrals are reflected on the balance sheet as a regulatory asset. If SJG is in a net cumulative overcollected position, amounts due back to customers are reflected on the balance sheet as a regulatory liability. SJG pays interest on net overcollected BGSS balances at the rate of return on rate base utilized by the BPU to set rates in the last base rate proceeding. Regulatory actions regarding the BGSS were as follows: • January 2014 - SJG credited the accounts of its periodic BGSS customer with refunds totaling $11.2 million due to gas costs that were lower than projected. • May 2014 - SJG filed its annual BGSS filing with the BPU requesting a $27.0 million , or a 9.3% increase in gas cost recoveries. • September 2014 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $27.0 million increase in gas cost recoveries. • June 2015 - SJG filed its annual BGSS filing with the BPU, requesting a $28.4 million decrease in gas cost recoveries. • September 2015 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $28.4 million decrease in gas cost recoveries. • January 2016 - SJG provided a BGSS bill credit of approximately $20.0 million to its residential and small commercial customers. This credit was in addition to the overall rate reduction that was approved by the BPU and took effect in 2015. • June 2016 - SJG filed its annual BGSS filing with the BPU, requesting a $47.1 million decrease in gas cost recoveries. • September 2016 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $47.1 million decrease in gas cost recoveries, effective October 2016. • December 2016 - SJG provided a BGSS bill credit of approximately $10.0 million to its residential and small commercial customers. The credit was in addition to the overall rate reduction that was approved by the BPU and took effect in October 2016. Conservation Incentive Program (CIP) - The primary purpose of the CIP is to promote conservation efforts, without negatively impacting financial stability, and to base SJG's profit margin on the number of customers rather than the amount of natural gas distributed to customers. Each CIP year begins October 1 and ends September 30 of the subsequent year. On a monthly basis during the CIP year, SJG records adjustments to earnings based on weather and customer usage factors, as incurred. Subsequent to each year, SJG makes filings with the BPU to review and approve amounts recorded under the CIP. BPU-approved cash inflows or outflows generally will not begin until the next CIP year. Regulatory actions regarding the CIP were as follows: • May 2014 - SJG made its annual CIP filing with the BPU requesting a revenue reduction of $21.8 million , which includes a $4.2 million increase in non-weather related revenues and a $26.0 million reduction in weather related revenues. • September 2014 - The BPU issued an Order approving, on a provisional basis, the 2014-2015 CIP rates filed in May 2014, effective October 1 2014. • June 2015 - SJG filed its annual CIP filing with the BPU, requesting a decrease in revenues of $11.3 million , which includes a $8.8 million decrease in non-weather related revenues and a $2.5 million decrease in weather related revenues. • September 2015 - The BPU issued an Order approving, on a provisional basis, the 2015-2016 CIP rates filed in June 2015, effective October 1, 2015. • June 2016 - SJG filed its annual CIP filing with the BPU, requesting a $46.5 million increase in revenues, which includes a $9.9 million increase in non-weather related revenues and a $36.6 million increase in weather related revenues. • September 2016 - The BPU issued an Order approving, on a provisional basis, the 2016-2017 CIP rates filed in June 2016, effective October 2016. Accelerated Infrastructure Replacement Program (AIRP) - In February 2013, the BPU issued an Order approving a $141.2 million program to replace cast iron and unprotected bare steel mains and services over a four -year period, with annual investments of approximately $35.3 million . Pursuant to the Order, AIRP investments are to be reviewed and included in rate base in future base rate proceedings. Regulatory actions regarding AIRP were as follows: • September 2014 - The BPU approved SJG’s base rate case, which included a $7.5 million increase in revenues associated with the roll in of $69.9 million of AIRP investments, inclusive of $3.2 million of AFUDC, into base rates. • February 2016 - SJG filed a petition with the BPU for approval to continue its AIRP, which was set to expire at the end of 2016. In its petition, SJG requested to extend the AIRP for an additional seven years with program investments totaling approximately $500.0 million . In its Petition, SJG also requested to increase revenues by $13.0 million to reflect in base rates all AIRP investments made from the time of SJG’s last base rate case to the end of the initial AIRP. • October 2016 - The BPU issued an Order approving an extension of the AIRP for a five -year period (“AIRP II”), commencing October 1, 2016, with authorized investments of up to $302.5 million to continue replacing cast iron and unprotected bare steel mains and associated services. The BPU also approved an $11.0 million increase in revenues associated with the roll in of $80.2 million of AIRP investments, inclusive of $5.7 million of AFUDC, into base rates, effective December 1, 2016. Storm Hardening and Reliability Program (SHARP) - In September 2013, SJG filed with the BPU an asset hardening program pursuant to which SJG will invest approximately $280.0 million over seven years to replace low pressure distribution mains and services with high pressure mains and services in coastal areas that are susceptible to flooding during major storm events. Regulatory actions regarding SHARP were as follows: • August 2014 - The BPU approved the SHARP, authorizing SJG to invest $103.5 million over three years for system hardening on barrier islands. SJG will earn a return on these investments as they are made and will reflect the investments in base rates through annual rate adjustments. • April 2015 - SJG filed a petition seeking a base rate adjustment to increase annual revenues by approximately $4.0 million to reflect approximately $36.6 million of SHARP investments made from July 2014 through June 2015. • September 2015 - The BPU approved SJG’s request to increase annual revenues from base rates by $4.0 million , effective October 1, 2015. • April 2016 - SJG filed a petition seeking a base rate adjustment to increase annual revenues by approximately $4.3 million to reflect approximately $33.7 million of SHARP investments made from July 2015 through June 2016. • September 2016 - The BPU approved an increase in annual revenues from base rates of $3.9 million to reflect the roll-in of $33.7 million of SHARP investments made from July 2015 through June 2016, effective October 1, 2016. Energy Efficiency Tracker (EET) - Under this program, SJG was permitted to invest $17.0 million over two years in energy efficiency measures to be installed in customer homes and businesses. SJG also recovered incremental operating and maintenance expenses and earn a return of, and return on, program investments. In June 2013, the BPU authorized SJG to continue to offer Energy Efficiency Programs (EEPs) through June 2015 with an approved budget of $24.0 million . In August 2015, the BPU approved a two -year extension of SJG’s EEPs through August 31, 2017, with a program budget of $36.3 million . Regulatory actions regarding the EET/EEP were as follows: • May 2014 - SJG filed its annual EET rate adjustment petition requesting a $1.4 million increase in revenues to recover the costs of, and the allowed return on, prior investments associated with energy efficiency programs. • September 2014 - The BPU approved a revenue increase of $2.2 million associated with the 2012-2013 annual EET rate adjustment filing, with rates effective October 1, 2014. • January 2015 - SJG filed a petition with the BPU seeking to continue offering energy efficiency programs through June 2018 with a proposed budget of $56.0 million and with the same rate recovery mechanism that exists for its current EEPs. • June 2015, SJG filed its annual EET rate adjustment petition, requesting a $7.6 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with EEPs. • August 2015, the BPU approved a two -year extension of SJG's EEPs through August 31, 2017, with a program budget of $36.3 million . The BPU’s approval permitted SJG to adjust its EET rate, effective September 1, 2015, to increase annual revenues by $2.6 million , to recover projected costs and the allowed return on the first year of its investments in the EEP extension. • February 2016 - The BPU approved a revenue decrease of $7.9 million associated with the two most recent annual EET rate adjustment filings, effective April 1, 2016. • June 2016 - SJG filed its annual EET rate adjustment petition, requesting a $0.8 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with EEPs. • October 2016 - The BPU approved a revenue decrease of $1.6 million associated with SJG's annual EET rate adjustment filing, effective November 10, 2016. • November 2016 - SJG filed a letter petition requesting an extension of its current Energy Efficiency Program (“EEP III”) through December 31, 2018, allowing SJG to spend the remainder of its existing BPU approved budget over the extended term. The BPU approved this extension in January 2017. Societal Benefits Clause (SBC) - The SBC allows SJG to recover costs related to several BPU-mandated programs. Within the SBC are a Remediation Adjustment Clause (RAC), a New Jersey Clean Energy Program (NJCEP) and a Universal Service Fund (USF) program. Regulatory actions regarding the SBC, with the exception of USF, which requires separate regulatory filings, were as follows: • July 2014 - SJG made its annual 2014-2015 SBC filing requesting a $25.7 million decrease in SBC revenues. The BPU approved this filing in May 2015. • July 2015 - SJG made its annual 2015-2016 SBC filing, requesting a $5.0 million decrease in SBC revenues. The BPU approved this filing in April 2016. • July 2016 - SJG made its annual 2016-2017 SBC filing, requesting a $16.0 million increase in SBC revenues. This petition is currently pending. Remediation Adjustment Clause (RAC) - The RAC recovers environmental remediation costs of 12 former gas manufacturing plants (see Note 15). The BPU allows SJG to recover such costs over seven -year amortization periods. The net between the amounts actually spent and amounts recovered from customers is recorded as a regulatory asset, "Environmental Remediation Cost Expended - Net." RAC activity affects revenue and cash flows but does not directly affect earnings because of the cost recovery over seven -year amortization periods. As of December 31, 2016 and 2015 , SJG reflected the unamortized remediation costs of $72.0 million and $42.0 million , respectively, on the consolidated balance sheets under Regulatory Assets (see Note 11). Since implementing the RAC in 1992, SJG has recovered $112.7 million through rates. Clean Energy Program Clause (CLEP) - A component of the SBC, the CLEP recovers costs associated with state mandated NJCEP as it relates to SJG's energy efficiency and renewable energy programs. In June 2013, the BPU approved a NJCEP funding level of $345.0 million through June 2014, of which SJG was responsible for $14.5 million . In June 2014, the BPU approved a NJCEP funding level of $345.0 million through June 2015, of which SJG was responsible for $14.5 million . In June 2015, the BPU approved a NJCEP funding level of $345.0 million through June 2016, of which SJG was responsible for $14.6 million . In June of 2016, the BPU approved a NJCEP funding level of $345.0 million through June 2017, of which SJG was responsible for $14.6 million . CLEP adjustments affect revenue and cash flows but do not directly affect earnings as related costs are deferred and recovered through rates on an on-going basis. Universal Service Fund (USF) - The USF is a statewide program through which funds for the USF and Lifeline Credit and Tenants Assistance Programs are collected from customers of all New Jersey electric and gas utilities. USF adjustments affect cash flows but do not directly affect revenue or earnings as related costs are deferred and recovered through rates on an on-going basis. Separate regulatory actions regarding the USF were as follows: • June 2014 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to increase the statewide gas revenues by $19.9 million . This proposal was designed to increase SJG’s annual USF revenue by $2.6 million . • September 2014 - The BPU approved the statewide budget of $71.8 million for all the State’s gas utilities. SJG's portion of the total is approximately $7.9 million , which increased rates effective October 1, 2014, resulting in a $2.6 million increase to its USF recoveries. • June 2015 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to decrease the statewide gas revenues by $46.4 million . This proposal was designed to decrease SJG’s annual USF revenue by $3.4 million . • September 2015 - The BPU approved the statewide budget of $46.4 million for all the State’s gas utilities. SJG's portion of the total is approximately $5.2 million , which decreased rates effective October 1, 2015, resulting in a $3.4 million decrease to its USF recoveries. • June 2016 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to increase the statewide gas revenues by $56.0 million . This proposal was designed to increase SJG’s annual USF revenue by $1.1 million . • September 2016 - The BPU approved the statewide budget of $56.0 million for all the State’s gas utilities. SJG's portion of the total is approximately $5.6 million , which increased rates effective October 1, 2016, resulting in a $1.1 million increase to its USF recoveries. Other Regulatory Matters - Unbundling - This allows all natural gas consumers to select their natural gas commodity supplier. As of December 31, 2016 , 33,467 of SJG's customers were purchasing their gas commodity from someone other than SJG. Customers choosing to purchase natural gas from providers other than the utility are charged for the cost of gas by the marketer. The resulting decrease in utility revenues is offset by a corresponding decrease in gas costs. While customer choice can reduce utility revenues, it does not negatively affect SJG's net income or financial condition. The BPU continues to allow for full recovery of prudently incurred natural gas costs through the BGSS. Unbundling did not change the fact that SJG still recovers cost of service, including certain deferred costs, through base rates. Pipeline Integrity Costs - SJG is permitted to defer and recover incremental costs incurred as a result of Pipeline Integrity Management regulations, which are aimed at enhancing public safety and reliability. The regulations require that utilities use a comprehensive analysis to assess, evaluate, repair and validate the integrity of certain transmission lines in the event of a leak or failure. As part of SJG's 2014 base rate case, it was permitted to recover previously deferred pipeline integrity costs incurred from October 2010 through June 2014. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in the next base rate proceeding, subject to review by the BPU. As of December 31, 2016 and 2015 , deferred pipeline integrity costs totaled $4.0 million and $2.7 million , respectively, and are included in other regulatory assets (see Note 11). Filings and petitions described above are still pending, unless otherwise indicated.

REGULATORY ASSETS & REGULATORY

REGULATORY ASSETS & REGULATORY LIABILITIES	12 Months Ended
	Dec. 31, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
REGULATORY ASSETS & REGULATORY LIABILITIES	REGULATORY ASSETS & REGULATORY LIABILITIES: The discussion under Note 10, Rates and Regulatory Actions, is integral to the following explanations of specific regulatory assets and liabilities. Regulatory Assets consisted of the following items (in thousands): December 31, 2016 December 31, 2015 Environmental Remediation Costs: Expended - Net $ 71,997 $ 42,032 Liability for Future Expenditures 153,047 123,194 Deferred Asset Retirement Obligation Costs 43,014 42,430 Deferred Pension and Other Postretirement Benefit Costs 85,693 79,779 Deferred Gas Costs - Net — 2,701 Conservation Incentive Program Receivable 27,567 2,624 Deferred Interest Rate Contracts 7,365 7,631 Energy Efficiency Tracker 219 496 Pipeline Supplier Service Charges 2,122 3,776 Pipeline Integrity Cost 4,810 4,596 AFUDC - Equity Related Deferrals 12,434 11,423 Other Regulatory Assets 2,478 2,752 Total Regulatory Assets $ 410,746 $ 323,434 Except where noted below, all regulatory assets are or will be recovered through utility rate charges, as detailed in the following discussion. SJG is currently permitted to recover interest on Environmental Remediation Costs, Societal Benefit Costs Receivable, Energy Efficiency Tracker and Pipeline Integrity Costs, while the other assets are being recovered without a return on investment. Environmental Remediation Costs - SJG has two regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or its predecessors previously operated gas manufacturing plants. The first asset, "Environmental Remediation Cost: Expended - Net," represents what was actually spent to clean up the sites, less recoveries through the RAC and insurance carriers. These costs meet the deferral requirements of GAAP as the BPU allows SJG to recover such expenditures through the RAC. The other asset, "Environmental Remediation Cost: Liability for Future Expenditures," relates to estimated future expenditures required to complete the remediation of these sites. SJG recorded this estimated amount as a regulatory asset with the corresponding current and noncurrent liabilities on the consolidated balance sheets under the captions "Current Liabilities" and "Deferred Credits and Other Noncurrent Liabilities." The BPU allows SJG to recover the deferred costs over seven -year periods after they are spent. The increase from December 31, 2015 is a result of expenditures made during 2016 and an increase in the expected future expenditures for remediation activities, primarily due to an increase in the scope of the remediation at a site related to additional contamination being discovered. Deferred Asset Retirement Obligation (ARO) Costs - This regulatory asset resulted from the recording of ARO and additional utility plant, primarily related to a legal obligation SJG has for certain safety requirements upon the retirement of its gas distribution and transmission system. SJG recovers asset retirement costs through rates charged to customers. All related accumulated accretion and depreciation amounts for these ARO represent timing differences in the recognition of retirement costs that SJG is currently recovering in rates and, as such, SJG is deferring such differences as regulatory assets. Deferred Pension and Other Postretirement Benefit Costs - The BPU authorized SJG to recover costs related to postretirement benefits under the accrual method of accounting consistent with GAAP. SJG's regulatory asset represents the recognition of the underfunded positions of SJG's pension and other postretirement benefit plans. Subsequent adjustments to this balance occur annually to reflect changes in the funded positions of these benefit plans caused by changes in actual plan experience as well as assumptions of future experience (see Note 12). Deferred Gas Costs - Net - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability (see Note 10). Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval (see Note 16). Conservation Incentive Program Receivable - The impact of the CIP is recorded as an adjustment to earnings as incurred, while cash recovery under the CIP generally occurs during the subsequent CIP year (see Note 10). Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 16. Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program. Pipeline Supplier Service Charges - This regulatory asset represents costs necessary to maintain adequate supply and system pressures, which are being recovered on a monthly basis through the BGSS over the term of the underlying supplier contracts (see Note 10). Pipeline Integrity Cost - As part of SJG's September 2014 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2014. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in SJG's next base rate proceeding, subject to review by the BPU (see Note 10). AFUDC Equity Related Deferrals - This regulatory asset represents the future revenue to recover the future income taxes related to the deferred tax liability for the equity component of AFUDC. Included in the balance is $1.0 million which is being recovered over a period of three years as approved by the BPU in SJG’s 2014 rate case settlement. The remaining balance is being amortized over the life of the associated utility plant. Other Regulatory Assets - Some of the assets included in Other Regulatory Assets are currently being recovered from ratepayers as approved by the BPU. Management believes the remaining deferred costs are probable of recovery from ratepayers through future utility rates. Regulatory Liabilities consisted of the following items (in thousands): December 31, 2016 December 31, 2015 Excess Plant Removal Costs $ 28,226 $ 32,644 Deferred Revenue - Net 17,800 — Societal Benefit Costs Payable 3,095 10,197 Total Regulatory Liabilities $ 49,121 $ 42,841 Excess Plant Removal Costs - Represents amounts accrued in excess of actual utility plant removal costs incurred to date. As part of SJG's September 2014 base rate increase, SJG is required to amortize approximately $1.1 million of this balance to depreciation expense each year. Deferred Revenue - Ne t - The BGSS changed from a $2.7 million regulatory asset at December 31, 2015 to a $17.8 million regulatory liability at December 31, 2016, primarily due to the gas costs recovered from customers exceeding the actual cost of the commodity. See previous discussion under "Deferred Gas Costs - Net" above. Societal Benefit Costs Payable - This regulatory liability primarily represents cumulative costs less recoveries under the USF and CLEP programs (see Note 10).

PENSION AND OTHER POSTRETIREMEN

PENSION AND OTHER POSTRETIREMENT BENEFITS	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
PENSION AND OTHER POSTRETIREMENT BENEFITS	PENSION AND OTHER POSTRETIREMENT BENEFITS: SJI has several defined benefit pension plans and other postretirement benefit plans. Approximately 38.2% of the Company's current, full-time, regular employees will be entitled to annuity payments upon retirement. Participation in the Company's qualified defined benefit pension plans was closed to new employees beginning in 2003; however, employees who are not eligible for these pension plans are eligible to receive an enhanced version of SJI's defined contribution plan. Certain SJI officers also participate in a non-funded supplemental executive retirement plan (SERP), a non-qualified defined benefit pension plan. The other postretirement benefit plans provide health care and life insurance benefits to some retirees. Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands): Pension Benefits 2016 2015 2014 Service Cost $ 4,843 $ 5,337 $ 4,510 Interest Cost 12,125 11,168 10,735 Expected Return on Plan Assets (13,508 ) (14,789 ) (13,491 ) Amortizations: Prior Service Cost 212 212 175 Actuarial Loss 9,394 10,608 5,716 Net Periodic Benefit Cost 13,066 12,536 7,645 Capitalized Benefit Costs (4,645 ) (4,805 ) (3,047 ) Deferred Benefit Costs (645 ) (1,007 ) — Total Net Periodic Benefit Expense $ 7,776 $ 6,724 $ 4,598 Other Postretirement Benefits 2016 2015 2014 Service Cost $ 851 $ 1,116 $ 891 Interest Cost 2,615 2,973 2,852 Expected Return on Plan Assets (3,104 ) (2,993 ) (2,603 ) Amortizations: Prior Service (Credits) Cost (344 ) 608 152 Actuarial Loss 1,109 1,342 974 Net Periodic Benefit Cost 1,127 3,046 2,266 Capitalized Benefit Costs (277 ) (1,043 ) (722 ) Deferred Benefit Costs — (256 ) — Total Net Periodic Benefit Expense $ 850 $ 1,747 $ 1,544 Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to the deferral of incremental expenses associated with the adoption of new mortality tables in 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case. Companies with publicly traded equity securities that sponsor a postretirement benefit plan are required to fully recognize, as an asset or liability, the overfunded or underfunded status of its benefit plans and recognize changes in the funded status in the year in which the changes occur. Changes in funded status are generally reported in Other Comprehensive Loss; however, since SJG recovers all prudently incurred pension and postretirement benefit costs from its ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this requirement are reported as regulatory assets (see Note 11). Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands): Regulatory Assets Accumulated Other Comprehensive Loss (pre-tax) Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Balance at January 1, 2015 $ 71,177 $ 27,863 $ 39,468 $ 6,755 Amounts Arising during the Period: Net Actuarial (Loss)/Gain (463 ) (3,155 ) 59 (2,285 ) Prior Service Cost (499 ) (106 ) Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (6,079 ) (1,107 ) (4,452 ) (221 ) Prior Service Cost (203 ) (7,755 ) (9 ) (2,081 ) Balance at December 31, 2015 64,432 15,347 35,066 2,062 Amounts Arising during the Period: Net Actuarial Gain 9,706 2,584 8,370 829 Prior Service Credit — 257 — 84 Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (5,485 ) (945 ) (3,838 ) (154 ) Prior Service Cost (203 ) — (8 ) — Balance at December 31, 2016 $ 68,450 $ 17,243 $ 39,590 $ 2,821 The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2017 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 127 $ (257 ) Net Actuarial Loss $ 6,202 $ 1,040 The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2017 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 5 $ (87 ) Net Actuarial Loss $ 3,943 $ 207 A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands): Pension Benefits Other Postretirement Benefits 2016 2015 2016 2015 Change in Benefit Obligations: Benefit Obligation at Beginning of Year $ 254,195 $ 265,434 $ 57,430 $ 75,592 Service Cost 4,843 5,337 851 1,116 Interest Cost 12,125 11,168 2,615 2,973 Actuarial Loss (Gain) 18,254 (17,349 ) 3,121 (8,591 ) Retiree Contributions — — 81 700 Plan Amendments — — — (9,899 ) Benefits Paid (11,129 ) (10,395 ) (3,748 ) (4,461 ) Benefit Obligation at End of Year $ 278,288 $ 254,195 $ 60,350 $ 57,430 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Year $ 184,824 $ 180,523 $ 47,759 $ 43,222 Actual Return on Plan Assets 13,569 (2,321 ) 2,784 (423 ) Employer Contributions 2,278 17,017 3,656 8,721 Retiree Contributions — — 81 700 Benefits Paid (11,129 ) (10,395 ) (3,748 ) (4,461 ) Fair Value of Plan Assets at End of Year $ 189,542 $ 184,824 $ 50,532 $ 47,759 Funded Status at End of Year: $ (88,746 ) $ (69,371 ) $ (9,818 ) $ (9,671 ) Amounts Related to Unconsolidated Affiliate 326 204 540 509 Accrued Net Benefit Cost at End of Year $ (88,420 ) $ (69,167 ) $ (9,278 ) $ (9,162 ) Amounts Recognized in the Statement of Financial Position Consist of: Current Liabilities $ (2,463 ) $ (2,261 ) $ — $ — Noncurrent Liabilities (85,957 ) (66,906 ) (9,278 ) (9,162 ) Net Amount Recognized at End of Year $ (88,420 ) $ (69,167 ) $ (9,278 ) $ (9,162 ) Amounts Recognized in Regulatory Assets Consist of: Prior Service Costs $ 538 $ 741 $ (3,032 ) $ (3,289 ) Net Actuarial Loss 67,912 63,691 20,275 18,636 $ 68,450 $ 64,432 $ 17,243 $ 15,347 Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax): Prior Service Costs $ 69 $ 77 $ (989 ) $ (1,074 ) Net Actuarial Loss 39,521 34,989 3,810 3,136 $ 39,590 $ 35,066 $ 2,821 $ 2,062 The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of SJI's qualified employee pension plans were $224.3 million and $208.3 million , respectively, as of December 31, 2016 ; and $207.7 million and $191.9 million , respectively, as of December 31, 2015 . The ABO of these plans exceeded the value of the plan assets as of December 31, 2016 and 2015. The value of these assets were $189.5 million and $184.8 million as of December 31, 2016 and 2015 , respectively, and can be seen in the table above. The PBO and ABO for SJI's non-funded SERP were $53.9 million and $51.9 million , respectively, as of December 31, 2016 ; and $46.5 million and $45.0 million , respectively, as of December 31, 2015 . The SERP obligation is reflected in the tables above and has no assets. The weighted-average assumptions used to determine benefit obligations at December 31 were: Pension Benefits Other Postretirement Benefits 2016 2015 2016 2015 Discount Rate 4.30 % 4.83 % 4.13 % 4.73 % Rate of Compensation Increase 3.50 % 3.50 % 3.50 % 3.50 % The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were: Pension Benefits Other Postretirement Benefits 2016 2015 2014 2016 2015 2014 Discount Rate 4.83 % 4.25 % 5.09 % 4.73 % 4.20 % 4.91 % Expected Long-Term Return on Plan Assets 7.50 % 7.75 % 7.75 % 6.50 % 6.25 % 6.25 % Rate of Compensation Increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % In 2014, the Society of Actuaries (SOA) released new mortality tables (RP-2014 base table with MP-2014 generational projection scale), which indicated that the average life expectancy of both active and retired plan participants had increased. Obligations as of December 31, 2014, disclosed herein reflect the use of those new tables. In 2015, the SOA released an update to the RP-2014 tables (MP-2015 base tables), slightly reducing the average life expectancy previously released. The obligations as of December 31, 2016 and 2015, disclosed herein, reflect the use of the updated 2015 tables. While the adoption of the new tables impacts liabilities significantly as of December 31of the year of adoption, the impact on expense did not occur until the subsequent year. The discount rates used to determine the benefit obligations at December 31, 2016 and 2015 , which are used to determine the net periodic benefit cost for the subsequent year, were based on a portfolio model of high-quality investments with maturities that match the expected benefit payments under our pension and other postretirement benefit plans. The expected long-term return on plan assets (“return”) has been determined by applying long-term capital market projections provided by our pension plan Trustee to the asset allocation guidelines, as defined in the Company's investment policy, to arrive at a weighted average return. For certain other equity securities held by an investment manager outside of the control of the Trustee, the return has been determined based on historic performance in combination with long-term expectations. The return for the other postretirement benefits plan is determined in the same manner as discussed above; however, the expected return is reduced based on the taxable nature of the underlying trusts. The retiree medical plan changed effective January 1, 2016. Retirees are provided a fixed contribution to a health reimbursement account, allowing them to obtain coverage from health-care exchanges, rather than utilizing the Company provided health-care plan. Since the health-care benefits are now a fixed dollar amount under the new plan and will not increase in the future, the plan no longer has health care trend assumptions as of December 31, 2015. As a result, assumed health care cost trend rates no longer have a significant effect on the amounts reported for SJI's postretirement health care plans. PLAN ASSETS - The Company's overall investment strategy for pension plan assets is to achieve a diversification by asset class, style of manager, and sector and industry limits to achieve investment results that match the actuarially assumed rate of return, while preserving the inflation adjusted value of the plans. The Company has implemented this diversification strategy primarily with commingled common/collective trust funds. The target allocations for pension plan assets are 28 - 48 percent U.S. equity securities, 13 - 25 percent international equity securities, 32 - 42 percent fixed income investments, and 0 - 7 percent to all other types of investments. Equity securities include investments in commingled common/collective trust funds as well as large-cap and mid-cap companies. Fixed income securities include commingled common/collective trust funds, group annuity contracts for pension payments, and hedge funds. Other types of investments include investments in private equity funds and real estate funds that follow several different strategies. The strategy recognizes that risk and volatility are present to some degree with all types of investments. We seek to avoid high levels of risk at the total fund level through diversification by asset class, style of manager, and sector and industry limits. Specifically prohibited investments include, but are not limited to, venture capital, margin trading, commodities and securities of companies with less than $250.0 million capitalization (except in the small-cap portion of the fund where capitalization levels as low as $50.0 million are permissible). These restrictions are only applicable to individual investment managers with separately managed portfolios and do not apply to mutual funds or commingled trusts. SJI evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2016 . Types of concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, and individual fund. As of December 31, 2016 , there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in SJI's pension and other postretirement benefit plan assets. GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. This hierarchy groups assets into three distinct levels, as fully described in Note 17, which will serve as the basis for presentation throughout the remainder of this Note. The fair values of SJI's pension plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2016 Cash / Cash Equivalents: Cash $ 63 $ 63 $ — $ — Common/Collective Trust Funds (a) 460 — 460 — STIF-Type Instrument (b) 1,431 — 1,431 — Equity securities: Common/Collective Trust Funds - U.S. (a) 51,902 — 51,902 — Common/Collective Trust Funds - International (a) 33,096 — 33,096 — U.S. Large-Cap (c) 17,792 17,792 — — U.S. Mid-Cap (c) 2,479 2,479 — — International (c) 3,340 3,340 — — Fixed Income: Common/Collective Trust Funds (a) 54,970 — 54,970 — Guaranteed Insurance Contract (d) 9,714 — — 9,714 Other types of investments: Private Equity Fund (f) 5,100 — — 5,100 Common/Collective Trust Fund - Real Estate (g) 9,195 — — 9,195 Total $ 189,542 $ 23,674 $ 141,859 $ 24,009 Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash / Cash Equivalents: Cash $ 35 $ 35 $ — $ — Common/Collective Trust Funds (a) 858 — 858 — STIF-Type Instrument (b) 1,360 — 1,360 — Equity securities: Common/Collective Trust Funds - U.S. (a) 52,058 — 52,058 — Common/Collective Trust Funds - International (a) 33,236 — 33,236 — U.S. Large-Cap (c) 14,305 14,305 — — U.S. Mid-Cap (c) 3,407 3,407 — — U.S. Small-Cap (c) 260 260 — — International (c) 1,695 1,695 — — Fixed Income: Common/Collective Trust Funds (a) 50,664 — 50,664 — Guaranteed Insurance Contract (d) 9,960 — — 9,960 Hedge Funds (e) 4,159 — — 4,159 Other types of investments: Private Equity Fund (f) 4,312 — — 4,312 Common/Collective Trust Fund - Real Estate (g) 8,515 — — 8,515 Total $ 184,824 $ 19,702 $ 138,176 $ 26,946 (a) This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. (b) This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements. Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information. Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments. (c) This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy. These common stocks are actively traded on exchanges and price quotes for these shares are readily available. These common stocks are classified as Level 1 investments. (d) This category represents SJI's Group Annuity contracts with a nationally recognized life insurance company. The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder. Valuation is based on a formula and calculation specified within the contract. Since the valuation is based on the reporting entity's own assumptions, these contracts are classified as Level 3 investments. (e) This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments. (f) This category represents a limited partnership/commingled trust which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments. Fund investments are illiquid and resale is restricted. These funds are classified as Level 3 investments. (g) This category represents real estate common/collective trust fund investments through a commingled employee benefit trust. These commingled funds are part of a direct investment in a pool of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals from sources with professional qualifications. Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments. Fair Value Measurement Using Significant Unobservable Inputs (Level 3) (In thousands) Guaranteed Private Insurance Hedge Equity Real Contract Funds Funds Estate Total Balance at January 1, 2015 $ 10,912 $ 4,331 $ 3,616 $ 7,476 $ 26,335 Actual return on plan assets: Relating to assets still held at the reporting date (106 ) (172 ) (302 ) 1,039 459 Relating to assets sold during the period 25 — 429 — 454 Purchases, Sales and Settlements (871 ) — 569 — (302 ) Balance at December 31, 2015 9,960 4,159 4,312 8,515 26,946 Actual return on plan assets: Relating to assets still held at the reporting date 541 (67 ) (140 ) 680 1,014 Relating to assets sold during the period 14 — 245 — 259 Purchases, Sales and Settlements (801 ) (4,092 ) 683 — (4,210 ) Balance at December 31, 2016 $ 9,714 $ — $ 5,100 $ 9,195 $ 24,009 As with the pension plan assets, the Company's overall investment strategy for post-retirement benefit plan assets is to achieve a diversification by asset class, style of manager, and sector and industry limits to achieve investment results that match the actuarially assumed rate of return, while preserving the inflation adjusted value of the plans. The Company has implemented this diversification strategy with a mix of common/collective trust funds, mutual funds and Company-owned life insurance policies. The target allocations for post-retirement benefit plan assets are 30 - 43 percent U.S. equity securities, 20 - 30 percent international equity securities, and 32 - 42 percent fixed income investments and 0 - 7 percent to all other types of investments. Equity securities include investments in large-cap, mid-cap and small-cap companies within mutual funds or common/collective trust funds. Fixed income securities within the common/collective trust fund include primarily investment grade, U.S. Government and mortgage-backed financial instruments. The insurance policies are backed by a series of commingled trust investments held by the insurance carrier. The fair values of SJI's other postretirement benefit plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2016: Cash $ — $ — $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 14,878 $ — $ 14,878 $ — Common/Collective Trust Funds - International (a) 8,674 — 8,674 — Fixed Income: Common/Collective Trust Funds - Bonds (a) 13,537 — 13,537 — Other Types of Investments: Company Owned Life Insurance (c) 13,443 — 13,443 — Total $ 50,532 $ — $ 50,532 $ — Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015: Cash $ 26 $ 26 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 13,522 $ — $ 13,522 $ — Common/Collective Trust Funds - International (a) 8,313 — 8,313 — Mutual Fund - U.S. (b) 1,309 1,309 — — Mutual Funds - International (b) 983 983 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 13,187 — 13,187 — Mutual Funds - Bonds (b) 1,441 1,441 — — Other Types of Investments: Mutual Funds - REITS (b) 152 152 — — Company Owned Life Insurance (c) 8,826 — 8,826 — Total $ 47,759 $ 3,911 $ 43,848 $ — (a) This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. (b) This category represents mutual fund investments. The mutual funds are actively traded on exchanges and price quotes for the shares are readily available. These mutual funds are classified as Level 1 investments. (c) This category represents Company-owned life insurance policies with a nationally known life insurance company. The value of these policies is backed by a series of common/collective trust funds held by the insurance carrier similar to category (a) above. Holdings in these insurance policies are classified as Level 2 investments. FUTURE BENEFIT PAYMENTS - The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following years (in thousands): Pension Benefits Other Postretirement Benefits 2017 $ 12,141 $ 4,399 2018 $ 12,583 $ 4,316 2019 $ 13,529 $ 4,403 2020 $ 14,056 $ 4,514 2021 $ 14,757 $ 4,511 2022 - 2025 $ 86,727 $ 21,308 CONTRIBUTIONS - SJI contributed $15.0 million to the pension plans in 2015, with no pension contribution made in 2016 or 2014. Payments related to the unfunded SERP plan in 2016, 2015 and 2014 were $2.3 million , $2.0 million and $1.5 million , respectively. SERP payments are expected to approximate $2.5 million in 2017. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to its other postretirement benefit plans’ trusts, less costs incurred directly by SJG. DEFINED CONTRIBUTION PLAN - SJI offers an Employees' Retirement Savings Plan (Savings Plan) to eligible employees. For employees eligible for participation in SJI's defined benefit pension plan, SJI matches 50% of participants' contributions up to 6% of base compensation. For employees who are not eligible for participation in SJI's defined benefit pension plans, SJI matches 50% of participants' contributions up to 8% of base compensation. Employees not eligible for the pension plans also receive a year-end contribution of $1,500 , if 10 or fewer years of service, or $2,000 , if more than 10 years of service. The amount expensed and contributed for the matching provision of the Savings Plan approximated $2.3 million , $2.1 million and $2.0 million for the years ended December 31, 2016 , 2015 and 2014 , respectively.

LINES OF CREDIT

LINES OF CREDIT	12 Months Ended
	Dec. 31, 2016
Line of Credit Facility [Abstract]
LINES OF CREDIT	LINES OF CREDIT: Credit facilities and available liquidity as of December 31, 2016 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 105,100 (A) $ 94,900 May 2018 Uncommitted Bank Lines 10,000 — 10,000 August 2017 Total SJG 210,000 105,100 104,900 SJI: Revolving Credit Facility 450,000 196,600 (B) 253,400 Various (C) Total SJI 450,000 196,600 253,400 Total $ 660,000 $ 301,700 $ 358,300 (A) Includes letters of credit outstanding in the amount of $0.8 million . (B) Includes letters of credit outstanding in the amount of $4.8 million . (C) In September 2016, the Company entered into an unsecured $50.0 million , 364 -day revolving credit agreement. The agreement matures September 2017, at which time the principal and any accrued but unpaid interest must be paid. At the annual request of the Company, but on not more than two occasions, the credit agreement may be extended for an additional period of 364 days. The 364 -day revolving facility bears interest at a variable base rate or a variable London Interbank Offered Rate (“LIBOR”), at the Company’s election. The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.47% , 1.13% and 0.83% at December 31, 2016 , 2015 and 2014 , respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $321.9 million and $335.0 million , respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2016 and 2015 were $467.7 million and $471.1 million , respectively. The SJI and SJG facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1 , measured at the end of each fiscal quarter. SJG has a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million . The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes. SJG uses the commercial paper program in tandem with the new $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million .

LONG-TERM DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT: Outstanding Long-Term Debt at December 31 consisted of the following: 2016 2015 Long-Term Debt (A): South Jersey Gas Company: First Mortgage Bonds: (B) 5.437% Series due 2016 (C) $ — $ 10,000 4.6% Series due 2016 (C) — 17,000 4.657% Series due 2017 15,000 15,000 7.97% Series due 2018 10,000 10,000 7.125% Series due 2018 20,000 20,000 5.587% Series due 2019 10,000 10,000 3.00% Series due 2024 (D) 50,000 50,000 3.03% Series due 2024 (E) 35,000 35,000 3.63% Series due 2025 (F) 8,182 9,091 4.84% Series due 2026 (G) 15,000 15,000 4.93% Series due 2026 (H) 45,000 45,000 4.03% Series due 2027 45,000 45,000 4.01% Series due 2030 (I) 50,000 50,000 4.23% Series due 2030 30,000 30,000 3.74% Series due 2032 35,000 35,000 5.55% Series due 2033 32,000 32,000 6.213% Series due 2034 10,000 10,000 5.45% Series due 2035 10,000 10,000 Series A 2006 Bonds at variable rates due 2036 (J) 24,900 24,900 SJG Term Facility (K) 200,000 139,000 Marina Energy LLC: (L) Series A 2001 Bonds at variable rates due 2031 20,000 20,000 Series B 2001 Bonds at variable rates due 2021 25,000 25,000 Series A 2006 Bonds at variable rates due 2036 16,400 16,400 South Jersey Industries: 2.71% Series B 2012 Notes due 2017 (M) 16,000 16,000 3.05% Series due 2019 60,000 60,000 3.05% Series due 2019 30,000 30,000 3.05% Series due 2019 50,000 50,000 3.46% Series C 2012 Notes due 2022 35,000 35,000 Series Notes at variable rates due 2019 (N) 40,000 40,000 Series Notes at variable rates due 2019 (N) 60,000 60,000 South Jersey Industries Term Loan at variable rates due 2020 (O) 50,000 50,000 ACB Energy Partners, LLC: 7.60 % Loan & Security Agreement (P) — 12,735 Other Energy Project Debt (Q): 4.83 % ACLE — 3,551 4.83 % SCLE — 1,738 4.83 % SXLE — 3,433 Total Long-Term Debt Outstanding (R) $ 1,047,482 $ 1,035,848 Less Current Maturities (231,909 ) (29,454 ) Total Long-Term Debt (R) $ 815,573 $ 1,006,394 (A) Long-term debt maturities for the succeeding five years are as follows (in thousands): 2017: $231,909 ; 2018: $38,909 ; 2019: $258,909 ; 2020: $67,909 ; and 2021: $52,909 . (B) The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. In January 2017, the First Mortgage was amended and restated in its entirety (see Note 19). (C) In July 2016, SJG retired $17.0 million of 4.60% Medium Term Notes (MTN's) at maturity. In August 2016, SJG retired $10.0 million of 5.437% MTN's at maturity. (D) SJG has $50.0 million of 3.00% MTN's, with $10.0 million due annually beginning September 2020 with the final payment due September 2024. (E) SJG has $35.0 million of 3.03% MTN's, with $7.0 million due annually beginning November 2020 with the final payment due November 2024. (F) SJG pays $0.9 million annually toward the principal amount of 3.63% MTN's, with the final payment to be made December 2025. As such, $0.9 million of the total outstanding amount on this debt is classified in current portion of long-term debt on the consolidated balance sheets as it is due within one year. (G) SJG has $15.0 million of 4.84% MTN's, with $2.5 million due annually beginning March 2021 with the final payment due March 2026. (H) SJG has $45.0 million of 4.93% MTN's, with $7.5 million due annually beginning June 2021 with the final payment due June 2026. (I) SJG has $50.0 million of 4.01% MTN's with several due dates, as follows: $8.0 million each due November 2018 and 2019; $2.0 million due November 2025; $3.0 million due November 2026; $8.0 million due November 2027; and $7.0 million each due November 2028, 2029 and 2030. (J) These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2016 was 0.74% . Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August 2018. These bonds contain no financial covenants. (K) SJG had a $200.0 million multiple-draw term facility offered by a syndicate of banks which was set to expire in June 2017. This facility bore interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of December 31, 2015, SJG had borrowed an aggregate $139.0 million under this facility at an average interest rate of 1.17% and the proceeds were used to pay down short-term debt. In January 2016, SJG issued an additional $61.0 million of long-term debt at an average interest rate of 1.41% under this facility. As such, the total outstanding amount under this facility as of December 31, 2016 was $200.0 million , which was classified in current portion of long-term debt on the consolidated balance sheets as it was due within one year. In January 2017, this term facility was paid in full (see Note 19). (L) Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2016 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.72% , 0.73% and 0.72% respectively. The interest rate on all but $46.1 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026. These bonds contain no financial covenants. Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March 2018. (M) As of December 31, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017, are classified in current portion of long-term debt on the consolidated balance sheets. SJI plans to pay off this debt at maturity. (N) At December 31, 2016 , the floating rate on these Senior Notes was 2.32% . (O) In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million , which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2016 was 1.79% . (P) ACB had a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million . Under the LSA, ACB paid principal and interest (at a fixed rate of 7.60% ) in equal quarterly installments that began in February 2011 and was scheduled to run through February 2021. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In January 2016, the Company paid $12.7 million to retire outstanding debt. (Q) ACLE, SCLE and SXLE (the "Other Energy Projects") had long-term debt agreements with a third party to borrow up to $10.0 million . Under the debt agreements, the Other Energy Projects paid principal and interest (at a fixed rate of 4.83% ) in equal installments that began December 2013 and was scheduled to run through December 2020. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the outstanding debt of $8.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In August 2016, the Company paid an aggregate $8.3 million to retire outstanding long-term debt for the Other Energy Projects. (R) Total Long-Term Debt in the table above does not include unamortized debt issuance costs of $7.6 million and $9.0 million for the years ended December 31, 2016 and 2015, respectively, which were reclassified to Long-Term Debt on the consolidated balance sheets to conform to ASU 2015-03 (see Note 1). In December 2015, SJG filed a petition with the BPU to issue up to $400.0 million of long term debt securities in various forms including MTN's and unsecured debt, with maturities of more than 12 months, over the next three years. This petition was approved in March 2016.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES: GAS SUPPLY CONTRACTS - In the normal course of business, SJG and SJRG have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The transportation and storage service agreements with interstate pipeline suppliers were made under FERC approved tariffs. SJRG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services is approximately $0.5 million per month. SJG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services averages approximately $5.6 million per month and is recovered on a current basis through the BGSS. SJRG has also committed to purchase a minimum of 745,000 dts/d and up to 940,000 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index based prices. PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary. The Company is currently involved in a pricing dispute related to two long-term gas supply contracts whereby the Company had sued the supplier to recover amounts that were improperly invoiced. Subsequently, the supplier countersued the Company claiming it is owed an amount which we extrapolate to be $14.9 million from SJG, plus interest, and $40.2 million from SJRG, plus interest, through December 31, 2016 . We believe any monies received or paid associated with the SJG claims would reflect gas costs that would be recovered from SJG's customers through adjusted rates. The Company is also involved in a dispute related to a three -year capacity management contract with a counterparty whereby the Company is the manager. The counterparty is claiming that it is owed approximately $13.3 million , plus interest, from SJRG under a sharing credit within the contract. Liabilities related to these claims are accrued when the amount or range of amounts of probable settlement costs or other charges for these claims can be reasonably estimated. The Company has accrued approximately $3.1 million and $3.2 million related to all claims in the aggregate as of December 31, 2016 and 2015 , respectively. Although the Company does not presently believe that these matters will have a material adverse effect on its business, given the inherent uncertainties in such situations, the Company can provide no assurance regarding the outcome of litigation. COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 45.0% of our workforce at December 31, 2016 . The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76. SJG and SJESP employees represented by the IBEW operate under collective bargaining agreements that run through February 2018. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017. GUARANTEES - As of December 31, 2016 , SJI, the parent company, has issued guarantees to third parties on behalf of its consolidated subsidiaries. These guarantees were issued to guarantee payment to third parties with whom SJI's consolidated subsidiaries have commodity supply contracts and for Marina's construction and operating activities. As of December 31, 2016 , these guarantees support future firm commitments of SJI's consolidated subsidiaries and $125.4 million of the Accounts Payable already recorded on SJI's consolidated balance sheet. As of December 31, 2016 , SJI had issued $6.0 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas. STANDBY LETTERS OF CREDIT — As of December 31, 2016 , SJI provided $4.8 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. SJG provided a $0.8 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. The Company also provided $87.5 million of additional letters of credit under separate facilities outside of the revolving credit facilities to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project. ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage. SJI successfully entered into settlements with all of its historic comprehensive general liability carriers regarding the environmental remediation expenditures at the SJG sites. Also, SJG had purchased a Cleanup Cost Cap Insurance Policy limiting the amount of remediation expenditures that SJG was required to make at 11 of its sites. This policy provided coverage up to $50.0 million , which was exhausted in 2012. Since the early 1980s, SJI accrued environmental remediation costs of $437.1 million , of which $282.1 million was spent as of December 31, 2016 . The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands): 2016 2015 Beginning of Year $ 126,623 $ 128,172 Accruals 60,713 19,489 Expenditures (32,323 ) (21,038 ) End of Year $ 155,013 $ 126,623 The balances are segregated between current and noncurrent on the consolidated balance sheets under the captions Current Liabilities and Deferred Credits and Other Noncurrent Liabilities. Management estimates that undiscounted future costs to clean up SJG's sites will range from $153.0 million to $257.1 million . Six of SJG's sites comprise the majority of these estimates, the sum of the six sites range from a low of $141.2 million to a high of $246.7 million . SJG recorded the lower end of this range as a liability because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue. Recorded amounts include estimated costs based on projected investigation and remediation work plans using existing technologies. Actual costs could differ from the estimates due to the long-term nature of the projects, changing technology, government regulations and site-specific requirements. Significant risks surrounding these estimates include unforeseen market price increases for remedial services, property owner acceptance of remedy selection, regulatory approval of selected remedy and remedial investigative findings. The remediation efforts at SJG's six most significant sites include the following: Site 1 - Several interim remedial actions have been completed at the site. Steps remaining to remediate the balance of the site include selection of the remedial action, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy, long-term groundwater monitoring, and issuance of a Response Action Outcome. Site 2 - Various remedial investigation activities have been completed at this site and a final site remedy has been approved by the regulatory authority. The first phase of remedial action is underway and preparation for the next step is ongoing. Remaining steps to remediate the site include continued implementation of the approved remedy, long-term groundwater monitoring, and issuance of a Response Action Outcome. Site 3 - Various remedial investigation activities have been completed at this site and a final site remedy is being developed for proposal to the regulatory authority. Steps remaining to remediate the site include s election of a final remedy, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy, long term groundwater monitoring, and issuance of a Response Action Outcome. Site 4 - Remedial investigation activities are complete at this site and a final remedy has been approved by the regulatory authority. Steps remaining to remediate the site include installation of a sub-surface containment unit, post remediation groundwater monitoring, and issuance of a Response Action Outcome. Site 5 -The remedial action to address impacted soil at the site is ongoing. Steps remaining include long-term groundwater monitoring and issuance of a Response Action Outcome. Site 6 - Remedial investigation activities have been completed at this site and a final site remedy is being developed for proposal to the regulatory authority. Steps remaining to remediate the site include selection of a final remedy, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy and issuance of a Response Action Outcome. With Morie's sale in 1996, EMI assumed responsibility for environmental liabilities currently estimated between $1.3 million and $2.1 million . The information available on these sites is sufficient only to establish a range of probable liability and no point within the range is more likely than any other. Therefore, EMI has accrued the lower end of the range. Changes in the accrual are included in the statements of consolidated income under Loss from Discontinued Operations. SJI and SJF estimate their potential exposure for the future remediation of five sites where fuel oil operations existed years ago to range from $0.7 million to $1.3 million . The lower end of this range has been recorded under Current Liabilities and Deferred Credits and Other Noncurrent Liabilities as of December 31, 2016 .

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVE INSTRUMENTS	DERIVATIVE INSTRUMENTS: Certain SJI subsidiaries are involved in buying, selling, transporting and storing natural gas and buying and selling retail electricity for their own accounts as well as managing these activities for third parties. These subsidiaries are subject to market risk on expected future purchases and sales due to commodity price fluctuations. The Company uses a variety of derivative instruments to limit this exposure to market risk in accordance with strict corporate guidelines. These derivative instruments include forward contracts, swap agreements, options contracts and futures contracts. As of December 31, 2016 , the Company had outstanding derivative contracts intended to limit the exposure to market risk on 67.9 MMdts of expected future purchases of natural gas, 62.1 MMdts of expected future sales of natural gas, 2.3 MMmwh of expected future purchases of electricity and 1.7 MMmwh of expected future sales of electricity. In addition to these derivative contracts, the Company has basis and index related purchase and sales contracts totaling 141.6 MMdts. These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives — Energy Related Assets or Derivatives — Energy Related Liabilities on the consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility. As part of its gas purchasing strategy, SJG uses financial contracts through SJRG to limit exposure to forward price risk. The costs or benefits of these short-term contracts are recoverable through SJG's BGSS clause, subject to BPU approval. The retail gas operations of SJE transact commodities on a physical basis and typically does not directly enter into positions that financially settle. SJRG performs this risk management function for SJE and enters into the types of financial transactions noted above. The retail electric operations of SJE use forward physical and financial contracts to mitigate commodity price risk on fixed price electric contracts. Management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in identifying, assessing and controlling various risks. Management reviews any open positions in accordance with strict policies to limit exposure to market risk. The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, some of which have been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the consolidated balance sheets. Hedge accounting has been discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously recorded in Accumulated Other Comprehensive Loss (AOCL) on the consolidated balance sheets, are being recorded into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026. As of December 31, 2016 , SJI's active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type of Debt Obligor $ 14,500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 330,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 12,500,000 3.530% 12/1/2006 2/1/2036 Tax-exempt SJG $ 12,500,000 3.430% 12/1/2006 2/1/2036 Tax-exempt SJG The unrealized gains and losses on interest rate derivatives that are not designated as cash flow hedges are included in Interest Charges. However, for selected interest rate derivatives at SJG, management believes that, subject to BPU approval, the market value upon termination can be recovered in rates and, therefore, these unrealized losses have been included in Other Regulatory Assets in the consolidated balance sheets. The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP 2016 2015 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current $ 72,391 $ 60,082 $ 83,093 $ 90,708 Derivatives – Energy Related – Non-Current 8,502 4,540 16,238 21,697 Interest rate contracts: Derivatives - Other - Current — 681 — — Derivatives - Other - Non-Current — 9,349 — 10,943 Total derivatives not designated as hedging instruments under GAAP 80,893 74,652 99,331 123,348 Total Derivatives $ 80,893 $ 74,652 $ 99,331 $ 123,348 The Company enters into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. The Company presents derivatives at gross fair values on the consolidated balance sheets. As of December 31, 2016 and 2015 , information related to these offsetting arrangements were as follows (in thousands): As of December 31, 2016 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets $ 80,893 $ — $ 80,893 $ (38,809 ) (A) $ (3,474 ) $ 38,610 Derivatives - Energy Related Liabilities $ (64,622 ) $ — $ (64,622 ) $ 38,809 (B) $ — $ (25,813 ) Derivatives - Other $ (10,030 ) $ — $ (10,030 ) $ — $ — $ (10,030 ) As of December 31, 2015 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets $ 99,331 $ — $ 99,331 $ (35,491 ) (A) $ — $ 63,840 Derivatives - Energy Related Liabilities $ (112,405 ) $ — $ (112,405 ) $ 35,491 (B) $ 23,045 $ (53,869 ) Derivatives - Other $ (10,943 ) $ — $ (10,943 ) $ — $ — $ (10,943 ) (A) The balances at December 31, 2016 and 2015 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at December 31, 2016 and 2015 were related to derivative assets which can be net settled against derivative liabilities. The effect of derivative instruments on the statements of consolidated income and comprehensive income for the year ended December 31 is as follows (in thousands): Derivatives in Cash Flow Hedging Relationships 2016 2015 2014 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — Losses reclassified from AOCL into income (a) $ (333 ) $ (551 ) $ (419 ) Losses recognized in income on ineffective portion (a) $ — $ — $ — (a) Included in Interest Charges Derivatives Not Designated as Hedging Instruments under GAAP 2016 2015 2014 Gains (losses) on energy-related commodity contracts (a) $ 26,935 $ 8,401 $ (6,592 ) Gains (losses) on interest rate contracts (b) 647 96 (467 ) Total $ 27,582 $ 8,497 $ (7,059 ) (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges Net realized (losses) gains associated with SJG’s energy-related financial commodity contracts of $(3.0) million , $(9.1) million and $1.7 million for the years ended 2016 , 2015 and 2014 , respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy-related financial commodity contracts are deferred in Regulatory Assets or Liabilities, as applicable, and there is no impact on earnings. Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on December 31, 2016 , is $9.6 million . If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2016 , the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $8.1 million after offsetting asset positions with the same counterparties under master netting arrangements.

FAIR VALUE OF FINANCIAL ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES: GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. The levels of the hierarchy are described below: • Level 1: Observable inputs, such as quoted prices in active markets for identical assets or liabilities. • Level 2: Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly; these include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active. • Level 3: Unobservable inputs that reflect the reporting entity’s own assumptions. Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of financial assets and financial liabilities and their placement within the fair value hierarchy. For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands): As of December 31, 2016 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 32 $ 32 $ — $ — Derivatives – Energy Related Assets (B) 80,893 33,994 11,814 35,085 $ 80,925 $ 34,026 $ 11,814 $ 35,085 Liabilities Derivatives – Energy Related Liabilities (B) $ 64,622 $ 16,502 $ 22,070 $ 26,050 Derivatives – Other (C) 10,030 — 10,030 — $ 74,652 $ 16,502 $ 32,100 $ 26,050 As of December 31, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 14,810 $ 2,925 $ 11,885 $ — Derivatives – Energy Related Assets (B) 99,331 16,006 24,730 58,595 $ 114,141 $ 18,931 $ 36,615 $ 58,595 Liabilities Derivatives – Energy Related Liabilities (B) $ 112,405 $ 42,170 $ 11,008 $ 59,227 Derivatives – Other (C) 10,943 — 10,943 — $ 123,348 $ 42,170 $ 21,951 $ 59,227 (A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy. (B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forward contracts, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. (C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands, except for ranges): Type Fair Value at December 31, 2016 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 23,301 $ 18,109 Discounted Cash Flow Forward price (per dt) $1.03 - $11.33 (A) Forward Contract - Electric $ 11,784 $ 7,941 Discounted Cash Flow Fixed electric load profile (on-peak) 21.43% - 100.00% (B) Fixed electric load profile (off-peak) 0.00% - 78.57% (B) Type Fair Value at December 31, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 29,459 $ 31,733 Discounted Cash Flow Forward price (per dt) $(0.77) - $10.00 [$2.15] (A) Forward Contract - Electric $ 29,136 $ 27,494 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.20%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.80%] (B) (A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas. (B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak. The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2016 and 2015 , using significant unobservable inputs (Level 3), are as follows (in thousands): Year Ended December 31, 2016 Balance at January 1, 2016 $ (632 ) Other changes in fair value from continuing and new contracts, net 5,657 Transfers in to/(out of) of Level 3 (A) 4,116 Settlements (106 ) Balance at December 31, 2016 $ 9,035 Year Ended December 31, 2015 Balance at January 1, 2015 $ (5,608 ) Other changes in fair value from continuing and new contracts, net (5,069 ) Transfers in to/(out of) of Level 3 (A) 7,402 Settlements 2,643 Balance at December 31, 2015 $ (632 ) (A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the years ended December 31, 2016 and 2015, $4.1 million and $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management. Total gains for 2016 included in earnings for the year ended December 31, 2016 that are attributable to the change in unrealized gains relating to those assets and liabilities included in Level 3 still held as of December 31, 2016 , are $5.7 million . These gains are included in Operating Revenues-Nonutility on the statements of consolidated income.

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL)	ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL): The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2016 (in thousands): Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Other Comprehensive Income (Loss) of Affiliated Companies Total Balance at January 1, 2016 (a) $ (22,145 ) $ (2,129 ) $ (128 ) $ (97 ) $ (24,499 ) Other comprehensive income before reclassifications (5,617 ) — 323 — (5,294 ) Amounts reclassified from AOCL (b) 2,420 197 (205 ) — 2,412 Net current period other comprehensive income (3,197 ) 197 118 — (2,882 ) Balance at December 31, 2016 (a) $ (25,342 ) $ (1,932 ) $ (10 ) $ (97 ) $ (27,381 ) (a) Determined using a combined average statutory tax rate of 40% . (b) See table below. The following table provides details about reclassifications out of AOCL for the year ended December 31, 2016 (in thousands): Amounts Reclassified from AOCL Affected Line Item in the Statements of Consolidated Income For the Year Ended December 31, 2016 Actuarial Loss on Postretirement Benefits $ 4,001 Operating Expenses: Operations Income Taxes (1,581 ) Income Taxes (a) $ 2,420 Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 333 Interest Charges Income Taxes (136 ) Income Taxes (a) $ 197 Unrealized Gain on Available-for-Sale Securities $ (342 ) Other Income Income Taxes 137 Income Taxes (a) $ (205 ) Losses from reclassifications for the period net of tax $ 2,412 (a) Determined using a combined average statutory tax rate of 40% .

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS: In January 2017, SJG entered into a Supplemental Indenture Amending and Restating First Mortgage Indenture (the “New Mortgage”), which amended and restated in its entirety that Indenture of Mortgage dated October 1, 1947 (see Note 14). The New Mortgage provides for the issuance by SJG of bonds, notes or other securities that are secured by a lien on substantially all of the operating properties and franchises of SJG. In January 2017, SJG issued $200.0 million aggregate principal amount of MTN's, Series E, 2017, due January 2047, with principal payments beginning in 2025. The MTN's bear interest at an annual rate of 3.0% payable semiannually. Proceeds were used to pay down the $200.0 million multiple-draw term facility which was set to expire in June 2017. In January 2017, SJG entered into an unsecured, $200.0 million term loan credit agreement ("Credit Agreement"), which is syndicated among seven banks. Term loans under the Credit Agreement bear interest at a variable base rate or a variable LIBOR rate, at SJG's election. Under the Credit Agreement, SJG can borrow up to an aggregate of $200.0 million until July 2018, of which SJG borrowed $73.0 million on January 31, 2017. All loans under the Credit Agreement become due in January 2019. In January 2017, SJG filed a base rate case with the BPU to increase its base rates in order to obtain a return on new capital investments made by SJG since the settlement of its last base rate case in 2014. SJG expects the base rate case to be concluded during 2017.

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	Quarterly Financial Data (Unaudited) (Summarized quarterly results of SJI's operations, in thousands except for per share amounts) 2016 Quarter Ended 2015 Quarter Ended March 31 June 30 Sept. 30 Dec. 31 March 31 June 30 Sept. 30 Dec. 31 Operating Revenues $ 333,035 $ 154,402 $ 219,082 $ 329,981 $ 382,952 $ 177,710 $ 141,062 $ 257,844 Expenses: Cost of Sales - (Excluding depreciation) 152,975 98,340 142,988 186,684 241,707 90,945 99,124 127,566 Operations and Maintenance Including Fixed Charges 73,042 71,034 69,410 77,858 71,279 62,634 63,867 71,148 Income Taxes 39,267 (7,189 ) 2,807 19,266 16,613 (3,279 ) (10,968 ) (1,006 ) Energy and Other Taxes 1,925 1,243 1,449 1,725 2,196 1,265 1,231 1,334 Total Expenses 267,209 163,428 216,654 285,533 331,795 151,565 153,254 199,042 Other Income and Expense 2,361 4,228 7,236 1,560 2,696 (12,804 ) (340 ) (7,854 ) Income (Loss) from Continuing Operations 68,187 (4,798 ) 9,664 46,008 53,853 13,341 (12,532 ) 50,948 Loss from Discontinued Operations - (Net of tax benefit) (118 ) (29 ) (29 ) (75 ) (276 ) (74 ) (91 ) (62 ) Net Income (Loss) $ 68,069 $ (4,827 ) $ 9,635 $ 45,933 $ 53,577 $ 13,267 $ (12,623 ) $ 50,886 Basic Earnings Per Common Share: Continuing Operations $ 0.96 $ (0.06 ) $ 0.12 $ 0.58 $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 Discontinued Operations — — — — — — — — Basic Earnings Per Common Share $ 0.96 $ (0.06 ) $ 0.12 $ 0.58 $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 Average Shares of Common Stock Outstanding - Basic 71,127 75,298 79,478 79,478 68,397 68,467 68,607 69,460 Diluted Earnings Per Common Share: Continuing Operations $ 0.95 $ (0.06 ) $ 0.12 $ 0.58 $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 Discontinued Operations — — — — — — — — Diluted Earnings Per Common Share $ 0.95 $ (0.06 ) $ 0.12 $ 0.58 $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 Average Shares of Common Stock Outstanding - Diluted 71,416 75,298 79,635 79,643 68,618 68,653 68,607 69,646 The sum of the quarters for basic and diluted earnings per common share for 2016 does not equal the year's total due to the impact of the equity offering on the average shares of common stock outstanding (see Note 6 to the consolidated financial statements). The sum of the quarters for basic and diluted earnings per common share for 2015 does not equal the year's total due to rounding. All share and per share amounts were adjusted for all periods presented for the 2 -for-1 stock split, effected in the form of a stock dividend, effective on May 8, 2015. See Note 1 to the consolidated financial statements. NOTE: Because of the seasonal nature of the business and the volatility from energy-related derivatives, statements for the 3-month periods are not indicative of the results for a full year.

Schedule I

Schedule I	12 Months Ended
	Dec. 31, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Schedule I	SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF INCOME (In Thousands) 2016 2015 2014 Management Service Fee Revenues $ 25,463 $ 20,990 $ 21,118 Operating Expenses: Operations 23,852 17,979 18,183 Depreciation 377 406 439 Energy and Other Taxes 1,033 806 813 Total Operating Expenses 25,262 19,191 19,435 Operating Income 201 1,799 1,683 Other Income: Equity in Earnings of Subsidiaries 119,061 105,610 97,628 Other 11,953 10,145 7,283 Total Other Income 131,014 115,755 104,911 Interest Charges 12,148 11,822 8,803 Income Taxes 6 122 163 Income from Continuing Operations 119,061 105,610 97,628 Equity in Undistributed Earnings of Discontinued Operations (251 ) (503 ) (582 ) Net Income $ 118,810 $ 105,107 $ 97,046 SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (In Thousands) 2016 2015 2014 Net Income $ 118,810 $ 105,107 $ 97,046 Other Comprehensive Income (Loss) - Net of Tax* Postretirement Liability Adjustment (3,197 ) 5,518 (9,160 ) Unrealized Gain (Loss) on Available-for-Sale Securities 118 (53 ) (472 ) Unrealized Gain on Derivatives - Other 197 294 134 Total Other Comprehensive (Loss) Income - Net of Tax* (2,882 ) 5,759 (9,498 ) Comprehensive Income $ 115,928 $ 110,866 $ 87,548 * Determined using a combined average statutory tax rate of 40% . SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF RETAINED EARNINGS (In Thousands) 2016 2015 2014 Retained Earnings - Beginning $ 474,167 $ 439,218 $ 406,041 Net Income 118,810 105,107 97,046 592,977 544,325 503,087 Dividends Declared - Common Stock (82,380 ) (70,158 ) (63,869 ) Retained Earnings - Ending $ 510,597 $ 474,167 $ 439,218 SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF CASH FLOWS FOR THE TWELVE MONTHS ENDED DECEMBER 31, (In Thousands) 2016 2015 2014 CASH PROVIDED BY OPERATING ACTIVITIES $ 20,120 $ 38,593 $ 22,244 CASH FLOWS FROM INVESTING ACTIVITIES: Net Repayments from (Advances to) Associated Companies 32,300 (118,802 ) (104,979 ) Capital Expenditures (345 ) (150 ) (1,610 ) Proceeds from Sale of Property, Plant & Equipment — — 27 Purchase of Company Owned Life Insurance (2,398 ) (2,328 ) (1,250 ) Investment in Affiliate (65,000 ) — (25,000 ) Net Cash Used in Investing Activities (35,443 ) (121,280 ) (132,812 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from Issuance of Long Term Debt — 50,000 240,000 Principal Repayments of Long Term Debt — (114,000 ) — Payments for Issuance of Long Term Debt (84 ) (55 ) (1,558 ) Net (Repayments of) Borrowings from Short-Term Credit Facilities (105,500 ) 153,000 (144,100 ) Dividends on Common Stock (82,380 ) (70,158 ) (63,869 ) Proceeds from Sale of Common Stock 214,426 63,192 80,680 Net Cash Provided by Financing Activities 26,462 81,979 111,153 NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 11,139 (708 ) 585 CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 1,708 2,416 1,831 CASH AND CASH EQUIVALENTS AT END OF YEAR $ 12,847 $ 1,708 $ 2,416 SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED BALANCE SHEETS (In Thousands) 2016 2015 Assets Property Plant and Equipment: Nonutility Property, Plant and Equipment, at cost $ 2,685 $ 2,468 Accumulated Depreciation (2,026 ) (1,768 ) Property, Plant and Equipment - Net 659 700 Investments: Investments in Subsidiaries 1,233,856 1,051,675 Available-for-Sale Securities 32 3,860 Total Investments 1,233,888 1,055,535 Current Assets: Cash and Cash Equivalents 12,847 1,708 Receivable from Associated Companies 550,227 582,406 Accounts Receivable 49 49 Other — 2,859 Total Current Assets 563,123 587,022 Other Noncurrent Assets (See Note 1) 44,974 38,168 Total Assets $ 1,842,644 $ 1,681,425 Capitalization and Liabilities Equity: Common Stock SJI Par Value $1.25 a share Authorized - 120,000,000 shares Outstanding Shares - 79,478,055 (2016) and 70,965,622 (2015) $ 99,347 $ 88,707 Premium on Common Stock 706,943 499,460 Treasury Stock (at par) (266 ) (296 ) Accumulated Other Comprehensive Loss (27,381 ) (24,499 ) Retained Earnings 510,597 474,167 Total Equity 1,289,240 1,037,539 Long-Term Debt (See Note 1) 323,971 339,665 Current Liabilities: Notes Payable - Banks 191,800 297,300 Current Portion of Long-Term Debt 16,000 — Payable to Associated Companies 382 262 Accounts Payable 211 425 Other Current Liabilities 7,707 3,579 Total Current Liabilities 216,100 301,566 Other Noncurrent Liabilities 13,333 2,655 Total Capitalization and Liabilities $ 1,842,644 $ 1,681,425 Notes to Condensed Financial Statements 1. BASIS OF PRESENTATION: Pursuant to rules and regulations of the SEC, the parent-company only condensed financial statements of SJI do not reflect all of the information and notes normally included with financial statements prepared in accordance with GAAP in the United States. Therefore, these condensed financial statements should be read in conjunction with the consolidated financial statements and related notes included under Item 8 in this Form 10-K. Certain reclassifications have been made to the prior period's condensed balance sheets to conform to the current period presentation. The unamortized debt issuance costs previously included in "Other Noncurrent Assets" on the condensed balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described under "New Accounting Pronouncements" in Note 1 of the consolidated financial statements. No dividends were received from subsidiaries in 2016. Dividends received from subsidiaries amounted to $40.8 million and $18.2 million in 2015 and 2014, respectively.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2016
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS (In Thousands) Col. A Col. B Col. C Col. D Col. E Additions Classification Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts - Describe (a) Deductions - Describe (b) Balance at End of Period Provision for Uncollectible Accounts for the Year Ended December 31, 2016 $ 10,252 $ 6,907 $ (47 ) $ 4,368 $ 12,744 Provision for Uncollectible Accounts for the Year Ended December 31, 2015 $ 7,910 $ 14,730 $ (79 ) $ 12,309 $ 10,252 Provision for Uncollectible Accounts for the Year Ended December 31, 2014 $ 5,854 $ 9,519 $ (102 ) $ 7,361 $ 7,910 (a) Recoveries of accounts previously written off and minor adjustments. (b) Uncollectible accounts written off.

SUMMARY OF SIGNIFICANT ACCOUN31

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
GENERAL	GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries: ▪ South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey. ▪ South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial, industrial and residential customers. ▪ South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets along with fuel management services on a wholesale basis in the mid-Atlantic, Appalachian and southern states. ▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. ▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The significant wholly-owned subsidiaries of Marina include: • ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey. • AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties in New Jersey. • MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey. ▪ South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. • SJI Midstream, LLC invests in infrastructure and other midstream projects, including a current project to build a 100 -mile natural gas pipeline in Pennsylvania and New Jersey.
BASIS OF PRESENTATION	BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position, operating results and cash flows at the dates and for the periods presented.
RECLASSIFICATIONS	Certain reclassifications have been made to the prior period's consolidated balance sheets, as well as the prior period's long-term debt carrying value and the prior period's segment disclosures in Notes 7 and 8, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the consolidated balance sheets were reclassified to "Long-Term Debt" to conform to ASU 2015-03, which is described below under "New Accounting Pronouncements." This reclassification caused the prior periods long-term debt carrying value in Note 7 to be adjusted, along with the prior periods unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 8 to be removed.
EQUITY INVESTMENTS	EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary. Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. We include the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in Earnings (Loss) of Affiliated Companies (see Note 3). An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary.
ESTIMATES AND ASSUMPTIONS	ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (GAAP). Management makes estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition.
REGULATION	REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980 -”Regulated Operations.” In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities.
OPERATING REVENUES	OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy-related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. SJRG presents revenues and expenses related to its energy trading activities on a net basis in operating revenues. This net presentation has no effect on operating income or net income. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers.
REVENUE AND THROUGHPUT-BASED TAXES	REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses.
ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLETIBLE ACCOUNTS	ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLECTIBLE ACCOUNTS - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts.
NATURAL GAS IN STORAGE	NATURAL GAS IN STORAGE – Natural Gas in Storage is reflected at average cost on the consolidated balance sheets, and represents natural gas that will be utilized in the ordinary course of business.
ASSET RETIREMENT OBLIGATIONS	ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.
PROPERTY, PLANT AND EQUIPMENT	PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account. As of December 31, 2016 , SJG's utility plant had a gross book value of $2.4 billion , which consists of utility plant assets along with projects for distribution, some of which are part of SJG's Accelerated Infrastructure Replacement Program (AIRP), as discussed in Note 10.
DEPRECIATION	DEPRECIATION - We depreciate utility plant on a straight-line basis over the estimated remaining lives of the various property classes. These estimates are periodically reviewed and adjusted as required after BPU approval. The composite annual rate for all depreciable utility property was approximately 2.2% in each of 2016 , 2015 and 2014 . The actual composite rate may differ from the approved rate as the asset mix changes over time. Except for retirements outside of the normal course of business, accumulated depreciation is charged with the cost of depreciable utility property retired, less salvage. Nonutility property depreciation is computed on a straight-line basis over the estimated useful lives of the property, ranging up to 50 years. Gain or loss on the disposition of nonutility property is recognized in operating income.
CAPITALIZED INTEREST	CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in SJG's last base rate proceeding. For SJG's accelerated infrastructure programs, SJG capitalizes interest on construction at a rate prescribed by the programs (see Note 10), and amounts are included in Utility Plant on the consolidated balance sheets. Marina and Midstream capitalize interest on capital projects in progress based on the actual cost of borrowed funds, and amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the statements of consolidated income.
IMPAIRMENT OF LONG-LIVED ASSETS	IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable.
DERIVATIVE INSTRUMENTS	DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.” We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause. Initially and on an ongoing basis, we assess whether derivatives designated as hedges are highly effective in offsetting changes in cash flows or fair values of the hedged items. We discontinue hedge accounting prospectively if we decide to discontinue the hedging relationship; determine that the anticipated transaction is no longer likely to occur; or determine that a derivative is no longer highly effective as a hedge. In the event that hedge accounting is discontinued, we will continue to carry the derivative on the balance sheet at its current fair value and recognize subsequent changes in fair value in current period earnings. Unrealized gains and losses on the discontinued hedges that were previously included in Accumulated Other Comprehensive Loss will be reclassified into earnings when the forecasted transaction occurs, or when it is probable that it will not occur. Hedge accounting has been discontinued for all remaining derivatives that were designated as hedging instruments.
GAS EXPLORATION AND DEVELOPMENT	GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred.
TREASURY STOCK	TREASURY STOCK – SJI uses the par value method of accounting for treasury stock.
INCOME TAXES	INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow-through method.
CASH AND CASH EQUIVALENTS	CASH AND CASH EQUIVALENTS - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents.
IDENTIFIABLE INTANGIBLE ASSETS	IDENTIFIABLE INTANGIBLE ASSETS - Identifiable intangible assets were acquired as part of the acquisition of Energenic projects as discussed in Note 3 and are a part of the On-Site Energy Production segment. The primary identifiable intangible assets of the Company are customer relationships. The Company determines the useful lives of identifiable intangible assets after considering the specific facts and circumstances related to each intangible asset. Considerations may include the contractual term of any agreement related to the asset, the historical performance of the asset, the Company's long-term strategy for using the asset, any laws or other local regulations which could impact the useful life of the asset, and other economic factors, including competition and specific market conditions. Intangible assets that are deemed to have definite lives (finite-lived intangible assets) are amortized, primarily on a straight-line basis, over their useful lives, generally ranging from 2 to 20 years.
GOODWILL	GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects as discussed in Note 3 and is a part of the On-Site Energy Production segment. Goodwill represents the excess of the consideration paid over the fair value of identifiable net assets acquired. Goodwill is not amortized, but instead is subject to impairment testing on an annual basis, and between annual tests whenever events or changes in circumstances indicate that the fair value of a reporting unit may be below its carrying amount.
NEW ACCOUNTING PRONOUNCEMENTS	NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2016 , 2015 or 2014 had, or is expected to have, a material impact on the consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition , and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. In connection with this new standard, the FASB has issued several amendments to ASU 2014-09, as follows: • In March 2016, the FASB issued ASU 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) . This standard improves the implementation guidance on principal versus agent considerations and whether an entity reports revenue on a gross or net basis. • In April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing . This standard clarifies identifying performance obligations and the licensing implementation guidance. • In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients . This standard provides additional guidance on (a) the objective of the collectibility criterion, (b) the presentation of sales tax collected from customers, (c) the measurement date of non-cash consideration received, (d) practical expedients in respect of contract modifications and completed contracts at transition, and (e) disclosure of the effects of the accounting change in the period of adoption. • In December 2016, the FASB issued ASU No. 2016-20, Technical Corrections and Improvements to (Topic 606), Revenue from Contracts with Customers , which amends certain narrow aspects of the guidance including the disclosure of remaining performance obligations and prior-period performance obligations, as well as other amendments to the guidance on loan guarantee fees, contract costs, refund liabilities, advertising costs and the clarification of certain examples. The new guidance in ASU 2014-09, as well as all amendments discussed above, is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Management has formed an implementation team that is currently evaluating the impact that adoption of this guidance will have on the Company's financial statement results. Based on the review of customer contracts to date, the Company is not anticipating a material impact to its statements of consolidated income, cash flows or consolidated balance sheets upon adoption. The Company expects to transition to the new guidance using the modified retrospective approach. In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results. In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis , which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. Adoption of this guidance did not have an impact on the Company's financial statement results. In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs . This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's results of operations; however, balance sheet presentations were modified to conform to this guidance, as described under "Basis of Presentation" above. Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40) . This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance was effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's financial statement results. In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory . This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In January 2016, the FASB issued ASU 2016-01, Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities , which enhances the reporting model for financial instruments and includes amendments to address aspects of recognition, measurement, presentation and disclosure. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017. Early adoption is permitted for only certain portions of the new guidance. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) , which establishes a new lease accounting model for lessees. The new standard requires substantially all leases be recognized by lessees on their balance sheet as a right-of-use asset and corresponding lease liability, including leases currently accounted for as operating leases. The new standard also will result in enhanced quantitative and qualitative disclosures, including significant judgments made by management, to provide greater insight into the extent of revenue and expense recognized and expected to be recognized from existing leases. The accounting for leases by the lessor remains relatively the same. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2018, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In March 2016, the FASB issued ASU 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships . The amendments in this guidance clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In March 2016, the FASB issued ASU 2016-07, Investments- Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting, which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In March 2016, the FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting , which simplifies various aspects of accounting for share-based payment arrangements. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. This standard is intended to provide guidance concerning the classification of certain cash receipts and cash payments in the statement of cash flows and to eliminate the diversity in practice related to such classifications. This standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In October 2016, the FASB issued ASU 2016-16, Income Taxes (Topic 740); Intra-Entity Transfers of Assets Other Than Inventory. This standard requires recognition of the current and deferred income tax effects of an intra-entity asset transfer, other than inventory, when the transfer occurs, as opposed to current GAAP, which requires companies to defer the income tax effects of intra-entity asset transfers until the asset has been sold to an outside party. The income tax effects of intra-entity inventory transfers will continue to be deferred until the inventory is sold. ASU 2016-16 is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within those annual reporting periods, with early adoption permitted. The standard is required to be adopted on a modified retrospective basis with a cumulative-effect adjustment recorded to retained earnings as of the beginning of the period of adoption. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In November 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash . This standard is intended to reduce diversity in practice in the classification and presentation of changes in restricted cash on the consolidated statement of cash flows. The ASU requires that the consolidated statement of cash flows explain the change in total cash and cash equivalents and amounts generally described as restricted cash or restricted cash equivalents when reconciling the beginning-of-period and end-of-period total amounts. The ASU also requires a reconciliation between the total of cash and equivalents and restricted cash presented on the consolidated statement of cash flows and the cash and cash equivalents balance presented on the consolidated balance sheets. ASU 2016-18 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In January 2017, the FASB issued ASU 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business. This new standard provides amended and clarifying guidance regarding whether an integrated set of assets and activities acquired is deemed the acquisition of a business (and, thus, accounted for as a business combination) or the acquisition of assets. This ASU is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In January 2017, the FASB issued ASU 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment . The update simplifies how an entity is required to test goodwill for impairment by eliminating Step 2 from the goodwill impairment test. Step 2 measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount. The amendments in this Update are effective for annual and any interim impairment tests performed in periods beginning after December 31, 2019. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
FAIR VALUE	GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. The levels of the hierarchy are described below: • Level 1: Observable inputs, such as quoted prices in active markets for identical assets or liabilities. • Level 2: Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly; these include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active. • Level 3: Unobservable inputs that reflect the reporting entity’s own assumptions. Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of financial assets and financial liabilities and their placement within the fair value hierarchy. (A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy. (B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forward contracts, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. (C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

SUMMARY OF SIGNIFICANT ACCOUN32

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Asset retirement obligation activity	ARO activity was as follows (in thousands): 2016 2015 AROs as of January 1, $ 57,943 $ 42,502 Accretion 1,937 1,675 Additions 1,098 802 Settlements (1,551 ) (1,110 ) Revisions in Estimated Cash Flows (A) — 14,074 ARO's as of December 31, $ 59,427 $ 57,943 (A) The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.
Summary of changes in goodwill	The following table summarizes the changes in Goodwill for the year ended December 31, 2016 (in thousands): 2016 Beginning Balance, January 1 $ 8,880 Fair Value Adjustments During Measurement Period (See Note 3) (4,042 ) Ending Balance, December 31 $ 4,838

STOCK-BASED COMPENSATION PLAN (

STOCK-BASED COMPENSATION PLAN (Tables)	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of the nonvested restricted stock awards outstanding and the assumptions used to estimate the fair value of the awards	The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2016 , and the assumptions used to estimate the fair value of the awards: Grants Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate Officers & Key Employees - 2015 - TSR 33,537 $ 26.31 16.0 % 1.10 % 2015 - EGR, ROE, Time 73,118 $ 29.47 N/A N/A 2016 - TSR 66,101 $ 22.53 18.1 % 1.31 % 2016 - CEGR, Time 122,759 23.52 N/A N/A Directors - 2016 35,197 $ 23.88 N/A N/A
Summary of the total stock-based compensation cost for the period	The following table summarizes the total stock-based compensation cost for the years ended December 31 (in thousands): 2016 2015 2014 Officers & Key Employees $ 3,051 $ 1,128 $ 1,260 Directors 841 769 633 Total Cost 3,892 1,897 1,893 Capitalized (385 ) (216 ) (147 ) Net Expense $ 3,507 $ 1,681 $ 1,746
Summary of information regarding restricted stock award activity during the period excluding accrued dividend equivalents	The following table summarizes information regarding restricted stock award activity during 2016 , excluding accrued dividend equivalents: Officers & Other Key Employees Directors Weighted Average Fair Value Nonvested Shares Outstanding, January 1, 2016 226,191 26,338 $ 26.89 Granted 194,347 35,197 $ 23.28 Vested* (113,917 ) (26,338 ) $ 25.69 Cancelled/Forfeited** (11,106 ) — $ 25.11 Nonvested Shares Outstanding, December 31, 2016 295,515 35,197 $ 24.96 *Based on performance information available at the filing of this Report, management expects to award 29,044 shares associated with the 2014 grants to Officers and other key employees in 2017. ** Represents shares forfeited as a result of separation of employment prior to the satisfaction of service conditions.

AFFILIATIONS AND DISCONTINUED34

AFFILIATIONS AND DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
Schedule of the fair value of the assets acquired and the liabilities assumed	The following table summarizes the final purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.0 million , which represents the fair value of the Company’s interest in the Partner Projects exchanged ( $31.5 million ) as well as the existing value of the Marina Projects immediately prior to the exchange ( $14.5 million ) (in thousands): Current assets (excluding inventory) $ 7,804 Inventory 3,154 Note Receivable Received 19,504 Fixed Assets 46,460 Intangible Assets: Identifiable Intangibles 16,950 Goodwill 4,838 Non-Current Assets 4,783 Current Liabilities (8,196 ) Note Payable - Affiliate (16,986 ) Long-Term Debt, including current portion (21,642 ) Capital Lease Payable (10,458 ) Other Non-Current Liabilities (181 ) Fair Value of Consolidated Assets and Liabilities of Acquired Projects $ 46,030
Summarized operating results of the discontinued operations	Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts): 2016 2015 2014 Loss before Income Taxes: Sand Mining $ (205 ) $ (422 ) $ (620 ) Fuel Oil (179 ) (338 ) (274 ) Income Tax Benefits 133 257 312 Loss from Discontinued Operations — Net $ (251 ) $ (503 ) $ (582 ) Earnings Per Common Share from Discontinued Operations — Net: Basic and Diluted $ — $ (0.01 ) $ (0.01 )

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Schedule of components of income tax expense (benefit) and effective income tax rate reconciliation	Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for the following reasons (in thousands): 2016 2015 2014 Tax at Statutory Rate $ 60,624 $ 37,440 $ 35,727 Increase (Decrease) Resulting from: State Income Taxes 6,438 3,985 1,960 ESOP Dividend (1,300 ) (1,298 ) (1,232 ) Amortization of Investment Tax Credits - Utility — (149 ) (211 ) AFUDC (900 ) (1,109 ) (1,481 ) Investment and Other Tax Credits (10,706 ) (37,503 ) (30,661 ) Other - Net (5 ) (6 ) 347 Income Taxes: Continuing Operations 54,151 1,360 4,449 Discontinued Operations (133 ) (257 ) (312 ) Total Income Tax Expense $ 54,018 $ 1,103 $ 4,137 The provision for Income Taxes is comprised of the following (in thousands): 2016 2015 2014 Current: Federal $ — $ — $ (62 ) State (1,638 ) (2,352 ) 3,052 Total Current (1,638 ) (2,352 ) 2,990 Deferred: Federal 44,246 (4,622 ) 1,707 State 11,543 8,483 (37 ) Total Deferred 55,789 3,861 1,670 Investment Tax Credit - Utility — (149 ) (211 ) Income Taxes: Continuing Operations 54,151 1,360 4,449 Discontinued Operations (133 ) (257 ) (312 ) Total Income Tax Expense $ 54,018 $ 1,103 $ 4,137
Schedule of deferred tax assets and liabilities	The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax assets and liabilities at December 31 (in thousands): 2016 2015 Deferred Tax Assets: Net Operating Loss Carryforward $ 211,004 $ 195,358 Investment and Other Tax Credits 213,946 200,491 Derivatives / Unrealized Gain — 5,652 Deferred State Tax 28,833 24,833 Pension & Other Post Retirement Benefits 19,351 29,998 Deferred Revenues 7,669 4,924 Provision for Uncollectibles 5,231 4,200 Other 8,368 6,448 Total Deferred Tax Asset $ 494,402 $ 471,904 Deferred Tax Liabilities: Book versus Tax Basis of Property $ 732,535 $ 675,521 Deferred Gas Costs - Net 2,052 3,998 Derivatives / Unrealized Loss 1,794 — Environmental Remediation 32,885 19,207 Deferred Regulatory Costs 1,554 566 Budget Billing - Customer Accounts 3,347 830 Deferred Pension & Other Post Retirement Benefits 34,432 42,216 Conservation Incentive Program 11,846 1,132 Equity In Loss Of Affiliated Companies 3,092 9,111 Other 14,414 15,268 Total Deferred Tax Liability $ 837,951 $ 767,849 Deferred Tax Liability - Net $ 343,549 $ 295,945
Summary of operating loss carryforward	As of December 31, 2016 , SJI has the following federal and state net operating loss carryforwards (in thousands): Net Operating Loss Carryforwards Expire in: Federal State 2031 $ 163,572 $ 45,866 2032 42,988 19,356 2033 67,496 34,940 2034 119,122 28,622 2035 70,992 9,860 2036 93,508 81,369 $ 557,678 $ 220,013
Summary of tax credit carryforwards	As of December 31, 2016 , SJI has the following investment tax credit carryforwards (in thousands): Expire in: Investment Tax Credit Carryforward 2030 $ 11,628 2031 25,664 2032 32,071 2033 45,606 2034 37,699 2035 45,097 2036 11,659 $ 209,424
Reconciliation of unrecognized tax benefits	A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands): 2016 2015 2014 Balance at January 1, $ 559 $ 552 $ 547 Increase as a result of tax positions taken in prior years 886 7 5 Balance at December 31, $ 1,445 $ 559 $ 552

COMMON STOCK (Tables)

COMMON STOCK (Tables)	12 Months Ended
	Dec. 31, 2016
Common Stock [Abstract]
Common stock shares issued and outstanding	The following shares were issued and outstanding at December 31 (See Note 1): 2016 2015 2014 Beginning of Year 70,965,622 68,334,860 65,430,084 New Issues During Year: Dividend Reinvestment Plan 417,095 2,604,424 2,881,556 Stock-Based Compensation Plan 45,338 26,338 23,220 Public Equity Offering 8,050,000 — — End of Year 79,478,055 70,965,622 68,334,860

SEGMENTS OF BUSINESS (Tables)

SEGMENTS OF BUSINESS (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segments of Business	Information about SJI’s operations in different reportable operating segments is presented below (in thousands): 2016 2015 2014 Operating Revenues: Gas Utility Operations $ 461,055 $ 534,290 $ 501,875 Energy Group: Wholesale Energy Operations 220,707 129,098 77,048 Retail Gas and Other Operations 92,371 87,198 127,001 Retail Electric Operations 182,540 150,049 123,773 Subtotal Energy Group 495,618 366,345 327,822 Energy Services: On-Site Energy Production 94,375 63,665 56,129 Appliance Service Operations 7,898 11,186 10,518 Subtotal Energy Services 102,273 74,851 66,647 Corporate & Services 35,147 31,156 30,174 Subtotal 1,094,093 1,006,642 926,518 Intersegment Sales (57,593 ) (47,074 ) (39,522 ) Total Operating Revenues $ 1,036,500 $ 959,568 $ 886,996 2016 2015 2014 Operating Income: Gas Utility Operations $ 122,455 $ 119,585 $ 113,690 Energy Group: Wholesale Energy Operations 41,667 35,024 9,493 Retail Gas and Other Operations 4,680 (3,218 ) 479 Retail Electric Operations 7,007 1,042 (466 ) Subtotal Energy Group 53,354 32,848 9,506 Energy Services: On-Site Energy Production 13,301 2,027 2,560 Appliance Service Operations 582 468 362 Subtotal Energy Services 13,883 2,495 2,922 Corporate and Services (416 ) 1,966 1,485 Total Operating Income $ 189,276 $ 156,894 $ 127,603 Depreciation and Amortization: Gas Utility Operations $ 63,901 $ 58,668 $ 52,155 Energy Group: Wholesale Energy Operations 484 435 168 Retail Gas and Other Operations 337 161 83 Subtotal Energy Group 821 596 251 Energy Services: On-Site Energy Production 43,395 30,242 25,020 Appliance Service Operations 301 316 269 Subtotal Energy Services 43,696 30,558 25,289 Corporate and Services 1,400 1,220 816 Total Depreciation and Amortization $ 109,818 $ 91,042 $ 78,511 Interest Charges: Gas Utility Operations $ 17,875 $ 19,906 $ 17,872 Energy Group: Wholesale Energy Operations — 441 371 Retail Gas and Other Operations 350 185 267 Subtotal Energy Group 350 626 638 Energy Services: On-Site Energy Production 11,961 8,169 8,723 Corporate and Services 12,118 11,822 8,803 Subtotal 42,304 40,523 36,036 Intersegment Borrowings (10,855 ) (8,901 ) (6,476 ) Total Interest Charges $ 31,449 $ 31,622 $ 29,560 2016 2015 2014 Income Taxes: Gas Utility Operations $ 39,366 $ 36,945 $ 34,895 Energy Group: Wholesale Energy Operations 15,882 14,410 4,822 Retail Gas and Other Operations 2,118 (978 ) 787 Retail Electric Operations 2,862 426 (190 ) Subtotal Energy Group 20,862 13,858 5,419 Energy Services: On-Site Energy Production (6,353 ) (49,225 ) (36,404 ) Appliance Service Operations 232 186 223 Subtotal Energy Services (6,121 ) (49,039 ) (36,181 ) Corporate and Services 44 (404 ) 316 Total Income Taxes $ 54,151 $ 1,360 $ 4,449 Property Additions: Gas Utility Operations $ 228,275 $ 218,260 $ 201,737 Energy Group: Wholesale Energy Operations 7 382 18 Retail Gas and Other Operations 1,642 2,053 1,421 Subtotal Energy Group 1,649 2,435 1,439 Energy Services: On-Site Energy Production (1) 38,193 139,018 132,214 Appliance Service Operations 431 379 84 Subtotal Energy Services 38,624 139,397 132,298 Corporate and Services 1,141 1,902 3,995 Total Property Additions $ 269,689 $ 361,994 $ 339,469 (1) The property additions for On-Site Energy Production in 2016 and 2015 do not include the approximately $5.6 million and $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3. 2016 2015 Identifiable Assets (See Note 1): Gas Utility Operations $ 2,551,923 $ 2,281,576 Energy Group: Wholesale Energy Operations 233,019 231,660 Retail Gas and Other Operations 52,729 55,111 Retail Electric Operations 41,280 55,528 Subtotal Energy Group 327,028 342,299 Energy Services: On-Site Energy Production 767,710 790,231 Appliance Service Operations 2,879 4,885 Subtotal Energy Services 770,589 795,116 Discontinued Operations 1,756 1,545 Corporate and Services 649,795 652,325 Intersegment Assets (570,524 ) (600,928 ) Total Identifiable Assets $ 3,730,567 $ 3,471,933

LEASES (Tables)

LEASES (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Schedule of minimum future rental receivables on operating lease	Minimum future rentals to be received on this operating lease of property and equipment as of December 31, 2016 for each of the next five years and in the aggregate are (in thousands): Year ended December 31, 2017 $ 5,396 2018 5,396 2019 5,396 2020 5,396 2021 5,396 Thereafter 29,230 Total minimum future rentals 56,210

REGULATORY ASSETS & REGULATOR39

REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory Assets consisted of the following items (in thousands): December 31, 2016 December 31, 2015 Environmental Remediation Costs: Expended - Net $ 71,997 $ 42,032 Liability for Future Expenditures 153,047 123,194 Deferred Asset Retirement Obligation Costs 43,014 42,430 Deferred Pension and Other Postretirement Benefit Costs 85,693 79,779 Deferred Gas Costs - Net — 2,701 Conservation Incentive Program Receivable 27,567 2,624 Deferred Interest Rate Contracts 7,365 7,631 Energy Efficiency Tracker 219 496 Pipeline Supplier Service Charges 2,122 3,776 Pipeline Integrity Cost 4,810 4,596 AFUDC - Equity Related Deferrals 12,434 11,423 Other Regulatory Assets 2,478 2,752 Total Regulatory Assets $ 410,746 $ 323,434
Schedule of Regulatory Liabilities	Regulatory Liabilities consisted of the following items (in thousands): December 31, 2016 December 31, 2015 Excess Plant Removal Costs $ 28,226 $ 32,644 Deferred Revenue - Net 17,800 — Societal Benefit Costs Payable 3,095 10,197 Total Regulatory Liabilities $ 49,121 $ 42,841

PENSION AND OTHER POSTRETIREM40

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
Schedule of Net Periodic Benefit Costs	Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands): Pension Benefits 2016 2015 2014 Service Cost $ 4,843 $ 5,337 $ 4,510 Interest Cost 12,125 11,168 10,735 Expected Return on Plan Assets (13,508 ) (14,789 ) (13,491 ) Amortizations: Prior Service Cost 212 212 175 Actuarial Loss 9,394 10,608 5,716 Net Periodic Benefit Cost 13,066 12,536 7,645 Capitalized Benefit Costs (4,645 ) (4,805 ) (3,047 ) Deferred Benefit Costs (645 ) (1,007 ) — Total Net Periodic Benefit Expense $ 7,776 $ 6,724 $ 4,598 Other Postretirement Benefits 2016 2015 2014 Service Cost $ 851 $ 1,116 $ 891 Interest Cost 2,615 2,973 2,852 Expected Return on Plan Assets (3,104 ) (2,993 ) (2,603 ) Amortizations: Prior Service (Credits) Cost (344 ) 608 152 Actuarial Loss 1,109 1,342 974 Net Periodic Benefit Cost 1,127 3,046 2,266 Capitalized Benefit Costs (277 ) (1,043 ) (722 ) Deferred Benefit Costs — (256 ) — Total Net Periodic Benefit Expense $ 850 $ 1,747 $ 1,544
Activity Within Regulatory Assets and Accumulated Other Comprehensive Income (Loss)	Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands): Regulatory Assets Accumulated Other Comprehensive Loss (pre-tax) Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Balance at January 1, 2015 $ 71,177 $ 27,863 $ 39,468 $ 6,755 Amounts Arising during the Period: Net Actuarial (Loss)/Gain (463 ) (3,155 ) 59 (2,285 ) Prior Service Cost (499 ) (106 ) Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (6,079 ) (1,107 ) (4,452 ) (221 ) Prior Service Cost (203 ) (7,755 ) (9 ) (2,081 ) Balance at December 31, 2015 64,432 15,347 35,066 2,062 Amounts Arising during the Period: Net Actuarial Gain 9,706 2,584 8,370 829 Prior Service Credit — 257 — 84 Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (5,485 ) (945 ) (3,838 ) (154 ) Prior Service Cost (203 ) — (8 ) — Balance at December 31, 2016 $ 68,450 $ 17,243 $ 39,590 $ 2,821
Estimated Costs That Will be Amortized from Regulatory Assets into Net Periodic Costs	The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2017 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 127 $ (257 ) Net Actuarial Loss $ 6,202 $ 1,040
Estimated Costs That Will be Amortized from Accumulated Other Comprehensive Income (Loss) into Net Periodic Benefit Costs	The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2017 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 5 $ (87 ) Net Actuarial Loss $ 3,943 $ 207
Reconciliation of the Plans' Benefit Obligations, Fair Value of Plan Assets and Funded Status	A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands): Pension Benefits Other Postretirement Benefits 2016 2015 2016 2015 Change in Benefit Obligations: Benefit Obligation at Beginning of Year $ 254,195 $ 265,434 $ 57,430 $ 75,592 Service Cost 4,843 5,337 851 1,116 Interest Cost 12,125 11,168 2,615 2,973 Actuarial Loss (Gain) 18,254 (17,349 ) 3,121 (8,591 ) Retiree Contributions — — 81 700 Plan Amendments — — — (9,899 ) Benefits Paid (11,129 ) (10,395 ) (3,748 ) (4,461 ) Benefit Obligation at End of Year $ 278,288 $ 254,195 $ 60,350 $ 57,430 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Year $ 184,824 $ 180,523 $ 47,759 $ 43,222 Actual Return on Plan Assets 13,569 (2,321 ) 2,784 (423 ) Employer Contributions 2,278 17,017 3,656 8,721 Retiree Contributions — — 81 700 Benefits Paid (11,129 ) (10,395 ) (3,748 ) (4,461 ) Fair Value of Plan Assets at End of Year $ 189,542 $ 184,824 $ 50,532 $ 47,759 Funded Status at End of Year: $ (88,746 ) $ (69,371 ) $ (9,818 ) $ (9,671 ) Amounts Related to Unconsolidated Affiliate 326 204 540 509 Accrued Net Benefit Cost at End of Year $ (88,420 ) $ (69,167 ) $ (9,278 ) $ (9,162 ) Amounts Recognized in the Statement of Financial Position Consist of: Current Liabilities $ (2,463 ) $ (2,261 ) $ — $ — Noncurrent Liabilities (85,957 ) (66,906 ) (9,278 ) (9,162 ) Net Amount Recognized at End of Year $ (88,420 ) $ (69,167 ) $ (9,278 ) $ (9,162 ) Amounts Recognized in Regulatory Assets Consist of: Prior Service Costs $ 538 $ 741 $ (3,032 ) $ (3,289 ) Net Actuarial Loss 67,912 63,691 20,275 18,636 $ 68,450 $ 64,432 $ 17,243 $ 15,347 Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax): Prior Service Costs $ 69 $ 77 $ (989 ) $ (1,074 ) Net Actuarial Loss 39,521 34,989 3,810 3,136 $ 39,590 $ 35,066 $ 2,821 $ 2,062
Schedule of Weighted-Average Assumptions Used	The weighted-average assumptions used to determine benefit obligations at December 31 were: Pension Benefits Other Postretirement Benefits 2016 2015 2016 2015 Discount Rate 4.30 % 4.83 % 4.13 % 4.73 % Rate of Compensation Increase 3.50 % 3.50 % 3.50 % 3.50 % The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were: Pension Benefits Other Postretirement Benefits 2016 2015 2014 2016 2015 2014 Discount Rate 4.83 % 4.25 % 5.09 % 4.73 % 4.20 % 4.91 % Expected Long-Term Return on Plan Assets 7.50 % 7.75 % 7.75 % 6.50 % 6.25 % 6.25 % Rate of Compensation Increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 %
Fair Value of Plan Assets	The fair values of SJI's pension plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2016 Cash / Cash Equivalents: Cash $ 63 $ 63 $ — $ — Common/Collective Trust Funds (a) 460 — 460 — STIF-Type Instrument (b) 1,431 — 1,431 — Equity securities: Common/Collective Trust Funds - U.S. (a) 51,902 — 51,902 — Common/Collective Trust Funds - International (a) 33,096 — 33,096 — U.S. Large-Cap (c) 17,792 17,792 — — U.S. Mid-Cap (c) 2,479 2,479 — — International (c) 3,340 3,340 — — Fixed Income: Common/Collective Trust Funds (a) 54,970 — 54,970 — Guaranteed Insurance Contract (d) 9,714 — — 9,714 Other types of investments: Private Equity Fund (f) 5,100 — — 5,100 Common/Collective Trust Fund - Real Estate (g) 9,195 — — 9,195 Total $ 189,542 $ 23,674 $ 141,859 $ 24,009 Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash / Cash Equivalents: Cash $ 35 $ 35 $ — $ — Common/Collective Trust Funds (a) 858 — 858 — STIF-Type Instrument (b) 1,360 — 1,360 — Equity securities: Common/Collective Trust Funds - U.S. (a) 52,058 — 52,058 — Common/Collective Trust Funds - International (a) 33,236 — 33,236 — U.S. Large-Cap (c) 14,305 14,305 — — U.S. Mid-Cap (c) 3,407 3,407 — — U.S. Small-Cap (c) 260 260 — — International (c) 1,695 1,695 — — Fixed Income: Common/Collective Trust Funds (a) 50,664 — 50,664 — Guaranteed Insurance Contract (d) 9,960 — — 9,960 Hedge Funds (e) 4,159 — — 4,159 Other types of investments: Private Equity Fund (f) 4,312 — — 4,312 Common/Collective Trust Fund - Real Estate (g) 8,515 — — 8,515 Total $ 184,824 $ 19,702 $ 138,176 $ 26,946 (a) This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. (b) This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements. Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information. Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments. (c) This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy. These common stocks are actively traded on exchanges and price quotes for these shares are readily available. These common stocks are classified as Level 1 investments. (d) This category represents SJI's Group Annuity contracts with a nationally recognized life insurance company. The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder. Valuation is based on a formula and calculation specified within the contract. Since the valuation is based on the reporting entity's own assumptions, these contracts are classified as Level 3 investments. (e) This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments. (f) This category represents a limited partnership/commingled trust which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments. Fund investments are illiquid and resale is restricted. These funds are classified as Level 3 investments. (g) This category represents real estate common/collective trust fund investments through a commingled employee benefit trust. These commingled funds are part of a direct investment in a pool of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals from sources with professional qualifications. Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments. The fair values of SJI's other postretirement benefit plan assets at December 31, 2016 and 2015 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2016: Cash $ — $ — $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 14,878 $ — $ 14,878 $ — Common/Collective Trust Funds - International (a) 8,674 — 8,674 — Fixed Income: Common/Collective Trust Funds - Bonds (a) 13,537 — 13,537 — Other Types of Investments: Company Owned Life Insurance (c) 13,443 — 13,443 — Total $ 50,532 $ — $ 50,532 $ — Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015: Cash $ 26 $ 26 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 13,522 $ — $ 13,522 $ — Common/Collective Trust Funds - International (a) 8,313 — 8,313 — Mutual Fund - U.S. (b) 1,309 1,309 — — Mutual Funds - International (b) 983 983 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 13,187 — 13,187 — Mutual Funds - Bonds (b) 1,441 1,441 — — Other Types of Investments: Mutual Funds - REITS (b) 152 152 — — Company Owned Life Insurance (c) 8,826 — 8,826 — Total $ 47,759 $ 3,911 $ 43,848 $ — (a) This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. (b) This category represents mutual fund investments. The mutual funds are actively traded on exchanges and price quotes for the shares are readily available. These mutual funds are classified as Level 1 investments. (c) This category represents Company-owned life insurance policies with a nationally known life insurance company. The value of these policies is backed by a series of common/collective trust funds held by the insurance carrier similar to category (a) above. Holdings in these insurance policies are classified as Level 2 investments.
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets	Guaranteed Private Insurance Hedge Equity Real Contract Funds Funds Estate Total Balance at January 1, 2015 $ 10,912 $ 4,331 $ 3,616 $ 7,476 $ 26,335 Actual return on plan assets: Relating to assets still held at the reporting date (106 ) (172 ) (302 ) 1,039 459 Relating to assets sold during the period 25 — 429 — 454 Purchases, Sales and Settlements (871 ) — 569 — (302 ) Balance at December 31, 2015 9,960 4,159 4,312 8,515 26,946 Actual return on plan assets: Relating to assets still held at the reporting date 541 (67 ) (140 ) 680 1,014 Relating to assets sold during the period 14 — 245 — 259 Purchases, Sales and Settlements (801 ) (4,092 ) 683 — (4,210 ) Balance at December 31, 2016 $ 9,714 $ — $ 5,100 $ 9,195 $ 24,009
Schedule of Future Benefit Payments	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following years (in thousands): Pension Benefits Other Postretirement Benefits 2017 $ 12,141 $ 4,399 2018 $ 12,583 $ 4,316 2019 $ 13,529 $ 4,403 2020 $ 14,056 $ 4,514 2021 $ 14,757 $ 4,511 2022 - 2025 $ 86,727 $ 21,308

LINES OF CREDIT (Tables)

LINES OF CREDIT (Tables)	12 Months Ended
	Dec. 31, 2016
Line of Credit Facility [Abstract]
Summary of Credit Facilities and Available Liquidity	Credit facilities and available liquidity as of December 31, 2016 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 105,100 (A) $ 94,900 May 2018 Uncommitted Bank Lines 10,000 — 10,000 August 2017 Total SJG 210,000 105,100 104,900 SJI: Revolving Credit Facility 450,000 196,600 (B) 253,400 Various (C) Total SJI 450,000 196,600 253,400 Total $ 660,000 $ 301,700 $ 358,300 (A) Includes letters of credit outstanding in the amount of $0.8 million . (B) Includes letters of credit outstanding in the amount of $4.8 million . (C) In September 2016, the Company entered into an unsecured $50.0 million , 364 -day revolving credit agreement. The agreement matures September 2017, at which time the principal and any accrued but unpaid interest must be paid. At the annual request of the Company, but on not more than two occasions, the credit agreement may be extended for an additional period of 364 days. The 364 -day revolving facility bears interest at a variable base rate or a variable London Interbank Offered Rate (“LIBOR”), at the Company’s election.

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Schedule of Long-term Debt	Outstanding Long-Term Debt at December 31 consisted of the following: 2016 2015 Long-Term Debt (A): South Jersey Gas Company: First Mortgage Bonds: (B) 5.437% Series due 2016 (C) $ — $ 10,000 4.6% Series due 2016 (C) — 17,000 4.657% Series due 2017 15,000 15,000 7.97% Series due 2018 10,000 10,000 7.125% Series due 2018 20,000 20,000 5.587% Series due 2019 10,000 10,000 3.00% Series due 2024 (D) 50,000 50,000 3.03% Series due 2024 (E) 35,000 35,000 3.63% Series due 2025 (F) 8,182 9,091 4.84% Series due 2026 (G) 15,000 15,000 4.93% Series due 2026 (H) 45,000 45,000 4.03% Series due 2027 45,000 45,000 4.01% Series due 2030 (I) 50,000 50,000 4.23% Series due 2030 30,000 30,000 3.74% Series due 2032 35,000 35,000 5.55% Series due 2033 32,000 32,000 6.213% Series due 2034 10,000 10,000 5.45% Series due 2035 10,000 10,000 Series A 2006 Bonds at variable rates due 2036 (J) 24,900 24,900 SJG Term Facility (K) 200,000 139,000 Marina Energy LLC: (L) Series A 2001 Bonds at variable rates due 2031 20,000 20,000 Series B 2001 Bonds at variable rates due 2021 25,000 25,000 Series A 2006 Bonds at variable rates due 2036 16,400 16,400 South Jersey Industries: 2.71% Series B 2012 Notes due 2017 (M) 16,000 16,000 3.05% Series due 2019 60,000 60,000 3.05% Series due 2019 30,000 30,000 3.05% Series due 2019 50,000 50,000 3.46% Series C 2012 Notes due 2022 35,000 35,000 Series Notes at variable rates due 2019 (N) 40,000 40,000 Series Notes at variable rates due 2019 (N) 60,000 60,000 South Jersey Industries Term Loan at variable rates due 2020 (O) 50,000 50,000 ACB Energy Partners, LLC: 7.60 % Loan & Security Agreement (P) — 12,735 Other Energy Project Debt (Q): 4.83 % ACLE — 3,551 4.83 % SCLE — 1,738 4.83 % SXLE — 3,433 Total Long-Term Debt Outstanding (R) $ 1,047,482 $ 1,035,848 Less Current Maturities (231,909 ) (29,454 ) Total Long-Term Debt (R) $ 815,573 $ 1,006,394 (A) Long-term debt maturities for the succeeding five years are as follows (in thousands): 2017: $231,909 ; 2018: $38,909 ; 2019: $258,909 ; 2020: $67,909 ; and 2021: $52,909 . (B) The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. In January 2017, the First Mortgage was amended and restated in its entirety (see Note 19). (C) In July 2016, SJG retired $17.0 million of 4.60% Medium Term Notes (MTN's) at maturity. In August 2016, SJG retired $10.0 million of 5.437% MTN's at maturity. (D) SJG has $50.0 million of 3.00% MTN's, with $10.0 million due annually beginning September 2020 with the final payment due September 2024. (E) SJG has $35.0 million of 3.03% MTN's, with $7.0 million due annually beginning November 2020 with the final payment due November 2024. (F) SJG pays $0.9 million annually toward the principal amount of 3.63% MTN's, with the final payment to be made December 2025. As such, $0.9 million of the total outstanding amount on this debt is classified in current portion of long-term debt on the consolidated balance sheets as it is due within one year. (G) SJG has $15.0 million of 4.84% MTN's, with $2.5 million due annually beginning March 2021 with the final payment due March 2026. (H) SJG has $45.0 million of 4.93% MTN's, with $7.5 million due annually beginning June 2021 with the final payment due June 2026. (I) SJG has $50.0 million of 4.01% MTN's with several due dates, as follows: $8.0 million each due November 2018 and 2019; $2.0 million due November 2025; $3.0 million due November 2026; $8.0 million due November 2027; and $7.0 million each due November 2028, 2029 and 2030. (J) These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2016 was 0.74% . Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August 2018. These bonds contain no financial covenants. (K) SJG had a $200.0 million multiple-draw term facility offered by a syndicate of banks which was set to expire in June 2017. This facility bore interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of December 31, 2015, SJG had borrowed an aggregate $139.0 million under this facility at an average interest rate of 1.17% and the proceeds were used to pay down short-term debt. In January 2016, SJG issued an additional $61.0 million of long-term debt at an average interest rate of 1.41% under this facility. As such, the total outstanding amount under this facility as of December 31, 2016 was $200.0 million , which was classified in current portion of long-term debt on the consolidated balance sheets as it was due within one year. In January 2017, this term facility was paid in full (see Note 19). (L) Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2016 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.72% , 0.73% and 0.72% respectively. The interest rate on all but $46.1 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026. These bonds contain no financial covenants. Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March 2018. (M) As of December 31, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017, are classified in current portion of long-term debt on the consolidated balance sheets. SJI plans to pay off this debt at maturity. (N) At December 31, 2016 , the floating rate on these Senior Notes was 2.32% . (O) In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million , which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2016 was 1.79% . (P) ACB had a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million . Under the LSA, ACB paid principal and interest (at a fixed rate of 7.60% ) in equal quarterly installments that began in February 2011 and was scheduled to run through February 2021. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In January 2016, the Company paid $12.7 million to retire outstanding debt. (Q) ACLE, SCLE and SXLE (the "Other Energy Projects") had long-term debt agreements with a third party to borrow up to $10.0 million . Under the debt agreements, the Other Energy Projects paid principal and interest (at a fixed rate of 4.83% ) in equal installments that began December 2013 and was scheduled to run through December 2020. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the outstanding debt of $8.7 million was included on the Company's consolidated balance sheets as of December 31, 2015. In August 2016, the Company paid an aggregate $8.3 million to retire outstanding long-term debt for the Other Energy Projects. (R) Total Long-Term Debt in the table above does not include unamortized debt issuance costs of $7.6 million and $9.0 million for the years ended December 31, 2016 and 2015, respectively, which were reclassified to Long-Term Debt on the consolidated balance sheets to conform to ASU 2015-03 (see Note 1).

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of Environmental Loss Contingencies	The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands): 2016 2015 Beginning of Year $ 126,623 $ 128,172 Accruals 60,713 19,489 Expenditures (32,323 ) (21,038 ) End of Year $ 155,013 $ 126,623

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of Interest Rate Swaps	As of December 31, 2016 , SJI's active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type of Debt Obligor $ 14,500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 330,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 12,500,000 3.530% 12/1/2006 2/1/2036 Tax-exempt SJG $ 12,500,000 3.430% 12/1/2006 2/1/2036 Tax-exempt SJG
Fair Value of Derivative Instruments	The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP 2016 2015 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current $ 72,391 $ 60,082 $ 83,093 $ 90,708 Derivatives – Energy Related – Non-Current 8,502 4,540 16,238 21,697 Interest rate contracts: Derivatives - Other - Current — 681 — — Derivatives - Other - Non-Current — 9,349 — 10,943 Total derivatives not designated as hedging instruments under GAAP 80,893 74,652 99,331 123,348 Total Derivatives $ 80,893 $ 74,652 $ 99,331 $ 123,348
Offsetting Arrangements	As of December 31, 2016 and 2015 , information related to these offsetting arrangements were as follows (in thousands): As of December 31, 2016 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets $ 80,893 $ — $ 80,893 $ (38,809 ) (A) $ (3,474 ) $ 38,610 Derivatives - Energy Related Liabilities $ (64,622 ) $ — $ (64,622 ) $ 38,809 (B) $ — $ (25,813 ) Derivatives - Other $ (10,030 ) $ — $ (10,030 ) $ — $ — $ (10,030 ) As of December 31, 2015 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets $ 99,331 $ — $ 99,331 $ (35,491 ) (A) $ — $ 63,840 Derivatives - Energy Related Liabilities $ (112,405 ) $ — $ (112,405 ) $ 35,491 (B) $ 23,045 $ (53,869 ) Derivatives - Other $ (10,943 ) $ — $ (10,943 ) $ — $ — $ (10,943 ) (A) The balances at December 31, 2016 and 2015 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at December 31, 2016 and 2015 were related to derivative assets which can be net settled against derivative liabilities.
Effect of Derivatives on Income	The effect of derivative instruments on the statements of consolidated income and comprehensive income for the year ended December 31 is as follows (in thousands): Derivatives in Cash Flow Hedging Relationships 2016 2015 2014 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — Losses reclassified from AOCL into income (a) $ (333 ) $ (551 ) $ (419 ) Losses recognized in income on ineffective portion (a) $ — $ — $ — (a) Included in Interest Charges Derivatives Not Designated as Hedging Instruments under GAAP 2016 2015 2014 Gains (losses) on energy-related commodity contracts (a) $ 26,935 $ 8,401 $ (6,592 ) Gains (losses) on interest rate contracts (b) 647 96 (467 ) Total $ 27,582 $ 8,497 $ (7,059 ) (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges

FAIR VALUE OF FINANCIAL ASSET45

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Summary of Financial Assets and Liabilities	For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands): As of December 31, 2016 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 32 $ 32 $ — $ — Derivatives – Energy Related Assets (B) 80,893 33,994 11,814 35,085 $ 80,925 $ 34,026 $ 11,814 $ 35,085 Liabilities Derivatives – Energy Related Liabilities (B) $ 64,622 $ 16,502 $ 22,070 $ 26,050 Derivatives – Other (C) 10,030 — 10,030 — $ 74,652 $ 16,502 $ 32,100 $ 26,050 As of December 31, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 14,810 $ 2,925 $ 11,885 $ — Derivatives – Energy Related Assets (B) 99,331 16,006 24,730 58,595 $ 114,141 $ 18,931 $ 36,615 $ 58,595 Liabilities Derivatives – Energy Related Liabilities (B) $ 112,405 $ 42,170 $ 11,008 $ 59,227 Derivatives – Other (C) 10,943 — 10,943 — $ 123,348 $ 42,170 $ 21,951 $ 59,227 (A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy. (B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forward contracts, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. (C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.
Quantitative Information Regarding Significant Unobservable Inputs	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands, except for ranges): Type Fair Value at December 31, 2016 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 23,301 $ 18,109 Discounted Cash Flow Forward price (per dt) $1.03 - $11.33 (A) Forward Contract - Electric $ 11,784 $ 7,941 Discounted Cash Flow Fixed electric load profile (on-peak) 21.43% - 100.00% (B) Fixed electric load profile (off-peak) 0.00% - 78.57% (B) Type Fair Value at December 31, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 29,459 $ 31,733 Discounted Cash Flow Forward price (per dt) $(0.77) - $10.00 [$2.15] (A) Forward Contract - Electric $ 29,136 $ 27,494 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.20%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.80%] (B) (A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas. (B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak.
Changes in Measurements Using Significant Unobservable Inputs	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2016 and 2015 , using significant unobservable inputs (Level 3), are as follows (in thousands): Year Ended December 31, 2016 Balance at January 1, 2016 $ (632 ) Other changes in fair value from continuing and new contracts, net 5,657 Transfers in to/(out of) of Level 3 (A) 4,116 Settlements (106 ) Balance at December 31, 2016 $ 9,035 Year Ended December 31, 2015 Balance at January 1, 2015 $ (5,608 ) Other changes in fair value from continuing and new contracts, net (5,069 ) Transfers in to/(out of) of Level 3 (A) 7,402 Settlements 2,643 Balance at December 31, 2015 $ (632 ) (A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the years ended December 31, 2016 and 2015, $4.1 million and $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management.

ACCUMULATED OTHER COMPREHENSI46

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Summary of Changes	The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2016 (in thousands): Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Other Comprehensive Income (Loss) of Affiliated Companies Total Balance at January 1, 2016 (a) $ (22,145 ) $ (2,129 ) $ (128 ) $ (97 ) $ (24,499 ) Other comprehensive income before reclassifications (5,617 ) — 323 — (5,294 ) Amounts reclassified from AOCL (b) 2,420 197 (205 ) — 2,412 Net current period other comprehensive income (3,197 ) 197 118 — (2,882 ) Balance at December 31, 2016 (a) $ (25,342 ) $ (1,932 ) $ (10 ) $ (97 ) $ (27,381 ) (a) Determined using a combined average statutory tax rate of 40% . (b) See table below. The following table provides details about reclassifications out of AOCL for the year ended December 31, 2016 (in thousands): Amounts Reclassified from AOCL Affected Line Item in the Statements of Consolidated Income For the Year Ended December 31, 2016 Actuarial Loss on Postretirement Benefits $ 4,001 Operating Expenses: Operations Income Taxes (1,581 ) Income Taxes (a) $ 2,420 Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 333 Interest Charges Income Taxes (136 ) Income Taxes (a) $ 197 Unrealized Gain on Available-for-Sale Securities $ (342 ) Other Income Income Taxes 137 Income Taxes (a) $ (205 ) Losses from reclassifications for the period net of tax $ 2,412 (a) Determined using a combined average statutory tax rate of 40% .

Quarterly Financial Data (Una47

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

SUMMARY OF SIGNIFICANT ACCOUN48

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	May 08, 2015	Feb. 26, 2015shares	Jun. 30, 2015USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2016USD ($)countymishares	Dec. 31, 2015USD ($)shares	Feb. 25, 2015shares
Accounting Policies [Abstract]
Number of counties in which entity operates | county							7
Length of natural gas pipeline (in miles) | mi							100
Common stock, authorized (in shares) | shares		120,000,000					120,000,000	120,000,000	60,000,000
Stock split, conversion ratio	2	2
Public Utilities Assessment (PUA) included in utility revenue and energy and other taxes				$ 1,100,000	$ 1,200,000	$ 1,100,000
Composite annual rate for all depreciable utility property				2.20%	2.20%	2.20%
Useful life				50 years
Interest capitalized				$ 6,600,000	$ 4,900,000	$ 4,600,000
Impairment of nonutility property and equipment and other noncurrent assets				0	0	0
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization							$ 8,800,000	$ 8,900,000
Treasury stock held (in shares) | shares							212,617	236,571
Schedule of Equity Method Investments [Line Items]
Impairment losses				0		0
Gross book value of utility plant							$ 2,424,134,000	$ 2,211,239,000
Book value of nonutility property and equipment							821,942,000	785,646,000
Accumulated depreciation for utility property and equipment							471,222,000	440,473,000
Accumulated depreciation for nonutility property and equipment							151,084,000	108,307,000
Intangible assets							15,820,000	21,553,000
Increase (decrease) in intangible assets				(5,700,000)
Increase (decrease) adjustment related to purchase price allocations				(4,600,000)
Amortization expense				1,100,000	0
Goodwill				8,880,000	8,880,000		4,838,000	8,880,000
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs (beginning balance)				57,943,000	42,502,000
Accretion				1,937,000	1,675,000
Additions				1,098,000	802,000
Settlements				(1,551,000)	(1,110,000)
Revisions in Estimated Cash Flows				0	14,074,000
AROs (ending balance)				59,427,000	57,943,000	$ 42,502,000
Goodwill [Roll Forward]
Beginning Balance				8,880,000
Fair Value Adjustments During Measurement Period (See Note 3)				(4,042,000)
Ending Balance				4,838,000	8,880,000
Noncurrent Assets
Schedule of Equity Method Investments [Line Items]
Intangible assets							15,800,000	21,600,000
Goodwill				8,900,000	8,900,000		4,800,000	$ 8,900,000
Goodwill [Roll Forward]
Beginning Balance				8,900,000
Ending Balance				$ 4,800,000	8,900,000
Minimum
Schedule of Equity Method Investments [Line Items]
Useful life of intangible assets				2 years
Maximum
Schedule of Equity Method Investments [Line Items]
Useful life of intangible assets				20 years
Energenic
Schedule of Equity Method Investments [Line Items]
Impairment losses			$ 7,700,000		$ 7,700,000
Solar assets
Schedule of Equity Method Investments [Line Items]
Book value of nonutility property and equipment							652,800,000
Cogeneration assets
Schedule of Equity Method Investments [Line Items]
Book value of nonutility property and equipment							124,200,000
Other property and equipment
Schedule of Equity Method Investments [Line Items]
Book value of nonutility property and equipment							$ 44,900,000

STOCK-BASED COMPENSATION PLAN49

STOCK-BASED COMPENSATION PLAN (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Fair Value Per Share (in USD per share)	$ 26.89	$ 26.89		$ 24.96	$ 26.89
Expected volatility, measurement period	3 years
Service period of shares	3 years
Net Expense	$ 3,507	$ 1,681	$ 1,746
Capitalized	$ (385)	$ (216)	(147)
Unrecognized compensation cost of awards granted under the plan				$ 4,000
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	1 year 8 months 12 days
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)	$ 26.89
Granted (in USD per share)	23.28
Vested (in USD per share)	25.69
Cancelled/Forfeited (in USD per share)	25.11
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 24.96	$ 26.89
Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ 3,892	$ 1,897	1,893
EPS | Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ (100)	$ (1,200)	$ (1,100)
Officers and other key employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	194,347	158,929	136,526
Actual amount of shares that ultimately vest of the original share units granted, minimum	0.00%
Actual amount of shares that ultimately vest of the original share units granted, maximum	200.00%
Shares Outstanding (in shares)	226,191	226,191		295,515	226,191
Number of shares awarded during the period (in shares)	13,247	0	0
Market value of shares awarded (in shares)	$ 300
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	226,191
Granted (in shares)	194,347	158,929	136,526
Vested (in shares)	(113,917)
Cancelled/Forfeited (in shares)	(11,106)
Nonvested Shares Outstanding, ending balance (in shares)	295,515	226,191
Expected number of shares to be awarded (in shares)				29,044
Officers and other key employees | Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ 3,051	$ 1,128	$ 1,260
Officers and other key employees | 2015 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	33,537	33,537			33,537
Fair Value Per Share (in USD per share)	$ 26.31	$ 26.31			$ 26.31
Expected Volatility		16.00%
Risk-Free Interest Rate		1.10%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	33,537
Nonvested Shares Outstanding, ending balance (in shares)		33,537
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)	$ 26.31
Nonvested Shares Outstanding, ending balance (in USD per share)		$ 26.31
Officers and other key employees | 2015 - EGR, ROE, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	73,118	73,118			73,118
Fair Value Per Share (in USD per share)	$ 29.47	$ 29.47			$ 29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	73,118
Nonvested Shares Outstanding, ending balance (in shares)		73,118
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)	$ 29.47
Nonvested Shares Outstanding, ending balance (in USD per share)		$ 29.47
Officers and other key employees | 2016 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	66,101			66,101
Fair Value Per Share (in USD per share)	$ 22.53			$ 22.53
Expected Volatility	18.10%
Risk-Free Interest Rate	1.31%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	66,101
Weighted Average Fair Value
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 22.53
Officers and other key employees | 2016 - CEGR, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	122,759			122,759
Fair Value Per Share (in USD per share)	$ 23.52			$ 23.52
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	122,759
Weighted Average Fair Value
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 23.52
Directors
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	35,197
Vesting period of shares	12 months
Shares Outstanding (in shares)	26,338	26,338		35,197	26,338
Market value of shares awarded (in shares)	$ 800	$ 800	600
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	26,338
Granted (in shares)	35,197
Vested (in shares)	(26,338)
Cancelled/Forfeited (in shares)	0
Nonvested Shares Outstanding, ending balance (in shares)	35,197	26,338
Directors | Total Cost
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense	$ 841	$ 769	$ 633
Directors | 2016
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	35,197			35,197
Fair Value Per Share (in USD per share)	$ 23.88			$ 23.88
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	35,197
Weighted Average Fair Value
Nonvested Shares Outstanding, ending balance (in USD per share)	$ 23.88
2015 Omnibus Equity Compensation Plan
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of options granted (in shares)	0	0	0
Number of options outstanding (in shares)			0	0	0
Performance-based restricted shares
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Return on equity award threshold		7.00%
Performance-based restricted shares | Officers and other key employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares	3 years
Stock appreciation rights
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	0	0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)	0	0	0
Restricted stock
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Return on equity award threshold	7.00%
Restricted stock | Officers and other key employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	58,304	47,678
Vesting period of shares		3 years
Payout limit, percentage		100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)	58,304	47,678
Restricted stock | Directors
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)	35,197	26,338	23,220
Percent of shares granted that generally vest				100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)	35,197	26,338	23,220
Restricted stock | Tranche Two
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Service period of shares		2 years
Restricted stock | Tranche Three
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Service period of shares		3 years
Performance shares | 2012 and 2013 Grants
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares	3 years

AFFILIATIONS AND DISCONTINUED50

AFFILIATIONS AND DISCONTINUED OPERATIONS - AFFILIATIONS (Details) $ in Thousands	Dec. 31, 2015USD ($)investmentagreement	Dec. 31, 2016USD ($)mi	Dec. 31, 2015USD ($)investmentagreement	Dec. 31, 2014USD ($)	Dec. 31, 2011
Affiliations [Abstract]
Notes receivable from affiliate	$ 16,400	$ 15,700	$ 16,400
Notes receivable from affiliate, current	3,134	$ 2,461	3,134
Length of natural gas pipeline (in miles) | mi		100
Net investments in unconsolidated affiliates		$ 7,500	18,000	$ 2,400
Notes receivable secured by property, plant, and equipment of affiliates		$ 13,600
Interest accrual on secured notes receivable		7.50%
Unsecured notes receivable		$ 2,100
Net asset - included in investment in affiliates and other noncurrent liabilities		28,900
Combined equity contributions and the notes receivable - affiliate		44,600
Equity Method Investment, Summarized Financial Information [Abstract]
Goodwill	$ 8,880	$ 4,838	$ 8,880
Energenic
Affiliations [Abstract]
Equity interest					50.00%
Potato Creek
Affiliations [Abstract]
Equity interest		30.00%
PennEast
Affiliations [Abstract]
Length of natural gas pipeline (in miles) | mi		100
Marina Energy LLC | Energenic
Affiliations [Abstract]
Equity interest				50.00%
Number of distribution and purchase agreements | agreement	2		2
Number of investments owned | investment	8		8
Notes receivable from affiliate	$ 19,500		$ 19,500
Notes receivable from affiliate, current		$ 1,500
Percentage of fair value of assets acquired and liabilities assumed	100.00%		100.00%
Consideration received	$ 46,000
Fair value of the interest in Partner Projects exchanged	14,500
Equity Method Investment, Summarized Financial Information [Abstract]
Current assets (excluding inventory)	7,804		$ 7,804
Inventory	3,154		3,154
Note Receivable Received	19,504		19,504
Fixed Assets	46,460		46,460
Identifiable Intangibles	16,950		16,950
Goodwill	4,838		4,838
Noncurrent assets	4,783		4,783
Current liabilities	(8,196)		(8,196)
Note Payable - Affiliate	(16,986)		(16,986)
Long-Term Debt, including current portion	(21,642)		(21,642)
Capital Lease Payable	(10,458)		(10,458)
Other Non-Current Liabilities	(181)		(181)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects	$ 46,030		$ 46,030
Marina Energy LLC | Energenic | Co-venturer
Affiliations [Abstract]
Number of investments owned | investment	7		7
Fair value of the interest in Partner Projects exchanged	$ 31,500
Midstream | PennEast
Affiliations [Abstract]
Equity interest		20.00%

AFFILIATIONS AND DISCONTINUED51

AFFILIATIONS AND DISCONTINUED OPERATIONS - OPERATING RESULTS OF DISCONTINUED OPERATIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Loss before Income Taxes: [Abstract]
Income Tax Benefits									$ 133	$ 257	$ 312
Loss from Discontinued Operations - (Net of tax benefit)	$ (75)	$ (29)	$ (29)	$ (118)	$ (62)	$ (91)	$ (74)	$ (276)	$ (251)	$ (503)	$ (582)
Earnings Per Common Share from Discontinued Operations - Net
Basic and Diluted (in USD per share)									$ 0	$ (0.01)	$ (0.01)
Sand Mining
Loss before Income Taxes: [Abstract]
Loss before Income Taxes									$ (205)	$ (422)	$ (620)
Fuel Oil
Loss before Income Taxes: [Abstract]
Loss before Income Taxes									$ (179)	$ (338)	$ (274)

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Tax at Statutory Rate									$ 60,624	$ 37,440	$ 35,727
Increase (Decrease) Resulting from:
State Income Taxes									6,438	3,985	1,960
ESOP Dividend									(1,300)	(1,298)	(1,232)
Amortization of Investment Tax Credits - Utility									0	(149)	(211)
AFUDC									(900)	(1,109)	(1,481)
Investment and Other Tax Credits									(10,706)	(37,503)	(30,661)
Other - Net									(5)	(6)	347
Income Taxes: Continuing Operations	$ 19,266	$ 2,807	$ (7,189)	$ 39,267	$ (1,006)	$ (10,968)	$ (3,279)	$ 16,613	54,151	1,360	4,449
Income Taxes: Discontinued Operations									(133)	(257)	(312)
Total Income Tax Expense									54,018	1,103	4,137
Current:
Federal									0	0	(62)
State									(1,638)	(2,352)	3,052
Total Current									(1,638)	(2,352)	2,990
Deferred:
Federal									44,246	(4,622)	1,707
State									11,543	8,483	(37)
Total Deferred									55,789	3,861	1,670
Investment Tax Credit - Utility									0	(149)	(211)
Income Taxes: Continuing Operations	19,266	$ 2,807	$ (7,189)	39,267	(1,006)	$ (10,968)	$ (3,279)	16,613	54,151	1,360	4,449
Income Taxes: Discontinued Operations									$ (133)	(257)	(312)
Annual amortization rate of investment tax credits									3.00%
Deferred Tax Assets:
Net Operating Loss Carryforward												$ 211,004	$ 195,358
Investment and Other Tax Credits												213,946	200,491
Derivatives / Unrealized Gain												0	5,652
Deferred State Tax												28,833	24,833
Pension & Other Post Retirement Benefits												19,351	29,998
Deferred Revenues												7,669	4,924
Provision for Uncollectibles												5,231	4,200
Other												8,368	6,448
Total Deferred Tax Asset												494,402	471,904
Deferred Tax Liabilities:
Book versus Tax Basis of Property												732,535	675,521
Deferred Gas Costs - Net												2,052	3,998
Derivatives / Unrealized Loss												1,794	0
Environmental Remediation												32,885	19,207
Deferred Regulatory Costs												1,554	566
Budget Billing - Customer Accounts												3,347	830
Deferred Pension & Other Post Retirement Benefits												34,432	42,216
Conservation Incentive Program												11,846	1,132
Equity In Loss Of Affiliated Companies												3,092	9,111
Other												14,414	15,268
Total Deferred Tax Liability												837,951	767,849
Deferred Tax Liability - Net												343,549	295,945
Research and development credits												3,300
Unrecognized tax benefits	1,445			559	559			552	$ 559	552	547	1,445	559	$ 552
Accrued interest and penalties on unrecognized tax benefits												700	$ 700	$ 700
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance (beginning)				$ 559				$ 552	559	552	547
Increase as a result of tax positions taken in prior years									886	7	5
Balance (ending)	$ 1,445				$ 559				$ 1,445	$ 559	$ 552
Federal
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												557,678
Investment Tax Credit Carryforward												209,424
Alternative minimum tax credits												1,200
Federal | 2030
Deferred Tax Liabilities:
Investment Tax Credit Carryforward												11,628
Federal | 2031
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												163,572
Investment Tax Credit Carryforward												25,664
Federal | 2032
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												42,988
Investment Tax Credit Carryforward												32,071
Federal | 2033
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												67,496
Investment Tax Credit Carryforward												45,606
Federal | 2034
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												119,122
Investment Tax Credit Carryforward												37,699
Federal | 2035
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												70,992
Investment Tax Credit Carryforward												45,097
Federal | 2036
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												93,508
Investment Tax Credit Carryforward												11,659
State
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												220,013
State | 2031
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												45,866
State | 2032
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												19,356
State | 2033
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												34,940
State | 2034
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												28,622
State | 2035
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												9,860
State | 2036
Deferred Tax Liabilities:
Net Operating Loss Carryforwards												$ 81,369

PREFERRED STOCK (Details)

PREFERRED STOCK (Details)	Dec. 31, 2016shares
Equity [Abstract]
Number of authorized shares of Preference Stock (in shares)	2,500,000

COMMON STOCK (Details)

COMMON STOCK (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	May 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning of Year (in shares)		70,965,622	68,334,860	65,430,084
New Issues During Year:
Dividend Reinvestment Plan (in shares)		417,095	2,604,424	2,881,556
Stock-Based Compensation Plan (in shares)		45,338	26,338	23,220
Public Equity Offering (in shares)	8,050,000	8,050,000	0	0
End of Year (in shares)		79,478,055	70,965,622	68,334,860
Par value of common stock (in USD per share)	$ 1.25	$ 1.25	$ 1.25
Net excess over par value recorded in premium on common stock		$ 207,500
Proceeds from issuance of common stock	$ 203,600	$ 214,426	$ 63,192	$ 80,680
Incremental shares included in diluted earnings per share (in shares)		112,590	195,139	150,062
Dividend per share (in USD per share)		$ 1.07	$ 1.02	$ 0.96
Equity capital raised through Dividend Reinvestment Plan		$ 10,800

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details)	1 Months Ended	3 Months Ended			12 Months Ended
	Jun. 30, 2015USD ($)term	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)term	Dec. 31, 2016USD ($)counterparty	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2011
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity investment impairments					$ 0		$ 0
Investment in Affiliate					$ 28,906,000	$ 16,983,000
Number of counterparties | counterparty					3
Carrying amount of long-term debt, including current maturities					$ 1,047,482,000	1,035,848,000
Unamortized debt issuance costs					7,600,000	9,000,000
Derivatives-Energy Related Assets | Supplier concentration risk
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current and noncurrent derivatives					$ 9,300,000
Percentage of current and noncurrent derivatives					11.50%
Atlantic City Note Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Amount of advance	$ 10,000,000			$ 10,000,000
Interest rate of advance	1.00%
Term of loans	6 months
Number of additional terms | term	2			2
Extension term	3 months
Energenic
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest								50.00%
Contract term								20 years
Equity investment impairments				$ 7,700,000		7,700,000
Share of settlement					$ 7,500,000
Associated costs					7,000,000
Investment in Affiliate					600,000
Notes receivable due from Affiliate					$ 13,600,000
Energenic | Other Income
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds received			$ 2,100,000
Energenic | Equity in Earnings of Affiliated Companies
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds received		$ 5,300,000
Marina Energy LLC | Energenic
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest							50.00%
ACB Energy Partners, LLC
Accounts, Notes, Loans and Financing Receivable [Line Items]
Debt service reserve						1,700,000
South Jersey Gas Company | Minimum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Term of loans					5 years
South Jersey Gas Company | Maximum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Term of loans					10 years
Level 1
Accounts, Notes, Loans and Financing Receivable [Line Items]
Margin accounts with selected counterparties to support risk management activities					$ 11,700,000	43,700,000
Level 1 | Marina Energy LLC
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held in escrow					1,900,000	3,400,000
Level 2
Accounts, Notes, Loans and Financing Receivable [Line Items]
Fair value of long-term debt, including current maturities					1,080,800,000	1,079,000,000
Carrying amount of long-term debt, including current maturities					1,039,900,000	1,026,900,000
Level 2 | South Jersey Gas Company | Financing receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Long-term receivables, net of unamortized discount					9,500,000	12,900,000
Imputed interest on long term receivables					$ 900,000	$ 1,300,000

SEGMENTS OF BUSINESS (Details)

SEGMENTS OF BUSINESS (Details) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)investment	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2016USD ($)category	Dec. 31, 2015USD ($)investment	Dec. 31, 2014USD ($)
Segment Reporting Information [Line Items]
Operating Revenues	$ 329,981	$ 219,082	$ 154,402	$ 333,035	$ 257,844	$ 141,062	$ 177,710	$ 382,952	$ 1,036,500	$ 959,568	$ 886,996
Operating Income (Loss)									189,276	156,894	127,603
Depreciation and Amortization									109,818	91,042	78,511
Interest Charges									31,449	31,622	29,560
Income Taxes	19,266	$ 2,807	$ (7,189)	$ 39,267	(1,006)	$ (10,968)	$ (3,279)	$ 16,613	54,151	1,360	4,449
Property Additions									269,689	361,994	339,469
Identifiable Assets	3,730,567				$ 3,471,933				3,730,567	3,471,933
Marina Energy LLC | Energenic
Segment Reporting Information [Line Items]
Property, Plant and Equipment obtained through acquisition									$ 5,600	$ 40,900
Number of acquired projects (in investments) | investment					8					8
Energy Group and Energy Services
Segment Reporting Information [Line Items]
Number of Operating Segments | category									2
Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues									$ 1,094,093	$ 1,006,642	926,518
Interest Charges									42,304	40,523	36,036
Operating Segments | Gas Utility Operations
Segment Reporting Information [Line Items]
Operating Revenues									461,055	534,290	501,875
Operating Income (Loss)									122,455	119,585	113,690
Depreciation and Amortization									63,901	58,668	52,155
Interest Charges									17,875	19,906	17,872
Income Taxes									39,366	36,945	34,895
Property Additions									228,275	218,260	201,737
Identifiable Assets	2,551,923				$ 2,281,576				2,551,923	2,281,576
Operating Segments | Energy Group
Segment Reporting Information [Line Items]
Operating Revenues									495,618	366,345	327,822
Operating Income (Loss)									53,354	32,848	9,506
Depreciation and Amortization									821	596	251
Interest Charges									350	626	638
Income Taxes									20,862	13,858	5,419
Property Additions									1,649	2,435	1,439
Identifiable Assets	327,028				342,299				327,028	342,299
Operating Segments | Energy Group | Wholesale Energy Operations
Segment Reporting Information [Line Items]
Operating Revenues									220,707	129,098	77,048
Operating Income (Loss)									41,667	35,024	9,493
Depreciation and Amortization									484	435	168
Interest Charges									0	441	371
Income Taxes									15,882	14,410	4,822
Property Additions									7	382	18
Identifiable Assets	233,019				231,660				233,019	231,660
Operating Segments | Energy Group | Retail Gas and Other Operations
Segment Reporting Information [Line Items]
Operating Revenues									92,371	87,198	127,001
Operating Income (Loss)									4,680	(3,218)	479
Depreciation and Amortization									337	161	83
Interest Charges									350	185	267
Income Taxes									2,118	(978)	787
Property Additions									1,642	2,053	1,421
Identifiable Assets	52,729				55,111				52,729	55,111
Operating Segments | Energy Group | Retail Electric Operations
Segment Reporting Information [Line Items]
Operating Revenues									182,540	150,049	123,773
Operating Income (Loss)									7,007	1,042	(466)
Income Taxes									2,862	426	(190)
Identifiable Assets	41,280				55,528				41,280	55,528
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Operating Revenues									102,273	74,851	66,647
Operating Income (Loss)									13,883	2,495	2,922
Depreciation and Amortization									43,696	30,558	25,289
Income Taxes									(6,121)	(49,039)	(36,181)
Property Additions									38,624	139,397	132,298
Identifiable Assets	770,589				795,116				770,589	795,116
Operating Segments | Energy Services | On-Site Energy Production
Segment Reporting Information [Line Items]
Operating Revenues									94,375	63,665	56,129
Operating Income (Loss)									13,301	2,027	2,560
Depreciation and Amortization									43,395	30,242	25,020
Interest Charges									11,961	8,169	8,723
Income Taxes									(6,353)	(49,225)	(36,404)
Property Additions									38,193	139,018	132,214
Identifiable Assets	767,710				790,231				767,710	790,231
Operating Segments | Energy Services | Appliance Service Operations
Segment Reporting Information [Line Items]
Operating Revenues									7,898	11,186	10,518
Operating Income (Loss)									582	468	362
Depreciation and Amortization									301	316	269
Income Taxes									232	186	223
Property Additions									431	379	84
Identifiable Assets	2,879				4,885				2,879	4,885
Operating Segments | Corporate & Services
Segment Reporting Information [Line Items]
Operating Revenues									35,147	31,156	30,174
Operating Income (Loss)									(416)	1,966	1,485
Depreciation and Amortization									1,400	1,220	816
Interest Charges									12,118	11,822	8,803
Income Taxes									44	(404)	316
Property Additions									1,141	1,902	3,995
Identifiable Assets	649,795				652,325				649,795	652,325
Intersegment
Segment Reporting Information [Line Items]
Operating Revenues									(57,593)	(47,074)	(39,522)
Interest Charges									(10,855)	(8,901)	$ (6,476)
Identifiable Assets	(570,524)				(600,928)				(570,524)	(600,928)
Discontinued Operations
Segment Reporting Information [Line Items]
Identifiable Assets	$ 1,756				$ 1,545				$ 1,756	$ 1,545

LEASES - OPERATING (Details)

LEASES - OPERATING (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Operating Leases, Future Minimum Payments Receivable [Abstract]
2,017	$ 5,396
2,018	5,396
2,019	5,396
2,020	5,396
2,021	5,396
Thereafter	29,230
Total minimum future rentals	56,210
Thermal energy generating property and equipment
Property Subject to or Available for Operating Lease, Net [Abstract]
Property and equipment under operating lease	75,900	$ 78,200
Accumulated depreciation of property and equipment under operating lease	$ 31,400	$ 28,500

LEASES - CAPITAL (Details)

LEASES - CAPITAL (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015
Capital Leased Assets [Line Items]
Useful life		50 years
Accumulated depreciation on capital lease	$ 471,222	$ 471,222	$ 440,473
Facilities and equipment
Capital Leased Assets [Line Items]
Interest rate		6.80%
Carrying costs of the capital lease			4,100
Purchase price of respective assets	10,600
Accumulated depreciation on capital lease	$ 200	$ 200	$ 0
Minimum | Facilities and equipment
Capital Leased Assets [Line Items]
Useful life		7 years
Maximum | Facilities and equipment
Capital Leased Assets [Line Items]
Useful life		39 years

RATES AND REGULATORY ACTIONS (D

RATES AND REGULATORY ACTIONS (Details) $ in Thousands	Oct. 01, 2016USD ($)	Feb. 29, 2016USD ($)	Oct. 01, 2014	Oct. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jul. 31, 2016USD ($)	Jun. 30, 2016USD ($)	Apr. 30, 2016USD ($)	Feb. 29, 2016USD ($)	Aug. 31, 2015USD ($)	Jul. 31, 2015USD ($)	Jun. 30, 2015USD ($)	Apr. 30, 2015USD ($)	Jan. 31, 2015USD ($)	Sep. 30, 2014USD ($)	Aug. 31, 2014USD ($)	Jul. 31, 2014USD ($)	May 31, 2014USD ($)	Sep. 30, 2013USD ($)	Feb. 28, 2013USD ($)	Jan. 31, 2009USD ($)	Dec. 31, 2016USD ($)sitecustomer	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Dec. 31, 2016USD ($)sitecustomer	Jan. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jan. 31, 2014USD ($)	Jun. 30, 2013USD ($)
Schedule of Capitalization [Line Items]
Approved base rate increase															$ 20,000
Rate of return on base rate															7.10%
Return on common equity															9.75%
Composite depreciation rate			2.10%																						2.40%
Amount of AIRP																				$ 141,200
Term of AIRP																				4 years
Annual investment amount of AIRP																				$ 35,300
Investment amount of SHARP																$ 103,500			$ 280,000					$ 36,600
Term of SHARP																3 years			7 years
Number of sites for environmental cleanup (in sites) | site																						12				12
Regulatory assets																						$ 410,746				$ 410,746		$ 323,434
Number of customers purchasing energy commodity from another entity | customer																						33,467				33,467
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							$ (800)
Approved request for revenue increase (decrease)		$ (7,900)							$ (7,900)
Regulatory assets																						$ 219				$ 219		496
Environmental Remediation Costs: Expended - Net
Schedule of Capitalization [Line Items]
Regulatory assets																						71,997				71,997		42,032
Deferred pipeline integrity costs
Schedule of Capitalization [Line Items]
Regulatory assets																						4,000				4,000		2,700
New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Approved requested rate increase (decrease)				$ 11,000
Roll of AIRP investments into base rates																						80,200
Approved budget					$ 56,000
South Jersey Gas Company | Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Approved requested rate increase (decrease)				(1,600)
South Jersey Gas Company | Storm Hardening and Reliability Program | Building
Schedule of Capitalization [Line Items]
Investments during the period																							$ 33,700
South Jersey Gas Company | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Authorized replacement investments (up to)				$ 302,500
Approved budget					5,600
Increase (decrease) in Universal Service Fund recoveries	$ 1,100
South Jersey Gas Company | New Jersey Board of Public Utilities | Storm Hardening and Reliability Program
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates								$ 4,300
Approved requested rate increase (decrease)					3,900
Accelerated Infrastructure Replacement Program
Schedule of Capitalization [Line Items]
Approved base rate increase															$ 7,500
Requested increase (decrease) in rates									13,000
Amount of AIRP									$ 500,000
Investments to be rolled to base rate															69,900										$ 69,900
Extension period of AIRP, requested and then received		7 years		5 years
Basic Gas Supply Service
Schedule of Capitalization [Line Items]
Bill credits																															$ 11,200
Percent of increase (decrease) in regulatory costs not yet approved																		9.30%
Amount of increase (decrease) in regulatory costs approved															27,000										27,000				$ (28,400)
Requested increase (decrease) in rates												$ (28,400)						$ 27,000
Basic Gas Supply Service | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Approved requested rate increase (decrease)					$ (47,100)
Basic Gas Supply Service | South Jersey Gas Company
Schedule of Capitalization [Line Items]
Bill credits																						$ 10,000				$ 10,000	$ 20,000
Basic Gas Supply Service | South Jersey Gas Company | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							(47,100)
Conservation Incentive Program
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							46,500					(11,300)						(21,800)
Conservation Incentive Program | Non-weather
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							9,900					(8,800)						4,200
Conservation Incentive Program | Weather
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates							36,600					(2,500)						(26,000)
Allowance for Funds Used Under Construction
Schedule of Capitalization [Line Items]
Approved base rate increase				$ 5,700											3,200
Storm Hardening and Reliability Program
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs approved																													4,000
Requested increase (decrease) in rates													$ 4,000
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs approved										$ 2,600					2,200										2,200
Requested increase (decrease) in rates												(7,600)		$ 56,000				$ 1,400
Period of program																					2 years
Extension period										2 years
Amount of regulatory costs available for recovery										$ 36,300											$ 17,000
Energy Efficiency Tracker | South Jersey Gas Company
Schedule of Capitalization [Line Items]
Amount of regulatory costs available for recovery																																$ 24,000
Societal Benefits Clause
Schedule of Capitalization [Line Items]
Requested increase (decrease) in rates						$ 16,000					$ (5,000)						$ (25,700)
Remediation Adjustment Clause
Schedule of Capitalization [Line Items]
Number of sites for environmental cleanup (in sites) | site																						12				12
Amortization period																						7 years
Regulated costs recovered																										$ 112,700
Remediation Adjustment Clause | Environmental Remediation Costs: Expended - Net
Schedule of Capitalization [Line Items]
Regulatory assets																						$ 72,000				$ 72,000		$ 42,000
New Jersey Clean Energy Program
Schedule of Capitalization [Line Items]
Amount of statewide funding approved							345,000					345,000											345,000	345,000						$ 345,000		345,000
Regulatory costs entity is expensing							14,600					14,600											14,600	14,600						14,500		$ 14,500
Universal Service Fund
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs approved															7,900										7,900				5,200
Amount of statewide funding approved															71,800										71,800				46,400
Amount of statewide costs proposed							56,000					(46,400)											56,000	(46,400)						19,900
Amount of proposed impact of annual costs							$ 1,100					$ (3,400)											$ 1,100	$ (3,400)					$ (3,400)	$ 2,600
Amount of increase (decrease) in annual impact approved															$ 2,600										$ 2,600

REGULATORY ASSETS & REGULATOR60

REGULATORY ASSETS & REGULATORY LIABILITIES - ASSETS (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)siteasset	Dec. 31, 2015USD ($)
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 410,746	$ 323,434
Number regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or their predecessors previously operated gas manufacturing plants (in regulatory assets) | asset	2
Number of sites where SJG or their predecessors previously operated gas manufacturing plants (in sites) | site	12
Environmental Remediation Costs: Expended - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 71,997	42,032
Environmental Restoration Costs: Liability for Future Expenditures
Regulatory Assets [Line Items]
Total Regulatory Assets	153,047	123,194
Deferred Asset Retirement Obligation Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	43,014	42,430
Deferred Pension and Other Postretirement Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	85,693	79,779
Deferred Gas Costs - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	0	2,701
Conservation Incentive Program Receivable
Regulatory Assets [Line Items]
Total Regulatory Assets	27,567	2,624
Deferred Interest Rate Contracts
Regulatory Assets [Line Items]
Total Regulatory Assets	7,365	7,631
Energy Efficiency Tracker
Regulatory Assets [Line Items]
Total Regulatory Assets	219	496
Pipeline Supplier Service Charges
Regulatory Assets [Line Items]
Total Regulatory Assets	2,122	3,776
Pipeline Integrity Cost
Regulatory Assets [Line Items]
Total Regulatory Assets	4,810	4,596
AFUDC - Equity Related Deferrals
Regulatory Assets [Line Items]
Total Regulatory Assets	12,434	11,423
Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 2,478	$ 2,752
Environmental restoration costs
Regulatory Assets [Line Items]
Regulatory costs, original recovery period of expenditures	7 years
Allowance for Funds Used Under Construction, Equity Related Deferrals, settlement
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 1,000
Regulatory costs, original recovery period of expenditures	3 years

REGULATORY ASSETS & REGULATOR61

REGULATORY ASSETS & REGULATORY LIABILITIES - LIABILITIES (Details) - USD ($) $ in Thousands	1 Months Ended
	Sep. 30, 2014	Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		$ 49,121	$ 42,841
Regulatory assets		410,746	323,434
Deferred Revenue - Net
Regulatory Liabilities [Line Items]
Regulatory assets			2,701
Excess Plant Removal Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		28,226	32,644
Annual amortization reflected in depreciation expense	$ 1,100
Deferred Revenue - Net
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		17,800	0
Societal Benefit Costs Payable
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities		$ 3,095	$ 10,197

PENSION AND OTHER POSTRETIREM62

PENSION AND OTHER POSTRETIREMENT BENEFITS - NET PERIODIC BENEFIT COST (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Percentage of employees entitled to annuity payments upon retirement	38.20%
Pension Benefits
Net periodic benefit cost [Abstract]
Service Cost	$ 4,843	$ 5,337	$ 4,510
Interest Cost	12,125	11,168	10,735
Expected Return on Plan Assets	(13,508)	(14,789)	(13,491)
Amortizations:
Prior Service (Credits) Cost	212	212	175
Actuarial Loss	9,394	10,608	5,716
Net Periodic Benefit Cost	13,066	12,536	7,645
Capitalized Benefit Costs	(4,645)	(4,805)	(3,047)
Deferred Benefit Costs	(645)	(1,007)	0
Total Net Periodic Benefit Expense	7,776	6,724	4,598
Other Postretirement Benefits
Net periodic benefit cost [Abstract]
Service Cost	851	1,116	891
Interest Cost	2,615	2,973	2,852
Expected Return on Plan Assets	(3,104)	(2,993)	(2,603)
Amortizations:
Prior Service (Credits) Cost	(344)	608	152
Actuarial Loss	1,109	1,342	974
Net Periodic Benefit Cost	1,127	3,046	2,266
Capitalized Benefit Costs	(277)	(1,043)	(722)
Deferred Benefit Costs	0	(256)	0
Total Net Periodic Benefit Expense	$ 850	$ 1,747	$ 1,544

PENSION AND OTHER POSTRETIREM63

PENSION AND OTHER POSTRETIREMENT BENEFITS - DETAILS OF ACTIVITY WITHIN THE REGULATORY ASSET AND ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Pension Benefits
Regulatory Assets
Beginning Balance	$ 64,432	$ 71,177
Amounts Arising during the Period: Net Actuarial (Loss) Gain	9,706	(463)
Amounts Arising during the Period: Prior Service Credit	0
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(5,485)	(6,079)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	(203)	(203)
Ending Balance	68,450	64,432
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	35,066	39,468
Amounts Arising during the Period: Net Actuarial (Loss) Gain	8,370	59
Amounts Arising during the Period: Prior Service Credit	0
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(3,838)	(4,452)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	(8)	(9)
Ending Balance	39,590	35,066
Other Postretirement Benefits
Regulatory Assets
Beginning Balance	15,347	27,863
Amounts Arising during the Period: Net Actuarial (Loss) Gain	2,584	(3,155)
Amounts Arising during the Period: Prior Service Credit	257	(499)
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(945)	(1,107)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	0	(7,755)
Ending Balance	17,243	15,347
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	2,062	6,755
Amounts Arising during the Period: Net Actuarial (Loss) Gain	829	(2,285)
Amounts Arising during the Period: Prior Service Credit	84	(106)
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(154)	(221)
Amounts Amortized to Net Periodic Costs: Prior Service Cost	0	(2,081)
Ending Balance	$ 2,821	$ 2,062

PENSION AND OTHER POSTRETIREM64

PENSION AND OTHER POSTRETIREMENT BENEFITS - ESTIMATED COSTS THAT WILL BE AMORTIZED (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Pension Benefits
Regulatory Assets into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	$ 127
Net Actuarial Loss	6,202
Accumulated Other Comprehensive Income (Loss) into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	5
Net Actuarial Loss	3,943
Other Postretirement Benefits
Regulatory Assets into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	(257)
Net Actuarial Loss	1,040
Accumulated Other Comprehensive Income (Loss) into Net Periodic Benefit Costs
Prior Service Cost/(Credit)	(87)
Net Actuarial Loss	$ 207

PENSION AND OTHER POSTRETIREM65

PENSION AND OTHER POSTRETIREMENT BENEFITS - RECONCILIATIONS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$ (2,463)	$ (2,261)
Noncurrent Liabilities	(95,235)	(76,068)
Pension Benefits
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	254,195	265,434
Service Cost	4,843	5,337	$ 4,510
Interest Cost	12,125	11,168	10,735
Actuarial Loss (Gain)	18,254	(17,349)
Retiree Contributions	0	0
Plan Amendments	0	0
Benefits Paid	(11,129)	(10,395)
Benefit Obligation at End of Year	278,288	254,195	265,434
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	184,824	180,523
Actual Return on Plan Assets	13,569	(2,321)
Employer Contributions	2,278	17,017
Retiree Contributions	0	0
Benefits Paid	(11,129)	(10,395)
Fair Value of Plan Assets at End of Year	189,542	184,824	180,523
Funded Status at End of Year	(88,746)	(69,371)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	(2,463)	(2,261)
Noncurrent Liabilities	(85,957)	(66,906)
Net Amount Recognized at End of Year	(88,420)	(69,167)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	538	741
Net Actuarial Loss	67,912	63,691
Amount Recognized in Regulatory Assets	68,450	64,432	71,177
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	69	77
Net Actuarial Loss	39,521	34,989
Amount Recognized in Accumulated Other Comprehensive Loss	39,590	35,066	39,468
Projected benefit obligation	224,300	207,700
Accumulated benefit obligation	208,300	191,900
Pension Benefits | Amounts Related to Unconsolidated Affiliate
Change in Plan Assets:
Funded Status at End of Year	326	204
Pension Benefits | Accrued Net Benefit Cost at End of Year
Change in Plan Assets:
Funded Status at End of Year	(88,420)	(69,167)
Other Postretirement Benefits
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	57,430	75,592
Service Cost	851	1,116	891
Interest Cost	2,615	2,973	2,852
Actuarial Loss (Gain)	3,121	(8,591)
Retiree Contributions	81	700
Plan Amendments	0	(9,899)
Benefits Paid	(3,748)	(4,461)
Benefit Obligation at End of Year	60,350	57,430	75,592
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	47,759	43,222
Actual Return on Plan Assets	2,784	(423)
Employer Contributions	3,656	8,721
Retiree Contributions	81	700
Benefits Paid	(3,748)	(4,461)
Fair Value of Plan Assets at End of Year	50,532	47,759	43,222
Funded Status at End of Year	(9,818)	(9,671)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	0	0
Noncurrent Liabilities	(9,278)	(9,162)
Net Amount Recognized at End of Year	(9,278)	(9,162)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	(3,032)	(3,289)
Net Actuarial Loss	20,275	18,636
Amount Recognized in Regulatory Assets	17,243	15,347	27,863
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	(989)	(1,074)
Net Actuarial Loss	3,810	3,136
Amount Recognized in Accumulated Other Comprehensive Loss	2,821	2,062	6,755
Other Postretirement Benefits | Amounts Related to Unconsolidated Affiliate
Change in Plan Assets:
Funded Status at End of Year	540	509
Other Postretirement Benefits | Accrued Net Benefit Cost at End of Year
Change in Plan Assets:
Funded Status at End of Year	(9,278)	(9,162)
Supplemental Employee Retirement Plan
Change in Plan Assets:
Employer Contributions	2,300	2,000	$ 1,500
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Projected benefit obligation	53,900	46,500
Accumulated benefit obligation	$ 51,900	$ 45,000

PENSION AND OTHER POSTRETIREM66

PENSION AND OTHER POSTRETIREMENT BENEFITS - WEIGHTED-AVERAGE ASSUMPTIONS (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount Rate	4.30%	4.83%
Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount Rate	4.83%	4.25%	5.09%
Expected Long-Term Return on Plan Assets	7.50%	7.75%	7.75%
Rate of Compensation Increase	3.50%	3.50%	3.50%
Other Postretirement Benefits
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount Rate	4.13%	4.73%
Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount Rate	4.73%	4.20%	4.91%
Expected Long-Term Return on Plan Assets	6.50%	6.25%	6.25%
Rate of Compensation Increase	3.50%	3.50%	3.50%

PENSION AND OTHER POSTRETIREM67

PENSION AND OTHER POSTRETIREMENT BENEFITS - PLAN ASSETS (Details) - Pension Benefits	12 Months Ended
	Dec. 31, 2016USD ($)
Defined Benefit Plan Disclosure [Line Items]
Required capitalization for plan asset allocation (less than)	$ 250,000,000
Required capitalization for plan asset allocation, small cap (as low as)	$ 50,000,000
U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	28.00%
Target allocation percentage of assets, equity securities, range maximum	48.00%
International equity securities
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	13.00%
Target allocation percentage of assets, equity securities, range maximum	25.00%
Fixed income securities
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	32.00%
Target allocation percentage of assets, equity securities, range maximum	42.00%
Other investments
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	0.00%
Target allocation percentage of assets, equity securities, range maximum	7.00%

PENSION AND OTHER POSTRETIREM68

PENSION AND OTHER POSTRETIREMENT BENEFITS - FAIR VALUE OF PLAN ASSETS (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2016USD ($)category
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 184,824	$ 180,523	$ 189,542
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	184,824	180,523
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	$ 189,542	184,824
Pension Benefits | Minimum
Defined Benefit Plan Disclosure [Line Items]
Fund Valuations Lag Period	90 days
Pension Benefits | Maximum
Defined Benefit Plan Disclosure [Line Items]
Fund Valuations Lag Period	120 days
Pension Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 19,702	19,702	23,674
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	19,702
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	23,674	19,702
Pension Benefits | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	138,176	138,176	141,859
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	138,176
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	141,859	138,176
Pension Benefits | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	26,946	26,335	24,009
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26,946	26,335
Actual return on plan assets:
Relating to assets still held at the reporting date	1,014	459
Relating to assets sold during the period	259	454
Purchases, Sales and Settlements	(4,210)	(302)
Fair Value of Plan Assets at End of Year	24,009	26,946
Pension Benefits | Common/Collective Trust Funds - U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	52,058	52,058	51,902
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	52,058
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	51,902	52,058
Pension Benefits | Common/Collective Trust Funds - U.S. | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds - U.S. | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	52,058	52,058	51,902
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	52,058
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	51,902	52,058
Pension Benefits | Common/Collective Trust Funds - U.S. | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Large-Cap
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	14,305	14,305	17,792
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	14,305
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	17,792	14,305
Pension Benefits | U.S. Large-Cap | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	14,305	14,305	$ 17,792
Number of sectors (in categories) | category			5
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	14,305
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	17,792	14,305
Pension Benefits | U.S. Large-Cap | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	$ 0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Large-Cap | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Mid-Cap
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	3,407	3,407	2,479
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,407
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,479	3,407
Pension Benefits | U.S. Mid-Cap | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	3,407	3,407	2,479
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,407
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,479	3,407
Pension Benefits | U.S. Mid-Cap | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Mid-Cap | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | U.S. Small-Cap
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	260	260
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	260
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		260
Pension Benefits | U.S. Small-Cap | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	260	260
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	260
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		260
Pension Benefits | U.S. Small-Cap | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | U.S. Small-Cap | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | International equity securities
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,695	1,695	3,340
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,695
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	3,340	1,695
Pension Benefits | International equity securities | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,695	1,695	3,340
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,695
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	3,340	1,695
Pension Benefits | International equity securities | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | International equity securities | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	33,236	33,236	33,096
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	33,236
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	33,096	33,236
Pension Benefits | Common/Collective Trust Funds - International | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds - International | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	33,236	33,236	33,096
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	33,236
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	33,096	33,236
Pension Benefits | Common/Collective Trust Funds - International | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	50,664	50,664	54,970
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	50,664
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	54,970	50,664
Pension Benefits | Common/Collective Trust Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	50,664	50,664	54,970
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	50,664
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	54,970	50,664
Pension Benefits | Common/Collective Trust Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Guaranteed Insurance Contract
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	9,960	9,960	9,714
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	9,960
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	9,714	9,960
Pension Benefits | Guaranteed Insurance Contract | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Guaranteed Insurance Contract | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Guaranteed Insurance Contract | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	9,960	10,912	9,714
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	9,960	10,912
Actual return on plan assets:
Relating to assets still held at the reporting date	541	(106)
Relating to assets sold during the period	14	25
Purchases, Sales and Settlements	(801)	(871)
Fair Value of Plan Assets at End of Year	9,714	9,960
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,159	4,159
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,159
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		4,159
Pension Benefits | Hedge Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | Hedge Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits | Hedge Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,159	4,331	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,159	4,331
Actual return on plan assets:
Relating to assets still held at the reporting date	(67)	(172)
Relating to assets sold during the period	0	0
Purchases, Sales and Settlements	(4,092)	0
Fair Value of Plan Assets at End of Year	0	4,159
Pension Benefits | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,312	4,312	5,100
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,312
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	5,100	4,312
Pension Benefits | Private Equity Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Private Equity Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Private Equity Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	4,312	3,616	5,100
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	4,312	3,616
Actual return on plan assets:
Relating to assets still held at the reporting date	(140)	(302)
Relating to assets sold during the period	245	429
Purchases, Sales and Settlements	683	569
Fair Value of Plan Assets at End of Year	5,100	4,312
Pension Benefits | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,515	8,515	9,195
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,515
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	9,195	8,515
Pension Benefits | Real Estate | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Real Estate | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Real Estate | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,515	7,476	9,195
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,515	7,476
Actual return on plan assets:
Relating to assets still held at the reporting date	680	1,039
Relating to assets sold during the period	0	0
Purchases, Sales and Settlements	0	0
Fair Value of Plan Assets at End of Year	9,195	8,515
Pension Benefits | Cash
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	35	35	63
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	35
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	63	35
Pension Benefits | Cash | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	35	35	63
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	35
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	63	35
Pension Benefits | Cash | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Cash | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	858	858	460
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	858
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	460	858
Pension Benefits | Common/Collective Trust Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | Common/Collective Trust Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	858	858	460
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	858
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	460	858
Pension Benefits | Common/Collective Trust Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | STIF-Type Instrument
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,360	1,360	1,431
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,360
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	1,431	1,360
Pension Benefits | STIF-Type Instrument | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Pension Benefits | STIF-Type Instrument | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,360	1,360	1,431
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,360
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	1,431	1,360
Pension Benefits | STIF-Type Instrument | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	47,759	43,222	50,532
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	47,759	43,222
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	50,532	47,759
Other Postretirement Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	3,911	3,911	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,911
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	3,911
Other Postretirement Benefits | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	43,848	43,848	50,532
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	43,848
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	50,532	43,848
Other Postretirement Benefits | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	$ 0	0
Other Postretirement Benefits | U.S. equity securities | Minimum
Actual return on plan assets:
Target plan allocation	30.00%
Other Postretirement Benefits | U.S. equity securities | Maximum
Actual return on plan assets:
Target plan allocation	43.00%
Other Postretirement Benefits | Common/Collective Trust Funds - U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 13,522	13,522	14,878
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,522
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	14,878	13,522
Other Postretirement Benefits | Common/Collective Trust Funds - U.S. | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Common/Collective Trust Funds - U.S. | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	13,522	13,522	14,878
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,522
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	14,878	13,522
Other Postretirement Benefits | Common/Collective Trust Funds - U.S. | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Mutual Fund - U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,309	1,309
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,309
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,309
Other Postretirement Benefits | Mutual Fund - U.S. | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,309	1,309
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,309
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,309
Other Postretirement Benefits | Mutual Fund - U.S. | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Fund - U.S. | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | International equity securities | Minimum
Actual return on plan assets:
Target plan allocation	20.00%
Other Postretirement Benefits | International equity securities | Maximum
Actual return on plan assets:
Target plan allocation	30.00%
Other Postretirement Benefits | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 8,313	8,313	8,674
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,313
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	8,674	8,313
Other Postretirement Benefits | Common/Collective Trust Funds - International | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Common/Collective Trust Funds - International | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,313	8,313	8,674
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,313
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	8,674	8,313
Other Postretirement Benefits | Common/Collective Trust Funds - International | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Mutual Funds - International
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	983	983
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	983
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		983
Other Postretirement Benefits | Mutual Funds - International | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	983	983
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	983
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		983
Other Postretirement Benefits | Mutual Funds - International | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Funds - International | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Fixed income investments | Minimum
Actual return on plan assets:
Target plan allocation	32.00%
Other Postretirement Benefits | Fixed income investments | Maximum
Actual return on plan assets:
Target plan allocation	42.00%
Other Postretirement Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 13,187	13,187	13,537
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,187
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,537	13,187
Other Postretirement Benefits | Common/Collective Trust Funds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Common/Collective Trust Funds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	13,187	13,187	13,537
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	13,187
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,537	13,187
Other Postretirement Benefits | Common/Collective Trust Funds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Mutual Funds - Bonds
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,441	1,441
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,441
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,441
Other Postretirement Benefits | Mutual Funds - Bonds | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,441	1,441
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,441
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,441
Other Postretirement Benefits | Mutual Funds - Bonds | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Funds - Bonds | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Other investments | Minimum
Actual return on plan assets:
Target plan allocation	0.00%
Other Postretirement Benefits | Other investments | Maximum
Actual return on plan assets:
Target plan allocation	7.00%
Other Postretirement Benefits | Mutual Funds - REITS
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 152	152
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	152
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		152
Other Postretirement Benefits | Mutual Funds - REITS | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	152	152
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	152
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		152
Other Postretirement Benefits | Mutual Funds - REITS | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Mutual Funds - REITS | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Other Postretirement Benefits | Company Owned Life Insurance
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,826	8,826	13,443
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,826
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,443	8,826
Other Postretirement Benefits | Company Owned Life Insurance | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Company Owned Life Insurance | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	8,826	8,826	13,443
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,826
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,443	8,826
Other Postretirement Benefits | Company Owned Life Insurance | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Cash
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	26	26	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	26
Other Postretirement Benefits | Cash | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	26	26	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	26
Other Postretirement Benefits | Cash | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	0
Other Postretirement Benefits | Cash | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0	$ 0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	$ 0	$ 0

PENSION AND OTHER POSTRETIREM69

PENSION AND OTHER POSTRETIREMENT BENEFITS - CONTRIBUTIONS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
Pension contribution	$ 0	$ 15,000,000	$ 0
Pension Benefits
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2,017	12,141,000
2,018	12,583,000
2,019	13,529,000
2,020	14,056,000
2,021	14,757,000
2022- 2025	86,727,000
Pension contribution	0	15,000,000	0
Employer contributions	2,278,000	17,017,000
Other Postretirement Benefits
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2,017	4,399,000
2,018	4,316,000
2,019	4,403,000
2,020	4,514,000
2,021	4,511,000
2022- 2025	21,308,000
Employer contributions	3,656,000	8,721,000
Expected contribution to plan	3,600,000
Supplemental Employee Retirement Plan
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
Employer contributions	2,300,000	$ 2,000,000	$ 1,500,000
Expected contribution to plan	$ 2,500,000

PENSION AND OTHER POSTRETIREM70

PENSION AND OTHER POSTRETIREMENT BENEFITS - DEFINED CONTRIBUTION PLAN (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)$ / employees	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Defined Benefit Plan Disclosure [Line Items]
Amount expensed and contributed for matching provision of Savings Plan | $	$ 2.3	$ 2.1	$ 2
Employees eligible for defined benefit pension plan
Defined Benefit Plan Disclosure [Line Items]
Matching percentage of participants' contributions	50.00%
Percentage of base compensation (up to)	6.00%
Employees ineligible for defined benefit pension plan
Defined Benefit Plan Disclosure [Line Items]
Matching percentage of participants' contributions	50.00%
Percentage of base compensation (up to)	8.00%
Year-end contribution (in dollars per employee)	1,500
Service threshold to determine year-end contribution (up to, more than)	10 years
Year-end contribution (in dollars per employee)	2,000

LINES OF CREDIT (Details)

LINES OF CREDIT (Details)	1 Months Ended	12 Months Ended
	Sep. 30, 2016USD ($)extension	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014
Line of Credit Facility [Line Items]
Total Facility	$ 50,000,000	$ 660,000,000
Usage		301,700,000
Available Liquidity		358,300,000
Letters of credit outstanding		$ 4,800,000
Number of extensions (not more than) | extension	2
Weighted average borrowing cost		1.47%	1.13%	0.83%
Average borrowings outstanding		$ 321,900,000	$ 335,000,000
Maximum amounts outstanding		$ 467,700,000	$ 471,100,000
Financial covenant, ratio of indebtedness to consolidated total capitalization (not more than)		0.65
Commercial Paper Program/Revolving Credit Facility
Line of Credit Facility [Line Items]
Term of agreement	364 days
Letters of credit
Line of Credit Facility [Line Items]
Total Facility		$ 4,800,000
South Jersey Gas commercial paper program
Line of Credit Facility [Line Items]
Total Facility		$ 200,000,000
Fixed maturities of notes, which may not exceed specified number of days		270 days
South Jersey Gas Company
Line of Credit Facility [Line Items]
Total Facility		$ 210,000,000
Usage		105,100,000
Available Liquidity		104,900,000
South Jersey Gas Company | Letters of credit
Line of Credit Facility [Line Items]
Letters of credit outstanding		800,000
South Jersey Gas Company | Commercial Paper Program/Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility		200,000,000
Usage		105,100,000
Available Liquidity		94,900,000
South Jersey Gas Company | Uncommitted Bank Lines
Line of Credit Facility [Line Items]
Total Facility		10,000,000
Usage		0
Available Liquidity		10,000,000
South Jersey Industries Inc.
Line of Credit Facility [Line Items]
Total Facility		450,000,000
Usage		196,600,000
Available Liquidity		253,400,000
South Jersey Industries Inc. | Commercial Paper Program/Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility		450,000,000
Usage		196,600,000
Available Liquidity		$ 253,400,000

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details) - USD ($)	1 Months Ended			12 Months Ended
	Aug. 31, 2016	Jul. 31, 2016	Jan. 31, 2016	Dec. 31, 2016	Sep. 30, 2016	Dec. 31, 2015	Oct. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2011
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 1,047,482,000		$ 1,035,848,000
Less Current Maturities				(231,909,000)		(29,454,000)
Total Long-Term Debt				815,573,000		1,006,394,000
Long-term Debt, Fiscal Year Maturity [Abstract]
2,017				231,909,000
2,018				38,909,000
2,019				258,909,000
2,020				67,909,000
2,021				52,909,000
Amount of facility				660,000,000	$ 50,000,000
Unamortized debt issuance costs				$ 7,600,000		9,000,000
Energenic
Long-term Debt, Fiscal Year Maturity [Abstract]
Equity interest										50.00%
Senior notes | Series Notes at variable rates due 2019
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				2.32%
Medium-term notes
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity						400,000,000
South Jersey Gas Company
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility				$ 210,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2016
Debt Instrument [Line Items]
Stated interest rate	5.437%			5.437%
Total Long-Term Debt Outstanding				$ 0		10,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt retired	$ 10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2016
Debt Instrument [Line Items]
Stated interest rate		4.60%		4.60%
Total Long-Term Debt Outstanding				$ 0		17,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt retired		$ 17,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2017
Debt Instrument [Line Items]
Stated interest rate				4.657%
Total Long-Term Debt Outstanding				$ 15,000,000		15,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2018
Debt Instrument [Line Items]
Stated interest rate				7.97%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2018
Debt Instrument [Line Items]
Stated interest rate				7.125%
Total Long-Term Debt Outstanding				$ 20,000,000		20,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				5.587%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2024 (D)
Debt Instrument [Line Items]
Stated interest rate				3.00%
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2024 (E)
Debt Instrument [Line Items]
Stated interest rate				3.03%
Total Long-Term Debt Outstanding				$ 35,000,000		35,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 7,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2025
Debt Instrument [Line Items]
Stated interest rate				3.63%
Total Long-Term Debt Outstanding				$ 8,182,000		9,091,000
Less Current Maturities				(900,000)
Long-term Debt, Fiscal Year Maturity [Abstract]
Payment towards principal				$ 900,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2026 (G)
Debt Instrument [Line Items]
Stated interest rate				4.84%
Total Long-Term Debt Outstanding				$ 15,000,000		15,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 2,500,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2026 (H)
Debt Instrument [Line Items]
Stated interest rate				4.93%
Total Long-Term Debt Outstanding				$ 45,000,000		45,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payment				$ 7,500,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2027
Debt Instrument [Line Items]
Stated interest rate				4.03%
Total Long-Term Debt Outstanding				$ 45,000,000		45,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2030 (I)
Debt Instrument [Line Items]
Stated interest rate				4.01%
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, Due November 2018 and November 2019
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				8,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2025
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				2,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2026
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				3,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2027
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				8,000,000
South Jersey Gas Company | First Mortgage Bonds | MTN, 4.01%, due November 2028, November 2029 and November 2030
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 7,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2030
Debt Instrument [Line Items]
Stated interest rate				4.23%
Total Long-Term Debt Outstanding				$ 30,000,000		30,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2032
Debt Instrument [Line Items]
Stated interest rate				3.74%
Total Long-Term Debt Outstanding				$ 35,000,000		35,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2033
Debt Instrument [Line Items]
Stated interest rate				5.55%
Total Long-Term Debt Outstanding				$ 32,000,000		32,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2034
Debt Instrument [Line Items]
Stated interest rate				6.213%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | First Mortgage Bonds | Series due 2035
Debt Instrument [Line Items]
Stated interest rate				5.45%
Total Long-Term Debt Outstanding				$ 10,000,000		10,000,000
South Jersey Gas Company | Unsecured debt | Series A 2006 Bonds at variable rates due 2036
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 24,900,000		24,900,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.74%
South Jersey Gas Company | Loans payable | Term facility
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 200,000,000		139,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility				200,000,000
Line of credit balance				200,000,000		$ 139,000,000
Average interest rate			1.41%			1.17%
Issuance of additional long-term debt			$ 61,000,000
Marina Energy LLC | Energenic
Long-term Debt, Fiscal Year Maturity [Abstract]
Equity interest								50.00%
Marina Energy LLC | Unsecured debt
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				61,400,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Outstanding amount of note not fixed by interest rate derivatives				$ 46,100,000
Fixed interest rate				4.22%
Marina Energy LLC | Unsecured debt | Series A 2001 Bonds at variable rates due 2031
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 20,000,000		$ 20,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.72%
Marina Energy LLC | Unsecured debt | Series B 2001 Bonds at variable rates due 2021
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 25,000,000		25,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.73%
Marina Energy LLC | Unsecured debt | Series A 2006 Bonds at variable rates due 2036
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 16,400,000		16,400,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				0.72%
South Jersey Industries Inc.
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility				$ 450,000,000
South Jersey Industries Inc. | Unsecured debt | South Jersey Industries Term Loan at variable rates due 2020
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
South Jersey Industries Inc. | Unsecured debt | Term loan due 2015 | Term facility
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding							$ 50,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end				1.79%
South Jersey Industries Inc. | Senior notes | Series B 2012 Notes due 2017
Debt Instrument [Line Items]
Stated interest rate				2.71%
Total Long-Term Debt Outstanding				$ 16,000,000		16,000,000
Less Current Maturities				$ (16,000,000)
South Jersey Industries Inc. | Senior notes | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				3.05%
Total Long-Term Debt Outstanding				$ 60,000,000		60,000,000
South Jersey Industries Inc. | Senior notes | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				3.05%
Total Long-Term Debt Outstanding				$ 30,000,000		30,000,000
South Jersey Industries Inc. | Senior notes | Series due 2019
Debt Instrument [Line Items]
Stated interest rate				3.05%
Total Long-Term Debt Outstanding				$ 50,000,000		50,000,000
South Jersey Industries Inc. | Senior notes | Series C 2012 Notes due 2022
Debt Instrument [Line Items]
Stated interest rate				3.46%
Total Long-Term Debt Outstanding				$ 35,000,000		35,000,000
South Jersey Industries Inc. | Senior notes | Series Notes at variable rates due 2019
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				40,000,000		40,000,000
South Jersey Industries Inc. | Senior notes | Series Notes at variable rates due 2019
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding				$ 60,000,000		60,000,000
ACB Energy Partners, LLC | Loan and security agreement | Loan & Security Agreement
Debt Instrument [Line Items]
Stated interest rate				7.60%
Total Long-Term Debt Outstanding				$ 0		12,735,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity				$ 16,000,000
Payment to retire outstanding debt			$ 12,700,000
ACLE | Debt agreement | Debt Agreement Due 2020, 4.83%, Agreement 1
Debt Instrument [Line Items]
Stated interest rate				4.83%
Total Long-Term Debt Outstanding				$ 0		3,551,000
SCLE | Debt agreement | Debt Agreement Due 2020, 4.83%, Agreement 2
Debt Instrument [Line Items]
Stated interest rate				4.83%
Total Long-Term Debt Outstanding				$ 0		1,738,000
SXLE | Debt agreement | Debt Agreement Due 2020, 4.83%, Agreement 3
Debt Instrument [Line Items]
Stated interest rate				4.83%
Total Long-Term Debt Outstanding				$ 0		3,433,000
ACLE, SCLE and SXLE | Debt agreement
Debt Instrument [Line Items]
Stated interest rate									4.83%
Total Long-Term Debt Outstanding						$ 8,700,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity									$ 10,000,000
Payment to retire outstanding debt	$ 8,300,000

COMMITMENTS AND CONTINGENCIES73

COMMITMENTS AND CONTINGENCIES (Details)	12 Months Ended		444 Months Ended
	Dec. 31, 2016USD ($)siteuniondecatherm / daycontract	Dec. 31, 2015USD ($)	Dec. 31, 2016USD ($)siteuniondecatherm / daycontract	Sep. 30, 2016USD ($)	Dec. 31, 2012USD ($)	Dec. 31, 1996USD ($)
Commitment and Contingencies [Line Items]
Minimum purchase amount under contract (in dts/d) | decatherm / day	745,000		745,000
Maximum purchase amount under contract (in dts/d) | decatherm / day	940,000		940,000
Minimum length of contract term	3 years
Maximum length of contract term	10 years
Capacity management contract, term	3 years
Accrual for pending litigation	$ 3,100,000	$ 3,200,000	$ 3,100,000
Percentage of workforce that is unionized	45.00%		45.00%
Number of unions with collective bargaining agreements | union	2		2
Guarantor obligations	$ 125,400,000		$ 125,400,000
Letter of credit provided	660,000,000		660,000,000	$ 50,000,000
Letters of credit outstanding	$ 4,800,000		$ 4,800,000
Number of sites for environmental cleanup (in number of sites) | site	12		12
Number of sites covered by insurance | site	11		11
Insurance policy limit					$ 50,000,000
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning of Year	$ 126,623,000	128,172,000
Accruals	60,713,000	19,489,000	$ 437,100,000
Expenditures	(32,323,000)	(21,038,000)	(282,100,000)
End of Year	155,013,000	$ 126,623,000	155,013,000
Letters of credit
Commitment and Contingencies [Line Items]
Letter of credit provided	4,800,000		4,800,000
Variable-rate demand bonds
Commitment and Contingencies [Line Items]
Letter of credit provided	$ 87,500,000		$ 87,500,000
Environmental restoration costs
Commitment and Contingencies [Line Items]
EMI's assumed responsibility for environment liabilities, minimum						$ 1,300,000
EMI's assumed responsibility for environment liabilities, maximum						$ 2,100,000
Environmental restoration costs | Fuel Oil
Commitment and Contingencies [Line Items]
Number of sites affected by environmental remediation | site	5		5
Environmental restoration costs | Majority of the environmental remediation
Commitment and Contingencies [Line Items]
Number of sites affected by environmental remediation | site	6		6
Environmental restoration costs | Minimum
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	$ 153,000,000		$ 153,000,000
Environmental restoration costs | Minimum | Fuel Oil
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	700,000		700,000
Environmental restoration costs | Minimum | Majority of the environmental remediation
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	141,200,000		141,200,000
Environmental restoration costs | Maximum
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	257,100,000		257,100,000
Environmental restoration costs | Maximum | Fuel Oil
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	1,300,000		1,300,000
Environmental restoration costs | Maximum | Majority of the environmental remediation
Commitment and Contingencies [Line Items]
Estimates of undiscounted future costs	246,700,000		246,700,000
Parental guarantee
Commitment and Contingencies [Line Items]
Guaranteed amount	$ 6,000,000		$ 6,000,000
Contract term	2 years
Pricing dispute, long-term gas supply contract
Commitment and Contingencies [Line Items]
Number of long-term gas supply contracts | contract	2		2
South Jersey Resources Group, LLC
Commitment and Contingencies [Line Items]
Amount of monthly fees paid to supplier	$ 500,000
South Jersey Resources Group, LLC | Pending litigation | Pricing dispute, long-term gas supply contract
Commitment and Contingencies [Line Items]
Damages sought	40,200,000
South Jersey Resources Group, LLC | Pending litigation | Dispute, long-term management contract
Commitment and Contingencies [Line Items]
Damages sought	13,300,000
South Jersey Gas Company
Commitment and Contingencies [Line Items]
Amount of monthly fees paid to supplier	5,600,000
Letter of credit provided	210,000,000		$ 210,000,000
South Jersey Gas Company | Letters of credit
Commitment and Contingencies [Line Items]
Letters of credit outstanding	800,000		$ 800,000
South Jersey Gas Company | Pending litigation | Pricing dispute, long-term gas supply contract
Commitment and Contingencies [Line Items]
Damages sought	$ 14,900,000

DERIVATIVE INSTRUMENTS (Details

DERIVATIVE INSTRUMENTS (Details) MWh in Millions	12 Months Ended
	Dec. 31, 2016USD ($)MWh	Dec. 31, 2016USD ($)MMcfe
Marina Energy LLC | Interest Rate Swap, 14,500,000
Derivative [Line Items]
Notional Amount	$ 14,500,000	$ 14,500,000
Fixed Interest Rate	3.905%	3.905%
Marina Energy LLC | Interest Rate Swap, 500,000
Derivative [Line Items]
Notional Amount	$ 500,000	$ 500,000
Fixed Interest Rate	3.905%	3.905%
Marina Energy LLC | Interest Rate Swap, 330,000
Derivative [Line Items]
Notional Amount	$ 330,000	$ 330,000
Fixed Interest Rate	3.905%	3.905%
South Jersey Gas Company | Interest Rate Swap, 12,500,000, Contract 1
Derivative [Line Items]
Notional Amount	$ 12,500,000	$ 12,500,000
Fixed Interest Rate	3.53%	3.53%
South Jersey Gas Company | Interest Rate Swap, 12,500,000, Contract 2
Derivative [Line Items]
Notional Amount	$ 12,500,000	$ 12,500,000
Fixed Interest Rate	3.43%	3.43%
Basis and index related purchase and sales contracts
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh) | MMcfe		141,600
Expected future purchases
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh)	2.3	67,900
Expected future sales
Derivative [Line Items]
Notional amount (natural gas in mmcfe and electricity in mwh)	1.7	62,100

DERIVATIVE INSTRUMENTS - FAIR V

DERIVATIVE INSTRUMENTS - FAIR VALUES OF ALL DERIVATIVE INSTRUMENTS (Details) - Derivatives not designated as hedging instruments under GAAP - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Assets	$ 80,893	$ 99,331
Liabilities	74,652	123,348
Commodity contract | Derivatives – Energy Related – Current
Derivatives, Fair Value [Line Items]
Assets	72,391	83,093
Liabilities	60,082	90,708
Commodity contract | Derivatives – Energy Related – Non-Current
Derivatives, Fair Value [Line Items]
Assets	8,502	16,238
Liabilities	4,540	21,697
Interest rate contract | Derivatives - Other - Current
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	681	0
Interest rate contract | Derivatives - Other - Non-Current
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	$ 9,349	$ 10,943

DERIVATIVE INSTRUMENTS - OFFSET

DERIVATIVE INSTRUMENTS - OFFSETTING ARRANGEMENTS (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Commodity contract
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	$ 80,893	$ 99,331
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	80,893	99,331
Gross amounts not offset in the balance sheet, Financial Instruments	(38,809)	(35,491)
Gross amounts not offset in the balance sheet, Cash Collateral Posted	(3,474)	0
Net amount	38,610	63,840
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(64,622)	(112,405)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(64,622)	(112,405)
Gross amounts not offset in the balance sheet, Financial Instruments	38,809	35,491
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	23,045
Net amount	(25,813)	(53,869)
Interest rate contract
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(10,030)	(10,943)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(10,030)	(10,943)
Gross amounts not offset in the balance sheet, Financial Instruments	0	0
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	0
Net amount	$ (10,030)	$ (10,943)

DERIVATIVE INSTRUMENTS - EFFECT

DERIVATIVE INSTRUMENTS - EFFECTS OF DERIVATIVE INSTRUMENTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Interest Rate Contracts [Abstract]
Losses recognized in AOCL on effective portion	$ 0	$ 0	$ 0
Losses reclassified from AOCL into income	(333)	(551)	(419)
Losses recognized in income on ineffective portion	0	0	0
Gains (losses) on energy-related commodity contracts	26,935	8,401	(6,592)
Gains (losses) on interest rate contracts	647	96	(467)
Total	27,582	8,497	(7,059)
Net realized gains (losses) on commodity contracts	(3,000)	$ (9,100)	$ 1,700
Fair value derivative instruments with credit-risk-related features	9,600
Additional collateral, aggregate fair value	$ 8,100

FAIR VALUE OF FINANCIAL ASSET78

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)$ / decatherm	Dec. 31, 2015USD ($)$ / decatherm
Liabilities
Net derivative assets (liabilities) transferred	$ 4,100	$ 7,400
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period	(632)	(5,608)
Other changes in fair value from continuing and new contracts, net	5,657	(5,069)
Transfers in to/(out of) of Level 3	4,116	7,402
Settlements	(106)	2,643
Balance at end of period	$ 9,035	$ (632)
Level 3 | Forward Contract | Minimum
Liabilities
Forward price (in USD per dt) | $ / decatherm	1.03	(0.77)
Level 3 | Forward Contract | Maximum
Liabilities
Forward price (in USD per dt) | $ / decatherm	11.33	10
Level 3 | Forward Contract | Weighted Average
Liabilities
Forward price (in USD per dt) | $ / decatherm	2.71	2.15
Level 3 | Forward Contract | Natural Gas
Liabilities
Assets	$ 23,301	$ 29,459
Liabilities	18,109	31,733
Level 3 | Forward Contract | Electric
Liabilities
Assets	11,784	29,136
Liabilities	$ 7,941	$ 27,494
Level 3 | Forward Contract | Electric | Minimum | On-peak
Liabilities
Fixed electric load profile	21.43%	8.47%
Level 3 | Forward Contract | Electric | Minimum | Off-peak
Liabilities
Fixed electric load profile	0.00%	0.00%
Level 3 | Forward Contract | Electric | Maximum | On-peak
Liabilities
Fixed electric load profile	100.00%	100.00%
Level 3 | Forward Contract | Electric | Maximum | Off-peak
Liabilities
Fixed electric load profile	78.57%	91.53%
Level 3 | Forward Contract | Electric | Weighted Average | On-peak
Liabilities
Fixed electric load profile	55.14%	56.20%
Level 3 | Forward Contract | Electric | Weighted Average | Off-peak
Liabilities
Fixed electric load profile	44.86%	43.80%
Measurement at fair value on recurring basis
Assets
Available-for-Sale Securities	$ 32	$ 14,810
Derivatives - Energy Related Assets	80,893	99,331
Assets	80,925	114,141
Liabilities
Derivatives - Energy Related Liabilities	64,622	112,405
Derivatives - Other	10,030	10,943
Liabilities	74,652	123,348
Measurement at fair value on recurring basis | Level 1
Assets
Available-for-Sale Securities	32	2,925
Derivatives - Energy Related Assets	33,994	16,006
Assets	34,026	18,931
Liabilities
Derivatives - Energy Related Liabilities	16,502	42,170
Derivatives - Other	0	0
Liabilities	16,502	42,170
Measurement at fair value on recurring basis | Level 2
Assets
Available-for-Sale Securities	0	11,885
Derivatives - Energy Related Assets	11,814	24,730
Assets	11,814	36,615
Liabilities
Derivatives - Energy Related Liabilities	22,070	11,008
Derivatives - Other	10,030	10,943
Liabilities	32,100	21,951
Measurement at fair value on recurring basis | Level 3
Assets
Available-for-Sale Securities	0	0
Derivatives - Energy Related Assets	35,085	58,595
Assets	35,085	58,595
Liabilities
Derivatives - Energy Related Liabilities	26,050	59,227
Derivatives - Other	0	0
Liabilities	$ 26,050	$ 59,227

ACCUMULATED OTHER COMPREHENSI79

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		$ 1,037,539	$ 932,432	$ 827,000
Other comprehensive income before reclassifications		(5,294)
Amounts reclassified from AOCL		2,412
Other Comprehensive (Loss) Income - Net of Tax	[1],[2]	(2,882)	5,759	(9,498)
Balance		$ 1,289,240	1,037,539	$ 932,432
Combined average statutory tax rate		40.00%
Postretirement Liability Adjustment
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		$ (22,145)
Other comprehensive income before reclassifications		(5,617)
Amounts reclassified from AOCL		2,420
Other Comprehensive (Loss) Income - Net of Tax		(3,197)
Balance		(25,342)	(22,145)
Unrealized Gain (Loss) on Derivatives-Other
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(2,129)
Other comprehensive income before reclassifications		0
Amounts reclassified from AOCL		197
Other Comprehensive (Loss) Income - Net of Tax		197
Balance		(1,932)	(2,129)
Unrealized Gain (Loss) on Available- for-Sale Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(128)
Other comprehensive income before reclassifications		323
Amounts reclassified from AOCL		(205)
Other Comprehensive (Loss) Income - Net of Tax		118
Balance		(10)	(128)
Other Comprehensive Income (Loss) of Affiliated Companies
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(97)
Other comprehensive income before reclassifications		0
Amounts reclassified from AOCL		0
Other Comprehensive (Loss) Income - Net of Tax		0
Balance		(97)	(97)
Accumulated Other Comprehensive Loss
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance		(24,499)
Balance		$ (27,381)	$ (24,499)
[1]	Determined using a combined average statutory tax rate of 40%.
[2]	Determined using a combined average statutory tax rate of 40%.

ACCUMULATED OTHER COMPREHENSI80

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) - RECLASSIFICATIONS OUT OF AOCL (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Operations									$ 151,957	$ 148,672	$ 140,260
Income Taxes	$ 19,266	$ 2,807	$ (7,189)	$ 39,267	$ (1,006)	$ (10,968)	$ (3,279)	$ 16,613	54,151	1,360	4,449
Net Income									(118,810)	(105,107)	(97,046)
Income from Continuing Operations	$ (46,008)	$ (9,664)	$ 4,798	$ (68,187)	$ (50,948)	$ 12,532	$ (13,341)	$ (53,853)	(119,061)	$ (105,610)	$ (97,628)
Losses from reclassifications for the period net of tax									$ 2,412
Combined average statutory tax rate									40.00%
Unrealized Gain (Loss) on Available- for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Losses from reclassifications for the period net of tax									$ (205)
Amounts Reclassified from AOCL | Actuarial Loss on Postretirement Benefits
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Operations									4,001
Income Taxes									(1,581)
Income from Continuing Operations									2,420
Amounts Reclassified from AOCL | Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Income Taxes									(136)
Net Income									197
Amounts Reclassified from AOCL | Unrealized Gain (Loss) on Available- for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Other Income									(342)
Income Taxes									137
Net Income									(205)
Amounts Reclassified from AOCL | Interest rate contract | Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges									$ 333

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details)	1 Months Ended
	Jan. 31, 2017USD ($)bank	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Dec. 31, 2015USD ($)
Subsequent Event [Line Items]
Amount of facility		$ 660,000,000	$ 50,000,000
South Jersey Gas Company
Subsequent Event [Line Items]
Amount of facility		210,000,000
South Jersey Gas Company | Loans payable | Term facility
Subsequent Event [Line Items]
Amount of facility		200,000,000
Line of credit balance		$ 200,000,000		$ 139,000,000
Subsequent event | South Jersey Gas Company | Unsecured term loan
Subsequent Event [Line Items]
Line of credit balance	$ 73,000,000
Subsequent event | South Jersey Gas Company | Credit Agreement | Unsecured term loan
Subsequent Event [Line Items]
Amount of facility	$ 200,000,000
Credit agreement syndicated among number of banks | bank	7
Subsequent event | South Jersey Gas Company | Medium-term notes | Series E, 2017, due January 2047
Subsequent Event [Line Items]
Private placement	$ 200,000,000
Stated interest rate	3.00%
Subsequent event | South Jersey Gas Company | Loans payable | Term facility
Subsequent Event [Line Items]
Repayments of multiple-draw term facility	$ 200,000,000

Quarterly Financial Data (Una82

Quarterly Financial Data (Unaudited) (Details) $ / shares in Units, shares in Thousands, $ in Thousands	May 08, 2015	Feb. 26, 2015	Dec. 31, 2016USD ($)$ / sharesshares	Sep. 30, 2016USD ($)$ / sharesshares	Jun. 30, 2016USD ($)$ / sharesshares	Mar. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Sep. 30, 2015USD ($)$ / sharesshares	Jun. 30, 2015USD ($)$ / sharesshares	Mar. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares
Quarterly Financial Information Disclosure [Abstract]
Operating Revenues			$ 329,981	$ 219,082	$ 154,402	$ 333,035	$ 257,844	$ 141,062	$ 177,710	$ 382,952	$ 1,036,500	$ 959,568	$ 886,996
Expenses:
Cost of Sales - (Excluding depreciation)			186,684	142,988	98,340	152,975	127,566	99,124	90,945	241,707
Operations and Maintenance Including Fixed Charges			77,858	69,410	71,034	73,042	71,148	63,867	62,634	71,279
Income Taxes			19,266	2,807	(7,189)	39,267	(1,006)	(10,968)	(3,279)	16,613	54,151	1,360	4,449
Energy and Other Taxes			1,725	1,449	1,243	1,925	1,334	1,231	1,265	2,196	6,342	6,026	5,720
Total Expenses			285,533	216,654	163,428	267,209	199,042	153,254	151,565	331,795
Other Income and Expense			1,560	7,236	4,228	2,361	(7,854)	(340)	(12,804)	2,696
Income from Continuing Operations			46,008	9,664	(4,798)	68,187	50,948	(12,532)	13,341	53,853	119,061	105,610	97,628
Loss from Discontinued Operations - (Net of tax benefit)			(75)	(29)	(29)	(118)	(62)	(91)	(74)	(276)	$ (251)	$ (503)	$ (582)
Net Income (Loss)			$ 45,933	$ 9,635	$ (4,827)	$ 68,069	$ 50,886	$ (12,623)	$ 13,267	$ 53,577
Basic Earnings Per Common Share:
Continuing Operations (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.96	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.54	$ 1.47
Discontinued Operations (in USD per share) | $ / shares			0	0	0	0	0	0	0	0	0	0.01	0.01
Basic Earnings per Common Share (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.96	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.53	$ 1.46
Average Shares of Common Stock Outstanding - Basic (in shares) | shares			79,478	79,478	75,298	71,127	69,460	68,607	68,467	68,397	76,362	68,735	66,278
Diluted Earnings Per Common Share:
Continuing Operations (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.95	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.53	$ 1.47
Discontinued Operations (in USD per share) | $ / shares			0	0	0	0	0	0	0	0	0	0.01	0.01
Diluted Earnings per Common Share (in USD per share) | $ / shares			$ 0.58	$ 0.12	$ (0.06)	$ 0.95	$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 1.56	$ 1.52	$ 1.46
Average Shares of Common Stock Outstanding - Diluted (in shares) | shares			79,643	79,635	75,298	71,416	69,646	68,607	68,653	68,618	76,475	68,931	66,428
Stock split, conversion ratio	2	2

Schedule I (Details)

Schedule I (Details) - USD ($)		1 Months Ended	3 Months Ended								12 Months Ended
		May 31, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Feb. 26, 2015	Feb. 25, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Expenses:
Operations											$ 151,957,000	$ 148,672,000	$ 140,260,000
Depreciation											90,389,000	72,451,000	63,004,000
Energy and Other Taxes			$ 1,725,000	$ 1,449,000	$ 1,243,000	$ 1,925,000	$ 1,334,000	$ 1,231,000	$ 1,265,000	$ 2,196,000	6,342,000	6,026,000	5,720,000
Operating Income											189,276,000	156,894,000	127,603,000
Other Income:
Equity in Earnings of Subsidiaries											5,396,000	(27,812,000)	(7,785,000)
Total Other Income											9,989,000	9,510,000	11,819,000
Interest Charges											31,449,000	31,622,000	29,560,000
Income Taxes			19,266,000	2,807,000	(7,189,000)	39,267,000	(1,006,000)	(10,968,000)	(3,279,000)	16,613,000	54,151,000	1,360,000	4,449,000
Income from Continuing Operations			46,008,000	9,664,000	(4,798,000)	68,187,000	50,948,000	(12,532,000)	13,341,000	53,853,000	119,061,000	105,610,000	97,628,000
Equity in Undistributed Earnings of Discontinued Operations			(75,000)	$ (29,000)	$ (29,000)	(118,000)	(62,000)	$ (91,000)	$ (74,000)	(276,000)	(251,000)	(503,000)	(582,000)
Net Income											118,810,000	105,107,000	97,046,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net Income											118,810,000	105,107,000	97,046,000
Other Comprehensive (Loss) Income - Net of Tax
Postretirement Liability Adjustment											(3,197,000)	5,518,000	(9,160,000)
Other Comprehensive (Loss) Income - Net of Tax	[1],[2]										$ (2,882,000)	5,759,000	(9,498,000)
Combined average statutory tax rate											40.00%
Retained Earnings [Roll Forward]
Retained Earnings - Beginning						474,167,000					$ 474,167,000
Net Income											118,810,000	105,107,000	97,046,000
Dividends Declared - Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Retained Earnings - Ending			510,597,000				474,167,000				510,597,000	474,167,000
Statement of Cash Flows [Abstract]
CASH PROVIDED BY OPERATING ACTIVITIES											262,240,000	186,794,000	161,332,000
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital Expenditures											(278,002,000)	(345,621,000)	(342,578,000)
Proceeds from Sale of Property, Plant & Equipment											0	0	53,000
Purchase of Company-Owned Life Insurance											(2,398,000)	(2,328,000)	(1,250,000)
Net Cash Used in Investing Activities											(245,168,000)	(370,652,000)	(375,019,000)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt											61,000,000	130,000,000	329,000,000
Principal Repayments of Long Term Debt											(49,366,000)	(125,009,000)	(21,000,000)
Payments for Issuance of Long Term Debt											(147,000)	(64,000)	(2,184,000)
Net (Repayments of) Borrowings from Short-Term Credit Facilities											(135,600,000)	186,000,000	(108,200,000)
Dividends on Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Proceeds from Sale of Common Stock		$ 203,600,000									214,426,000	63,192,000	80,680,000
Net Cash (Used in) Provided by Financing Activities											(2,667,000)	183,564,000	214,040,000
Net Increase (Decrease) in Cash and Cash Equivalents											14,405,000	(294,000)	353,000
Cash and Cash Equivalents at Beginning of Year						3,877,000				4,171,000	3,877,000	4,171,000	3,818,000
Cash and Cash Equivalents at End of Year			18,282,000				3,877,000				18,282,000	3,877,000	4,171,000
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost														$ 821,942,000	$ 785,646,000
Accumulated Depreciation														(151,084,000)	(108,307,000)
Property, Plant and Equipment - Net														2,623,770,000	2,448,105,000
Investments:
Available-for-Sale Securities														32,000	14,810,000
Total Investments														42,566,000	80,551,000
Current Assets:
Cash and Cash Equivalents			18,282,000			3,877,000	3,877,000			4,171,000	3,877,000	4,171,000	3,818,000	18,282,000	3,877,000			$ 4,171,000	$ 3,818,000
Other														31,369,000	40,167,000
Total Current Assets														473,313,000	431,274,000
Other Noncurrent Assets (See Note 1)														83,429,000	64,575,000
Total Assets														3,730,567,000	3,471,933,000
Equity:
Common Stock SJI, Par Value $1.25, Authorized 120,000,000 shares, Outstanding - 79,478,055 (2016) shares and 70,965,622 (2015)														99,347,000	88,707,000			$ 85,418,000
Premium on Common Stock														706,943,000	499,460,000
Treasury Stock (at par)														(266,000)	(296,000)
Accumulated Other Comprehensive Loss														(27,381,000)	(24,499,000)
Retained Earnings			510,597,000			474,167,000	474,167,000				474,167,000	474,167,000		510,597,000	474,167,000
Total Equity														1,289,240,000	1,037,539,000
Long-Term Debt (See Note 1)														1,047,482,000	1,035,848,000
Current Liabilities:
Notes Payable - Banks														296,100,000	431,700,000
Current Portion of Long-Term Debt														231,909,000	29,454,000
Accounts Payable														243,669,000	186,400,000
Other Current Liabilities														15,219,000	11,596,000
Total Current Liabilities														952,624,000	832,476,000
Other Noncurrent Liabilities														10,584,000	22,990,000
Total Capitalization and Liabilities														$ 3,730,567,000	$ 3,471,933,000
Common stock, par value (in USD per share)		$ 1.25												$ 1.25	$ 1.25
Common stock, authorized (in shares)														120,000,000	120,000,000	120,000,000	60,000,000
Common Stock, outstanding (in shares)														79,478,055	70,965,622			68,334,860	65,430,084
SOUTH JERSEY INDUSTRIES, INC.
Income Statement [Abstract]
Management Service Fee Revenues											25,463,000	20,990,000	21,118,000
Operating Expenses:
Operations											23,852,000	17,979,000	18,183,000
Depreciation											377,000	406,000	439,000
Energy and Other Taxes											1,033,000	806,000	813,000
Total Operating Expenses											25,262,000	19,191,000	19,435,000
Operating Income											201,000	1,799,000	1,683,000
Other Income:
Equity in Earnings of Subsidiaries											119,061,000	105,610,000	97,628,000
Other											11,953,000	10,145,000	7,283,000
Total Other Income											131,014,000	115,755,000	104,911,000
Interest Charges											12,148,000	11,822,000	8,803,000
Income Taxes											6,000	122,000	163,000
Income from Continuing Operations											119,061,000	105,610,000	97,628,000
Equity in Undistributed Earnings of Discontinued Operations											(251,000)	(503,000)	(582,000)
Net Income											118,810,000	105,107,000	97,046,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net Income											118,810,000	105,107,000	97,046,000
Other Comprehensive (Loss) Income - Net of Tax
Postretirement Liability Adjustment											(3,197,000)	5,518,000	(9,160,000)
Unrealized Gain (Loss) on Available-for-Sale Securities											118,000	(53,000)	(472,000)
Unrealized Gain on Derivatives - Other											197,000	294,000	134,000
Other Comprehensive (Loss) Income - Net of Tax											(2,882,000)	5,759,000	(9,498,000)
Comprehensive Income											$ 115,928,000	$ 110,866,000	$ 87,548,000
Combined average statutory tax rate											40.00%	40.00%	40.00%
Retained Earnings [Roll Forward]
Retained Earnings - Beginning						474,167,000				439,218,000	$ 474,167,000	$ 439,218,000	$ 406,041,000
Net Income											118,810,000	105,107,000	97,046,000
Retained Earnings After Net Income Before Dividends Declared														$ 592,977,000	$ 544,325,000			$ 503,087,000
Dividends Declared - Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Retained Earnings - Ending			510,597,000				474,167,000				510,597,000	474,167,000	439,218,000
Statement of Cash Flows [Abstract]
CASH PROVIDED BY OPERATING ACTIVITIES											20,120,000	38,593,000	22,244,000
CASH FLOWS FROM INVESTING ACTIVITIES:
Net Repayments from (Advances to) Associated Companies											32,300,000	(118,802,000)	(104,979,000)
Capital Expenditures											(345,000)	(150,000)	(1,610,000)
Proceeds from Sale of Property, Plant & Equipment											0	0	27,000
Purchase of Company-Owned Life Insurance											(2,398,000)	(2,328,000)	(1,250,000)
Investment in Affiliate											(65,000,000)	0	(25,000,000)
Net Cash Used in Investing Activities											(35,443,000)	(121,280,000)	(132,812,000)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt											0	50,000,000	240,000,000
Principal Repayments of Long Term Debt											0	(114,000,000)	0
Payments for Issuance of Long Term Debt											(84,000)	(55,000)	(1,558,000)
Net (Repayments of) Borrowings from Short-Term Credit Facilities											(105,500,000)	153,000,000	(144,100,000)
Dividends on Common Stock											(82,380,000)	(70,158,000)	(63,869,000)
Proceeds from Sale of Common Stock											214,426,000	63,192,000	80,680,000
Net Cash (Used in) Provided by Financing Activities											26,462,000	81,979,000	111,153,000
Net Increase (Decrease) in Cash and Cash Equivalents											11,139,000	(708,000)	585,000
Cash and Cash Equivalents at Beginning of Year						1,708,000				2,416,000	1,708,000	2,416,000	1,831,000
Cash and Cash Equivalents at End of Year			12,847,000				1,708,000				12,847,000	1,708,000	2,416,000
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost														2,685,000	2,468,000
Accumulated Depreciation														(2,026,000)	(1,768,000)
Property, Plant and Equipment - Net														659,000	700,000
Investments:
Investments in Subsidiaries														1,233,856,000	1,051,675,000
Available-for-Sale Securities														32,000	3,860,000
Total Investments														1,233,888,000	1,055,535,000
Current Assets:
Cash and Cash Equivalents			12,847,000			1,708,000	1,708,000			2,416,000	1,708,000	2,416,000	1,831,000	12,847,000	1,708,000			2,416,000	$ 1,831,000
Receivable from Associated Companies														550,227,000	582,406,000
Accounts Receivable														49,000	49,000
Other														0	2,859,000
Total Current Assets														563,123,000	587,022,000
Other Noncurrent Assets (See Note 1)														44,974,000	38,168,000
Total Assets														1,842,644,000	1,681,425,000
Equity:
Common Stock SJI, Par Value $1.25, Authorized 120,000,000 shares, Outstanding - 79,478,055 (2016) shares and 70,965,622 (2015)														99,347,000	88,707,000
Premium on Common Stock														706,943,000	499,460,000
Treasury Stock (at par)														(266,000)	(296,000)
Accumulated Other Comprehensive Loss														(27,381,000)	(24,499,000)
Retained Earnings			$ 510,597,000			$ 474,167,000	$ 474,167,000			$ 439,218,000	474,167,000	439,218,000	406,041,000	510,597,000	474,167,000			$ 439,218,000	$ 406,041,000
Total Equity														1,289,240,000	1,037,539,000
Long-Term Debt (See Note 1)														323,971,000	339,665,000
Current Liabilities:
Notes Payable - Banks														191,800,000	297,300,000
Current Portion of Long-Term Debt														16,000,000	0
Payable to Associated Companies														382,000	262,000
Accounts Payable														211,000	425,000
Other Current Liabilities														7,707,000	3,579,000
Total Current Liabilities														216,100,000	301,566,000
Other Noncurrent Liabilities														13,333,000	2,655,000
Total Capitalization and Liabilities														$ 1,842,644,000	$ 1,681,425,000
Common stock, par value (in USD per share)														$ 1.25	$ 1.25
Common stock, authorized (in shares)														120,000,000	120,000,000
Common Stock, outstanding (in shares)														79,478,055	70,965,622
Dividends received from subsidiaries											$ 0	$ 40,800,000	$ 18,200,000
[1]	Determined using a combined average statutory tax rate of 40%.
[2]	Determined using a combined average statutory tax rate of 40%.

Schedule II - Valuation and Q84

Schedule II - Valuation and Qualifying Accounts (Details) - Provision for Uncollectible Accounts - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 10,252	$ 7,910	$ 5,854
Charged to Costs and Expenses	6,907	14,730	9,519
Charged to Other Accounts	(47)	(79)	(102)
Deductions	4,368	12,309	7,361
Balance at End of Period	$ 12,744	$ 10,252	$ 7,910